PBF Finance 10-K 3 Mar 23 2022 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2022	Feb. 24, 2023	Jun. 30, 2022
Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	001-35764
Entity Registrant Name	PBF HOLDING COMPANY LLC
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	27-2198168
Entity Address, Address Line One	One Sylvan Way, Second Floor
Entity Address, City or Town	Parsippany
Entity Address, State or Province	NJ
Entity Address, Postal Zip Code	07054
City Area Code	973
Local Phone Number	455-7500
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	Yes
Entity Current Reporting Status	No
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 0
Entity Common Stock, Shares Outstanding (in shares)		0
Documents Incorporated by Reference	PBF Energy Inc., the managing member of our direct parent PBF Energy Company LLC, will file with the Securities and Exchange Commission a definitive Proxy Statement for its 2023
Entity Central Index Key	0001566011
Amendment Flag	false
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2022
PBF Finance Corporation
Entity Information [Line Items]
Entity Registrant Name	PBF FINANCE CORP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	45-2685067
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	Yes
Entity Current Reporting Status	No
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 0
Entity Common Stock, Shares Outstanding (in shares)		100
Entity Central Index Key	0001566097

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2022
Audit Information [Abstract]
Auditor Location	Morristown, New Jersey
Auditor Name	Deloitte & Touche LLP
Auditor Firm ID	34

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 2,153.9	$ 1,305.7
Accounts receivable	1,451.7	1,272
Accounts receivable - affiliate	6.3	4.1
Inventories	2,763.6	2,505.1
Prepaid and other current assets	119	71.7
Total current assets	6,494.5	5,158.6
Property, plant and equipment, net	4,601.8	4,114.8
Total lease right of use assets	1,099.9	1,202.4
Deferred charges and other assets, net	954	813.8
Total assets	13,150.2	11,289.6
Current liabilities:
Accounts payable	847.5	906.3
Accounts payable - affiliate	38.2	61.7
Accrued expenses	3,691	2,728.3
Deferred revenue	37.5	40.3
Current operating lease liabilities	165
Total current liabilities	4,779.2	3,892.1
Long-term debt	1,434.9	3,673.3
Deferred tax liabilities	21	24.2
Long-term operating lease liabilities	869
Finance Lease, Liability, Noncurrent	57.9	70.6
Other long-term liabilities	371.1	251
Total liabilities	7,533.1	8,876.2
Commitments and contingencies (Note 11)
Equity:
Member’s equity	2,959.7	2,870.2
Retained earnings (accumulated deficit)	2,649.6	(489.3)
Accumulated other comprehensive income (loss)	(4.4)	20.3
Total PBF Holding Company LLC equity	5,604.9	2,401.2
Noncontrolling interest	12.2	12.2
Total equity	5,617.1	2,413.4
Total liabilities and equity	13,150.2	11,289.6
Third Party Lease
Current assets:
Total lease right of use assets	678.3	717
Current liabilities:
Current operating lease liabilities	60.5	64.8
Long-term operating lease liabilities	551.8	570.3
Finance Lease, Liability, Noncurrent	57.9	70.6
Lease with Affiliate
Current assets:
Total lease right of use assets	421.6	485.4
Current liabilities:
Current operating lease liabilities	104.5	90.7
Long-term operating lease liabilities	$ 317.2	$ 394.7

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Statement [Abstract]
Revenues	$ 46,780.6	$ 27,202	$ 15,045
Cost and expenses:
Cost of products and other	39,350.7	24,114.3	14,548.2
Operating expenses (excluding depreciation and amortization expense as reflected below)	2,495.6	1,999.1	1,835.2
Depreciation and amortization expense	466.9	415.7	498
Cost of sales	42,313.2	26,529.1	16,881.4
General and administrative expenses (excluding depreciation and amortization expense as reflected below)	438.5	226.4	229
Depreciation and amortization expense	7.5	13.3	11.3
Change in fair value of contingent consideration, net	48.1	29.4	(79.3)
Impairment expense	0	0	91.8
Loss (gain) on sale of assets	0.9	(0.2)	(477.8)
Total cost and expenses	42,808.2	26,798	16,656.4
Income (loss) from operations	3,972.4	404	(1,611.4)
Other income (expense):
Interest expense, net	(206.9)	(275.1)	(210.3)
Change in fair value of catalyst obligations	(2)	8.5	(11.8)
(Loss) gain on extinguishment of debt	(66.1)	79.9	(22.2)
Other non-service components of net periodic benefit cost	8.8	7.8	4.3
Income (loss) before income taxes	3,706.2	225.1	(1,851.4)
Income tax (benefit) expense	(2.7)	(14)	6.1
Net income (loss)	3,708.9	239.1	(1,857.5)
Less: net income (loss) attributable to noncontrolling interests	(1.4)	2.3	(0.3)
Net income (loss) attributable to PBF Holding Company LLC	$ 3,710.3	$ 236.8	$ (1,857.2)

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 3,708.9	$ 239.1	$ (1,857.5)
Other comprehensive income (loss):
Unrealized loss on available for sale securities	(2.5)	(0.7)	(0.1)
Net (loss) gain on pension and other post-retirement benefits	(22.2)	27.1	3.7
Total other comprehensive income (loss)	(24.7)	26.4	3.6
Comprehensive income (loss)	3,684.2	265.5	(1,853.9)
Less: comprehensive income (loss) attributable to noncontrolling interests	(1.4)	2.3	(0.3)
Comprehensive income (loss) attributable to PBF Holding Company LLC	$ 3,685.6	$ 263.2	$ (1,853.6)

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total	Member's Equity	Accumulated Other Comprehensive Income (Loss)	Retained Earnings (Accumulated Deficit)	Noncontrolling Interest
Beginning balance at Dec. 31, 2019	$ 3,897.2	$ 2,739.1	$ (9.7)	$ 1,156.9	$ 10.9
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Member distributions	(23.1)			(23.1)
Capital contributions from PBF LLC	42.4	42.4
Stock based compensation	28.2	28.2
Comprehensive income	(1,853.9)		3.6	(1,857.2)	(0.3)
Ending balance at Dec. 31, 2020	2,090.8	2,809.7	(6.1)	(723.4)	10.6
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Member distributions	(2.7)			(2.7)
Capital contributions from PBF LLC	37	37
Distribution of assets to PBF LLC	(0.4)	(0.4)
Stock based compensation	23.9	23.9
Comprehensive income	265.5		26.4	236.8	2.3
Other	0.7				0.7
Ending balance at Dec. 31, 2021	2,413.4	2,870.2	20.3	(489.3)	12.2
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Member distributions	(571.4)			(571.4)
Capital contributions from PBF LLC	56.4	56.4
Distribution of assets to PBF LLC	(0.1)	(0.1)
Stock based compensation	33.2	33.2
Comprehensive income	3,684.2		(24.7)	3,710.3	(1.4)
Other	1.4				1.4
Ending balance at Dec. 31, 2022	$ 5,617.1	$ 2,959.7	$ (4.4)	$ 2,649.6	$ 12.2

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Cash flows from operating activities:
Net income (loss)	$ 3,708.9	$ 239.1	$ (1,857.5)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization	495.6	444.3	523.8
Impairment expense	0	0	91.8
Stock-based compensation	44.1	30.3	29.3
Change in fair value of catalyst obligations	2	(8.5)	11.8
Deferred income taxes	(3.2)	(14.5)	7.3
Non-cash change in inventory repurchase obligations	(5.4)	(8.4)	(12.6)
Non-cash lower of cost or market inventory adjustment	0	(669.6)	268
Change in fair value of contingent consideration, net	48.1	29.4	(79.3)
Loss (gain) on extinguishment of debt	66.1	(79.9)	22.2
Pension and other post-retirement benefit costs	47.6	50.8	55.7
Loss (gain) on sale of assets	0.9	(0.2)	(477.8)
Changes in operating assets and liabilities:
Accounts receivable	(179.6)	(770.5)	325.1
Due to/from affiliates	(25.7)	9.3	6.7
Inventories	(258.5)	(149.3)	392.2
Prepaid and other current assets	(5)	(15.3)	(3)
Accounts payable	(97.7)	480.1	(200.6)
Accrued expenses	860.8	806.9	111.5
Deferred revenue	(2.8)	(4.8)	28.2
Other assets and liabilities	0	(76.9)	(62.8)
Net cash provided by (used in) operating activities	4,696.2	292.3	(820)
Cash flows from investing activities:
Expenditures for property, plant and equipment	(625.4)	(240.5)	(183.9)
Expenditures for deferred turnaround costs	(311.6)	(117.7)	(188.1)
Expenditures for other assets	(66)	(28.9)	(9.1)
Acquisition of Martinez refinery	0	0	(1,176.2)
Proceeds from sale of assets	0	0	543.1
Net cash used in investing activities	(1,003)	(387.1)	(1,014.2)
Cash flows from financing activities:
Contributions from PBF LLC	56.4	37	42.4
Proceeds from revolver borrowings	400	0	1,450
Repayments of revolver borrowings	(1,300)	0	(550)
Settlements of precious metal catalyst obligations	(56.2)	(31.7)	(8.8)
Proceeds from catalyst financing arrangements	0	0	51.9
Payments on financing leases	(11.3)	(17.8)	(12.4)
Proceeds from insurance premium financing	2.1	0	0
Deferred financing costs and other	(31.3)	0.5	(34.7)
Net cash (used in) provided by financing activities	(2,845)	(169.6)	2,641.2
Net change in cash and cash equivalents	848.2	(264.4)	807
Cash and cash equivalents, beginning of period	1,305.7	1,570.1	763.1
Cash and cash equivalents, end of period	2,153.9	1,305.7	1,570.1
Non-cash activities:
Accrued and unpaid capital expenditures	165.2	103.2	31.1
Assets acquired or remeasured under operating and financing leases	82.8	(106.6)	702
Fair value of the Martinez Contingent Consideration at acquisition	0	0	77.3
Cash paid during the year for:
Interest (net of capitalized interest of $24.8, $8.9 and $11.9 in 2022, 2021 and 2020, respectively)	211.5	265.4	162.9
Capitalized interest	24.8	8.9	11.9
Income taxes	0.8	1	1
Collins Pipeline Company And T&M Terminal Company
Cash flows from financing activities:
Payments of capital distribution	0	(0.7)	0
Members
Cash flows from financing activities:
Payments of capital distribution	(571.4)	(2.7)	(23.1)
2025 Senior Secured Notes
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Loss (gain) on extinguishment of debt	(69.9)
Cash flows from financing activities:
Proceeds from issuance of long-term debt	0	0	1,250.6
Repayments of long-term debt	(1,307.4)	0	0
2028 Senior Notes
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Loss (gain) on extinguishment of debt	(3.6)	(62.4)
Cash flows from financing activities:
Proceeds from issuance of long-term debt	0	0	1,000
Repayments of long-term debt	(21.1)	(109.3)	0
2025 Senior Notes
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Loss (gain) on extinguishment of debt	(0.2)	(17.5)
Cash flows from financing activities:
Repayments of long-term debt	(4.8)	(37.5)	0
2023 Senior Notes
Cash flows from financing activities:
Repayments of long-term debt	0	0	(517.5)
Rail Term Loan
Cash flows from financing activities:
Repayments of long-term debt	$ 0	$ (7.4)	$ (7.2)

DESCRIPTION OF THE BUSINESS AND

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION	12 Months Ended
	Dec. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION	DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION Description of the Business PBF Holding Company LLC (“PBF Holding”), together with its 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 December 31, 2022. Collectively, PBF Holding and its consolidated subsidiaries are referred to hereinafter as the “Company”. Substantially all of the Company’s operations are in the United States. As of December 31, 2022, the Company’s oil refineries are all engaged in the refining of crude oil and other feedstocks into petroleum products, and have been aggregated to form one reportable segment. PBF Logistics GP LLC (“PBFX GP”) serves as the general partner of PBF Logistics LP (“PBFX”). PBF GP is wholly-owned by PBF LLC. On May 14, 2014, PBFX completed its initial public offering (the “PBFX Offering”). In connection with the PBFX Offering, we distributed to PBF LLC, which in turn contributed to PBFX, the assets and liabilities of certain crude oil terminaling assets. In a series of transactions subsequent to the PBFX Offering, we distributed certain additional assets to PBF LLC, which in turn contributed those assets to PBFX.(as described in “Note 10 - Related Party Transactions”). On November 27, 2022, PBF Energy and PBF LLC enter into the Merger Agreement with PBFX announcing the Merger Transaction, which was finalized on November 30, 2022 (all terms as defined in “Note 10 - Related Party Transactions”.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Principles of Consolidation and Presentation These Consolidated Financial Statements include the accounts of PBF Holding and its consolidated subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation. Cost Classifications Cost of products and other consists of the cost of crude oil, other feedstocks, blendstocks and purchased refined products and the related in-bound freight and transportation costs. Operating expenses (excluding depreciation and amortization) consists of direct costs of labor, maintenance and services, utilities, property taxes, environmental compliance costs and other direct operating costs incurred in connection with our refining operations. Such expenses exclude depreciation related to refining and logistics assets that are integral to the refinery production process, which is presented separately as Depreciation and amortization expense as a component of Cost of sales on the Company’s Consolidated Statements of Operations. Use of Estimates The preparation of the financial statements in conformity with accounting principles generally accepted in the United States (“GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures. Actual results could differ from those estimates. Impairment Assessment of Long-Lived Assets and Definite-Lived Intangibles The Company evaluates long-lived assets for impairment on a continual basis and reassesses the reasonableness of their related useful lives whenever events or changes in circumstances warrant assessment. Possible triggering events may include, among other things, significant adverse changes in the business climate, market conditions, environmental regulations or a determination that it is more likely than not that an asset or an asset group will be sold or retired before its estimated useful life. These possible triggering events of impairment may impact the Company’s assumptions related to future throughput levels, future operating revenues, expenses and gross margin, levels of anticipated capital expenditures and remaining useful life. Long-lived assets are tested for recoverability whenever events or changes in circumstances indicate that the carrying amount of the asset may not be recoverable. A long-lived asset is not recoverable if its carrying amount exceeds the sum of the undiscounted cash flows expected to result from its use, early retirement or disposition. Cash flows for long-lived assets/asset groups are determined at the lowest level for which identifiable cash flows exist. The cash flows from the refinery asset groups are evaluated individually regardless of product mix or fuel type produced. If a long-lived asset is not recoverable, an impairment loss is recognized for the amount by which the carrying amount of the long-lived asset exceeds its fair value, with fair value determined based on discounted estimated net cash flows or other appropriate methods. The Company’s assumptions incorporate inherent uncertainties that are at times difficult to predict and could result in impairment charges or accelerated depreciation in future periods if actual results materially differ from the estimated assumptions used. Business Combinations We use the acquisition method of accounting for the recognition of assets acquired and liabilities assumed in business combinations at their estimated fair values as of the date of acquisition. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired is recorded as goodwill. Significant judgment is required in estimating the fair value of assets acquired. As a result, in the case of significant acquisitions, we obtain the assistance of third-party valuation specialists in estimating fair values of tangible and intangible assets based on available historical information and on expectations and assumptions about the future, considering the perspective of marketplace participants. While management believes those expectations and assumptions are reasonable, they are inherently uncertain. Unanticipated market or macroeconomic events and circumstances may occur, which could affect the accuracy or validity of the estimates and assumptions. Certain of the Company’s acquisitions may include earn-out provisions or other forms of contingent consideration. As of the acquisition date, the Company records contingent consideration, as applicable, at the estimated fair value of expected future payments associated with the earn-out. Any changes to the recorded fair value of contingent consideration, subsequent to the measurement period, will be recognized as earnings in the period in which it occurs. Cash and Cash Equivalents The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents. The carrying amount of the cash equivalents approximates fair value due to the short-term maturity of those instruments. Concentrations of Credit Risk For the years ended December 31, 2022 and December 31, 2021, only one customer, Shell plc (“Shell”), accounted for 10% or more of the Company’s revenues (approximately 14% and 15%, respectively). As of December 31, 2022 and December 31, 2021, only one customer, Shell, accounted for 10% or more of the Company’s total trade accounts receivable (approximately 19% and 26%, respectively). Revenue Recognition The Company sells various refined products primarily through its refinery subsidiaries and recognizes revenue related to the sale of products when control of the promised goods or services is transferred to the customers, in an amount that reflects the consideration the Company expects to be entitled to in exchange for those goods or services. Refer to “Note 16 - Revenues” for further discussion of the Company’s revenue recognition policy. Accounts Receivable Accounts receivable are carried at invoiced amounts. An allowance for doubtful accounts is established, if required, to report such amounts at their estimated net realizable value. In estimating probable losses, management reviews accounts that are past due and determines if there are any known disputes. Excise taxes on sales of refined products that are collected from customers and remitted to various governmental agencies are reported on a net basis. Inventory Inventories are carried at the lower of cost or market. The cost of crude oil, feedstocks, blendstocks and refined products are determined under the last-in first-out (“LIFO”) method using the dollar value LIFO method with increments valued based on average purchase prices during the year. The cost of supplies and other inventories is determined principally on the weighted average cost method. RINs The Company is subject to obligations to purchase Renewable Identification Numbers (“RINs”) required to comply with the renewable fuel standard implemented by Environmental Protection Agency (“EPA”), which sets annual quotas for the quantity of renewable fuels (such as ethanol) that must be blended into motor fuels consumed in the United States (the “RFS”). The Company’s overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by EPA. 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. Leases The Company leases office space, office equipment, refinery facilities and equipment, railcars and other logistics assets primarily under non-cancelable operating leases, with terms typically ranging from one The Company determines whether a contract is or contains a lease at inception of the contract and whether that lease meets the classification criteria of a finance or operating lease. When available, the Company uses the rate implicit in the lease to discount lease payments to present value; however, most of the Company’s leases do not provide a readily determinable implicit rate. Therefore, the Company must discount lease payments based on an estimate of its incremental borrowing rate. For substantially all classes of underlying assets, the Company has elected the practical expedient not to separate lease and non-lease components, which allows for combining the components if certain criteria are met. For certain leases of refinery support facilities, the Company accounts for the non-lease service component separately. Property, Plant and Equipment Property, plant and equipment additions are recorded at cost. The Company capitalizes costs associated with the preliminary, pre-acquisition and development/construction stages of a major construction project. The Company capitalizes the interest cost associated with major construction projects based on the effective interest rate of total borrowings. The Company also capitalizes costs incurred in the acquisition and development of software for internal use, including the costs of software, materials, consultants and payroll-related costs for employees incurred in the application development stage. Depreciation is computed using the straight-line method over the following estimated useful lives: Process units and equipment 5-25 years Pipeline and equipment 5-25 years Buildings 25 years Computers, furniture and fixtures 3-7 years Leasehold improvements 20 years Railcars 50 years Maintenance and repairs are charged to operating expenses as they are incurred. Improvements and betterments, which extend the lives of the assets, are capitalized. Deferred Charges and Other Assets, Net Deferred charges and other assets include refinery turnaround costs, catalyst, precious metal catalysts, linefill, deferred financing costs and intangible assets. Refinery turnaround costs, which are incurred in connection with planned major maintenance activities, are capitalized when incurred and amortized on a straight-line basis over the period of time estimated to lapse until the next turnaround occurs. The amortization period generally ranges from 3 to 6 years; however, based upon the specific facts and circumstances, different periods of deferral occur. Precious metal catalysts, linefill and certain other intangibles are considered indefinite-lived assets as they are not expected to deteriorate in their prescribed functions. Such assets are assessed for impairment in connection with the Company’s review of its long-lived assets. Deferred financing costs are capitalized when incurred and amortized over the life of the loan (generally 1 to 8 years). Intangible assets with finite lives primarily consist of emission credits and permits and are amortized over their estimated useful lives (generally 1 to 10 years). Asset Retirement Obligations The Company records an asset retirement obligation at fair value for the estimated cost to retire a tangible long-lived asset at the time the Company incurs that liability, which is generally when the asset is purchased, constructed, or leased. The Company records the liability when it has a legal or contractual obligation to incur costs to retire the asset and when a reasonable estimate of the fair value of the liability can be made. If a reasonable estimate cannot be made at the time the liability is incurred, the Company will record the liability when sufficient information is available to estimate the liability’s fair value. Certain of the Company’s asset retirement obligations are based on its legal obligation to perform remedial activity at its refinery sites when it permanently ceases operations of the long-lived assets. The Company therefore considers the settlement date of these obligations to be indeterminable. Accordingly, the Company cannot calculate an associated asset retirement liability for these obligations at this time. The Company will measure and recognize the fair value of these asset retirement obligations when the settlement date is determinable. Environmental Matters Liabilities for future remediation costs are recorded when environmental assessments and/or remedial efforts are probable and the costs can be reasonably estimated. Other than for assessments, the timing and magnitude of these accruals generally are based on the completion of investigations or other studies or a commitment to a formal plan of action. Environmental liabilities are based on best estimates of probable future costs using currently available technology and applying current regulations, as well as the Company’s own internal environmental policies. The measurement of environmental remediation liabilities may be discounted to reflect the time value of money if the aggregate amount and timing of cash payments of the liabilities are fixed or reliably determinable. The actual settlement of the Company’s liability for environmental matters could materially differ from its estimates due to a number of uncertainties such as the extent of contamination, changes in environmental laws and regulations, potential improvements in remediation technologies and the participation of other responsible parties. Stock-Based Compensation Stock-based compensation includes the accounting effect of options to purchase PBF Energy Class A common stock granted by PBF Energy to certain PBF Holding employees, Series A warrants issued or granted by PBF LLC to employees in connection with their acquisition of PBF LLC Series A units, options to acquire Series A units of PBF LLC granted by PBF LLC to certain employees, Series B units of PBF LLC that were granted to certain members of management and restricted PBF LLC Series A Units and restricted PBF Energy Class A common stock granted to certain directors and officers. The estimated fair value of the options to purchase PBF Energy Class A common stock and the PBF LLC Series A warrants and options, is based on the Black-Scholes option pricing model and the fair value of the PBF LLC Series B units is estimated based on a Monte Carlo simulation model. The estimated fair value is amortized as stock-based compensation expense on a straight-line method over the vesting period and included in General and administrative expense with forfeitures recognized in the period they occur. PBF Energy grants performance share unit awards and performance unit awards to certain key employees. Performance awards granted to employees prior to November 1, 2020 are based on a three-year performance cycle with four measurement periods and performance awards granted to employees after November 1, 2020 are based on a three-year performance cycle having a single measurement period. The payout for each, which ranges from zero to 200%, is based on the relative ranking of the total shareholder return (“TSR”) of PBF Energy’s common stock as compared to the TSR of a selected group of industry peer companies over an average of four measurement periods. The performance share unit awards and performance unit awards are each measured at fair value based on Monte Carlo simulation models. The performance share unit awards will be settled in PBF Energy Class A common stock and are accounted for as equity awards and the performance unit awards will be settled in cash and are accounted for as liability awards. Income Taxes As PBF Holding is a limited liability company treated as a “flow-through” entity for income tax purposes, there is no benefit or expense for federal or state income tax in the accompanying financial statements apart from the income taxes attributable to two subsidiaries acquired in connection with the acquisition of Chalmette Refining, L.L.C. (“Chalmette Refining”) and the Company’s wholly-owned Canadian subsidiary, PBF Energy Limited (“PBF Ltd.”). These subsidiaries are treated as C-corporations for tax purposes, with the tax provision calculated based on the effective tax rate for the periods presented. The State tax returns for all years since 2018 are subject to examination by the respective tax authorities. Pension and Other Post-Retirement Benefits The Company recognizes an asset for the overfunded status or a liability for the underfunded status of its pension and post-retirement benefit plans. The funded status is recorded within Other long-term liabilities or Other non-current assets. Changes in the plans’ funded status are recognized in other comprehensive income in the period the change occurs. Fair Value Measurement A fair value hierarchy (Level 1, Level 2, or Level 3) is used to categorize fair value amounts based on the quality of inputs used to measure fair value. Accordingly, fair values derived from Level 1 inputs utilize quoted prices in active markets for identical assets or liabilities. Fair values derived from Level 2 inputs are based on quoted prices for similar assets and liabilities in active markets, and inputs other than quoted prices that are either directly or indirectly observable for the asset or liability. Level 3 inputs are unobservable inputs for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability. The Company uses appropriate valuation techniques based on the available inputs to measure the fair values of its applicable assets and liabilities. When available, the Company measures fair value using Level 1 inputs because they generally provide the most reliable evidence of fair value. In some valuations, the inputs may fall into different levels in the hierarchy. In these cases, the asset or liability level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurements. Financial Instruments The estimated fair value of financial instruments has been determined based on the Company’s assessment of available market information and appropriate valuation methodologies. The Company’s non-derivative financial instruments that are included in current assets and current liabilities are recorded at cost in the Consolidated Balance Sheets. The estimated fair value of these financial instruments approximates their carrying value due to their short-term nature. Derivative instruments are recorded at fair value in the Consolidated Balance Sheets. The Company’s commodity contracts are measured and recorded at fair value using Level 1 inputs based on quoted prices in an active market, Level 2 inputs based on quoted market prices for similar instruments, or Level 3 inputs based on third-party sources and other available market based data. The Company’s catalyst obligations and derivatives related to the Company’s crude oil and feedstocks and refined product purchase obligations are measured and recorded at fair value using Level 2 inputs on a recurring basis, based on observable market prices for similar instruments. Derivative Instruments The Company is exposed to market risk, primarily related to changes in commodity prices for the crude oil and feedstocks used in the refining process as well as the prices of the refined products sold and the risk associated with the price of credits needed to comply with various governmental and regulatory environmental compliance programs. The accounting treatment for commodity and environmental compliance contracts depends on the intended use of the particular contract and on whether or not the contract meets the definition of a derivative. All derivative instruments, not designated as normal purchases or sales, are recorded in the Consolidated Balance Sheets as either assets or liabilities measured at their fair values. Changes in the fair value of derivative instruments that either are not designated or do not qualify for hedge accounting treatment or normal purchase or normal sale accounting are recognized in earnings. Contracts qualifying for the normal purchase and sales exemption are accounted for upon settlement. Cash flows related to derivative instruments that are not designated or do not qualify for hedge accounting treatment are included in operating activities. The Company designates certain derivative instruments as fair value hedges of a particular risk associated with a recognized asset or liability. At the inception of the hedge designation, the Company documents the relationship between the hedging instrument and the hedged item, as well as its risk management objective and strategy for undertaking various hedge transactions. Derivative gains and losses related to these fair value hedges, including hedge ineffectiveness, are recorded in cost of sales along with the change in fair value of the hedged asset or liability attributable to the hedged risk. Cash flows related to derivative instruments that are designated as fair value hedges are included in operating activities. Economic hedges are hedges not designated as fair value or cash flow hedges for accounting purposes that are used to (i) manage price volatility in certain refinery feedstock and refined product inventories, and (ii) manage price volatility in certain forecasted refinery feedstock purchases and refined product sales. These instruments are recorded at fair value and changes in the fair value of the derivative instruments are recognized currently in cost of sales. Derivative accounting is complex and requires management judgment in the following respects: identification of derivatives and embedded derivatives, determination of the fair value of derivatives, documentation of hedge relationships, assessment and measurement of hedge ineffectiveness and election and designation of the normal purchases and sales exemption. All of these judgments, depending upon their timing and effect, can have a significant impact on the Company’s earnings. Recently Issued Accounting Pronouncements In March 2020, the Financial Accounting Standards Board (“FASB”) 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 relationship 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.

CURRENT EXPECTED CREDIT LOSSES

CURRENT EXPECTED CREDIT LOSSES	12 Months Ended
	Dec. 31, 2022
Credit Loss [Abstract]
CURRENT EXPECTED CREDIT LOSSES	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 December 31, 2022 or December 31, 2021.

INVENTORIES

INVENTORIES	12 Months Ended
	Dec. 31, 2022
Inventory Disclosure [Abstract]
INVENTORIES	INVENTORIES Inventories consisted of the following: December 31, 2022 (in millions) Titled Inventory Inventory Intermediation Agreement Total Crude oil and feedstocks $ 1,195.2 $ 140.9 $ 1,336.1 Refined products and blendstocks 1,244.7 40.9 1,285.6 Warehouse stock and other 141.9 — 141.9 $ 2,581.8 $ 181.8 $ 2,763.6 Lower of cost or market adjustment — — — Total inventories $ 2,581.8 $ 181.8 $ 2,763.6 December 31, 2021 (in millions) Titled Inventory Inventory Intermediation Agreement Total Crude oil and feedstocks $ 953.5 $ 151.4 $ 1,104.9 Refined products and blendstocks 964.6 293.8 1,258.4 Warehouse stock and other 141.8 — 141.8 $ 2,059.9 $ 445.2 $ 2,505.1 Lower of cost or market adjustment — — — Total inventories $ 2,059.9 $ 445.2 $ 2,505.1 On October 25, 2021, PBF Holding and its subsidiaries, Delaware City Refining Company LLC, Paulsboro Refining Company LLC, and Chalmette Refining (collectively, the “PBF Entities”), entered into a third amended and restated inventory intermediation agreement (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 in Note 8 - Credit Facilities and Debt). Pursuant to the Third Inventory Intermediation Agreement, J. Aron will continue to purchase and hold 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 are sold back to the Company as the J. Aron Products are discharged out of the Storage Tanks. These purchases and sales are settled daily, and pricing is trued-up monthly at the market prices related to those J. Aron Products. These transactions are considered to be made in contemplation of each other and, accordingly, do not result in the recognition of a sale when title passes from the Refineries to J. Aron. Additionally, J. Aron has the right to store the J. Aron Products purchased in Storage Tanks under the Third Inventory Intermediation Agreement and will retain these storage rights for the term of the agreement. PBF Holding continues to market and sell the J. Aron Products independently to third parties. At December 31, 2022 and December 31, 2021, the replacement value of inventories exceeded the LIFO carrying value. There was no lower of cost or market (“LCM”) inventory reserve at December 31, 2022. During the year ended December 31, 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 December 31, 2021 compared to an LCM inventory reserve of $669.6 million at December 31, 2020. An actual valuation of inventories valued under the LIFO method is made at the end of each year based on inventory levels and costs at that time. The Company recorded a charge related to a LIFO layer decrement of $83.0 million during the year ended December 31, 2020. There were no significant decrements recorded during the years ended December 31, 2022 or December 31, 2021. The majority of the decrement recorded in 2020 related to the Company’s East Coast LIFO inventory layer and the reduction in the Company’s East Coast inventory experienced as part of the East Coast Refining Reconfiguration (as defined in “Note 5 - Property, Plant and Equipment, net”) and our decision to operate our two refineries on the east coast as one functional unit.

PROPERTY, PLANT AND EQUIPMENT,

PROPERTY, PLANT AND EQUIPMENT, NET	12 Months Ended
	Dec. 31, 2022
Property, Plant and Equipment [Abstract]
PROPERTY, PLANT AND EQUIPMENT, NET	PROPERTY, PLANT AND EQUIPMENT, NET Property, plant and equipment, net consisted of the following: (in millions) December 31, 2022 December 31, 2021 Land $ 418.8 $ 418.8 Processing units, pipelines and equipment 4,508.8 4,326.8 Buildings and leasehold improvements 107.8 107.3 Computers, furniture and fixtures 175.7 168.1 Construction in progress 825.1 328.1 6,036.2 5,349.1 Less - Accumulated depreciation (1,434.4) (1,234.3) Total property, plant and equipment, net $ 4,601.8 $ 4,114.8 Depreciation expense for the years ended December 31, 2022, 2021 and 2020 was $200.4 million, $192.3 million and $179.4 million, respectively. The Company capitalized $24.8 million and $8.9 million in interest during 2022 and 2021, respectively, in connection with construction in progress. East Coast Refining Reconfiguration On December 31, 2020, the Company reconfigured the Delaware City and Paulsboro refineries (the “East Coast Refining Reconfiguration”) temporarily idling certain of its major processing units at the Paulsboro refinery, in order to operate the two refineries as one functional unit referred to as the “East Coast Refining System”. The reconfiguration process resulted in lower overall throughput and inventory levels in addition to decreases in capital and operating costs. The Company abandoned certain projects related to assets under construction related to these idled assets, resulting in an impairment charge of approximately $11.9 million and a corresponding decrease to its construction in progress account in 2020. Capital Project Abandonments During 2020, in connection with the Company’s strategic response plan to deal with the COVID-19 pandemic and its East Coast Refining Reconfiguration, it assessed its refinery wide slate of capital projects that were either in process or not yet placed into service as of December 31, 2020. Based on this assessment and the Company’s strategic plan to reduce capital expenditures, it decided to abandon various capital projects across the refinery system, resulting in an impairment charge of approximately $79.9 million in 2020. Sale of Hydrogen Plants On April 17, 2020, the Company closed on the sale of five hydrogen plants to Air Products and Chemicals, Inc. (“Air Products”) in a sale-leaseback transaction for gross cash proceeds of $530.0 million and recognized a gain of $471.1 million. In connection with the sale, the Company entered into a transition services agreement which was followed by the execution of long-term supply agreements in August 2020. Refer to “Note 12 - Leases” for further information. Torrance Land Sales On December 30, 2020, the Company closed on a third-party sale of parcels of real property acquired as part of the Torrance refinery, but not part of the refinery itself. The sale resulted in a gain of approximately $8.1 million in 2020 included within Gain on sale of assets in the Consolidated Statements of Operations.

DEFERRED CHARGES AND OTHER ASSE

DEFERRED CHARGES AND OTHER ASSETS, NET	12 Months Ended
	Dec. 31, 2022
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
DEFERRED CHARGES AND OTHER ASSETS, NET	DEFERRED CHARGES AND OTHER ASSETS, NET Deferred charges and other assets, net consisted of the following: (in millions) December 31, 2022 December 31, 2021 Deferred turnaround costs, net $ 619.5 $ 537.0 Catalyst, net (a) 199.7 166.8 Environmental credits 41.4 41.3 Linefill 27.4 27.4 Pension plan assets 18.6 20.7 Other 47.4 20.6 Total deferred charges and other assets, net $ 954.0 $ 813.8 (a) Catalyst, net includes $117.0 million and $113.0 million of indefinite-lived precious metal catalysts (both owned or financed as part of existing catalyst financing arrangements) as of December 31, 2022 and December 31, 2021, respectively. The Company recorded amortization expense related to deferred turnaround costs, catalyst and intangible assets of $261.5 million, $220.6 million and $315.7 million for the years ended December 31, 2022, 2021 and 2020, respectively. Included in the year 2020 amortization expense is approximately $56.2 million of accelerated unamortized deferred turnaround costs associated with assets that were idled as part of the East Coast Refining Reconfiguration. Intangible assets, net, included in “Other” above, primarily consists of permits and emission credits. Our net balance as of December 31, 2022 and December 31, 2021 is shown below: (in millions) December 31, 2022 December 31, 2021 Intangible assets - gross $ 4.0 $ 4.0 Accumulated amortization (3.5) (3.5) Intangible assets - net $ 0.5 $ 0.5

ACCRUED EXPENSES

ACCRUED EXPENSES	12 Months Ended
	Dec. 31, 2022
Payables and Accruals [Abstract]
ACCRUED EXPENSES	ACCRUED EXPENSES Accrued expenses consisted of the following: (in millions) December 31, 2022 December 31, 2021 Inventory-related accruals $ 1,417.4 $ 959.9 Renewable energy credit and emissions obligations (a) 1,361.1 953.9 Accrued salaries and benefits 172.9 57.1 Accrued transportation costs 127.3 91.0 Excise and sales tax payable 123.8 112.3 Accrued utilities 105.4 73.0 Inventory intermediation agreement (b) 98.3 280.1 Accrued capital expenditures 85.7 62.6 Contingent Consideration 81.6 — Accrued refinery maintenance and support costs 48.1 55.8 Accrued interest 20.1 32.8 Environmental liabilities 14.1 14.3 Current finance lease liabilities 11.7 11.1 Other 23.5 24.4 Total accrued expenses $ 3,691.0 $ 2,728.3 (a) The Company is subject to obligations to purchase RINs required to comply with the RFS. The Company’s overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by EPA. 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. The Company enters into forward purchase commitments in order to acquire its renewable energy and emissions credits at fixed prices. As of December 31, 2022, the Company had entered into approximately $899.2 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 a triennial period program which will be settled through 2024. (b) The Company has the obligation to repurchase the J. Aron Products that are held in its Storage Tanks in accordance with the Third Inventory Intermediation Agreement. As of December 31, 2022 and December 31, 2021, a liability is recognized based on the repurchase obligation under the Third Inventory Intermediation Agreement 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.

CREDIT FACILITIES AND DEBT

CREDIT FACILITIES AND DEBT	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
CREDIT FACILITIES AND DEBT	CREDIT FACILITIES AND DEBT Long-term debt outstanding consisted of the following: (in millions) December 31, 2022 December 31, 2021 2025 Senior Secured Notes $ — $ 1,250.0 2028 Senior Notes 801.6 826.5 2025 Senior Notes 664.5 669.5 Revolving Credit Facility — 900.0 Catalyst financing arrangements 4.0 58.4 1,470.1 3,704.4 Unamortized premium — 0.5 Unamortized deferred financing costs (35.2) (31.6) Long-term debt $ 1,434.9 $ 3,673.3 As of December 31, 2022, the Company is in compliance with all covenants, including financial covenants, in all its debt agreements. 2025 Senior Secured Notes On May 13, 2020, PBF Holding entered into an indenture among PBF Holding and PBF Holding’s wholly-owned subsidiary, PBF Finance Corporation (“PBF Finance” and together with PBF Holding, the “Issuers”), the guarantors named therein (collectively the “Guarantors”), and Wilmington Trust, National Association, as Trustee, Paying Agent, Registrar, Transfer Agent, Authenticating Agent and Notes Collateral Agent, under which the Issuers issued $1.0 billion in aggregate principal amount of 9.25% senior secured notes due 2025 (the “initial 2025 Senior Secured Notes”). The Issuers received net proceeds of approximately $982.9 million from the offering after deducting the initial purchasers’ discount and offering expenses. On December 21, 2020 PBF Holding issued an additional $250.0 million in aggregate principal amount of tack on 9.25% senior secured notes due 2025 (the “additional 2025 Senior Secured Notes”). The additional 2025 Senior Secured Notes were issued at an offering price of 100.25% plus accrued and unpaid interest from and including, November 15, 2020. The additional 2025 Senior Secured Notes were issued under the indenture governing the initial 2025 Senior Secured Notes and, together with the additional 2025 Senior Secured Notes, the (“2025 Senior Secured Notes”). The additional 2025 Senior Secured Notes were treated as a single series with the initial 2025 Senior Secured Notes and had the same terms except that a portion of the additional 2025 Senior Secured Notes were issued initially under a new temporary CUSIP number to be used during the 40-day distribution compliance period. The Issuers received net proceeds of approximately $245.7 million from the offering after deducting the initial purchasers’ discount and offering expenses. The 2025 Senior Secured Notes were guaranteed on a senior secured basis by substantially all of PBF Holding’s subsidiaries. The 2025 Senior Secured Notes and guarantees were senior obligations and secured, subject to certain exceptions and permitted liens, on a first-priority basis, by substantially all of PBF Holding's and the guarantors’ present and future assets (other than assets securing the PBF Holding asset-based revolving credit facility (the “Revolving Credit Facility”)), which may also constitute collateral securing certain hedging obligations and any existing or future indebtedness that is permitted to be secured on a pari passu basis with the 2025 Senior Secured Notes. The 2025 Senior Secured Notes and guarantees were senior secured obligations and rank equal in right of payment with all of the Issuers’ and the Guarantors’ existing and future senior indebtedness, including the Revolving Credit Facility, the 6.00% senior unsecured notes due 2028 (the “2028 Senior Notes”), and the 7.25% senior unsecured notes due 2025 (the “2025 Senior Notes”). The 2025 Senior Secured Notes and guarantees ranked effectively senior to all of the Issuers’ and the Guarantors’ existing and future indebtedness that is not secured by the collateral (including the Revolving Credit Facility, the 2028 Senior Notes and the 2025 Senior Notes), subject to permitted liens on such collateral and certain other exceptions, and senior in right of payment to the Issuers’ and the Guarantors’ existing and future indebtedness that is expressly subordinated in right of payment thereto. The 2025 Senior Secured Notes and the guarantees were effectively subordinated to any of the Issuers’ and the Guarantors’ existing or future secured indebtedness that is secured by liens on assets owned by the Company that do not constitute part of the collateral securing the 2025 Senior Secured Notes and the guarantees (including the assets securing the Revolving Credit Facility) to the extent of the value of the collateral securing such indebtedness. The 2025 Senior Secured Notes and the guarantees were structurally subordinated to any existing or future indebtedness and other obligations of the Issuers’ non-guarantor subsidiaries. In addition, the 2025 Senior Secured Notes contained customary terms, events of default and covenants for an issuer of non-investment grade debt securities. These covenants included limitations on the incurrence of additional indebtedness, equity issuances, and payments. Many of these covenants were to cease to apply or were to be modified if the 2025 Senior Secured Notes were rated investment grade. During 2022, the Company exercised its rights under the indenture governing 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. 2028 Senior Notes On January 24, 2020, PBF Holding entered into an indenture among the Issuers, the Guarantors, Wilmington Trust, National Association, as Trustee and Deutsche Bank Trust Company Americas, as Paying Agent, Registrar, Transfer Agent and Authenticating Agent, under which the Issuers issued $1.0 billion in aggregate principal amount of the 2028 Senior Notes. The Issuers received net proceeds of approximately $987.0 million from the offering after deducting the initial purchasers’ discount and offering expenses. The Company primarily used the net proceeds to fully redeem the 7.00% senior notes due 2023 (the “2023 Senior Notes”), including accrued and unpaid interest, on February 14, 2020, and to fund a portion of the cash consideration for the acquisition of the Martinez refinery and related logistics assets (the “Martinez Acquisition”). The difference between the carrying value of the 2023 Senior Notes on the date they were reacquired and the amount for which they were reacquired has been classified as loss on extinguishment of debt in the Consolidated Statements of Operations. The 2028 Senior Notes included a registration rights arrangement whereby the Issuer and the Guarantors agreed to file with the U.S. Securities and Exchange Commission and use commercially reasonable efforts to consummate an offer to exchange the 2028 Senior Notes for an issue of registered notes with terms substantially identical to the notes not later than 365 days after the date of the original issuance of the notes. This registration statement was declared effective on October 14, 2020 and the exchange was consummated during the fourth quarter of 2020. As such, the Company did not have to transfer any consideration as a result of the registration rights agreement and thus no loss contingency was recorded. The 2028 Senior Notes are guaranteed on a senior unsecured basis by substantially all of PBF Holding’s subsidiaries. The 2028 Senior Notes and guarantees are senior unsecured obligations and rank equal in right of payment with all of the Issuers’ and the Guarantors’ existing and future indebtedness, including the Revolving Credit Facility, the 2025 Senior Notes and the 2025 Senior Secured Notes. The 2028 Senior Notes and the guarantees rank senior in right of payment to the Issuers’ and the Guarantors’ existing and future indebtedness that is expressly subordinated in right of payment thereto. The 2028 Senior Notes and the guarantees are effectively subordinated to any of the Issuers’ and the Guarantors’ existing or future secured indebtedness (including the Revolving Credit Facility) to the extent of the value of the collateral securing such indebtedness. The 2028 Senior Notes and the guarantees are structurally subordinated to any existing or future indebtedness and other obligations of the Issuers’ non-guarantor subsidiaries. In addition, the 2028 Senior Notes contain customary terms, events of default and covenants for an issuer of non-investment grade debt securities. These covenants include limitations on the incurrence of additional indebtedness, equity issuances, and payments. Many of these covenants will cease to apply or will be modified if the 2028 Senior Notes are rated investment grade. At any time prior to February 15, 2023, the Issuers may on any one or more occasions redeem up to 35% of the aggregate principal amount of the 2028 Senior Notes in an amount not greater than the net cash proceeds of certain equity offerings at a redemption price equal to 106.000% of the principal amount of the 2028 Senior Notes, plus any accrued and unpaid interest through the date of redemption. On or after February 15, 2023, the Issuers may redeem all or part of the 2028 Senior Notes, in each case at the redemption prices described in the indenture, together with any accrued and unpaid interest through the date of redemption. In addition, prior to February 15, 2023, the Issuers may redeem all or part of the 2028 Senior Notes at a “make-whole” redemption price described in the indenture, together with any accrued and unpaid interest through the date of redemption. During 2022, the Company made a number of open market repurchases of its 2028 Senior Notes that resulted in the extinguishment of $24.9 million in principal. Total cash consideration paid to repurchase the principal amount outstanding of the 2028 Senior Notes, excluding accrued interest, totaled $21.1 million and the Company recognized a $3.6 million gain on the extinguishment of debt during the year ended December 31, 2022. During 2021, the Company made a number of open market repurchases of its 2028 Senior Notes that resulted in the extinguishment of $173.5 million in principal. Total cash consideration paid to repurchase the principal amount outstanding of the 2028 Senior Notes, excluding accrued interest, totaled $109.3 million and the Company recognized a $62.4 million gain on the extinguishment of debt during the year ended December 31, 2021. 2025 Senior Notes On May 30, 2017, PBF Holding entered into an indenture among Issuers, the Guarantors, Wilmington Trust, National Association, as Trustee, and Deutsche Bank Trust Company Americas, as Paying Agent, Registrar, Transfer Agent and Authenticating Agent, under which the Issuers issued $725.0 million in aggregate principal amount of 7.25% 2025 Senior Notes. The Issuers received net proceeds of approximately $711.6 million from the offering after deducting the initial purchasers’ discount and offering expenses, all of which was used to fund the cash tender offer (the “Tender Offer”) for any and all of its outstanding 8.25% Senior Secured Notes due 2020 (the “2020 Senior Secured Notes”), to pay the related redemption price and accrued and unpaid interest for any 2020 Senior Secured Notes which remained outstanding after the completion of the Tender Offer, and for general corporate purposes. The 2025 Senior Notes are guaranteed by substantially all of PBF Holding’s subsidiaries. The 2025 Senior Notes and guarantees are senior unsecured obligations which rank equal in right of payment with all of the Issuers’ and the Guarantors’ existing and future senior indebtedness, including the Revolving Credit Facility, the 2028 Senior Notes and the 2025 Senior Secured Notes. The 2025 Senior Notes and the guarantees rank senior in right of payment to the Issuers’ and the Guarantors’ existing and future indebtedness that is expressly subordinated in right of payment thereto. The 2025 Senior Notes and the guarantees are effectively subordinated to any of the Issuers’ and the Guarantors’ existing or future secured indebtedness (including the Revolving Credit Facility) to the extent of the value of the collateral securing such indebtedness. The 2025 Senior Notes and the guarantees are structurally subordinated to any existing or future indebtedness and other obligations of the Issuers’ non-guarantor subsidiaries. PBF Holding has optional redemption rights to repurchase all or a portion of the 2025 Senior Notes at varying prices which are no less than 100% of the principal amount plus accrued and unpaid interest. The holders of the 2025 Senior Notes have repurchase options exercisable only upon a change in control, certain asset sale transactions, or in event of a default as defined in the indenture. In addition, the 2025 Senior Notes contain customary terms, events of default and covenants for an issuer of non-investment grade debt securities that limit certain types of additional debt, equity issuances, and payments. Many of these covenants will cease to apply or will be modified if the 2025 Senior Notes are rated investment grade. During 2022, the Company made a number of open market repurchases of its 2025 Senior Notes that resulted in the extinguishment of $5.0 million in principal. Total cash consideration paid to repurchase the principal amount outstanding of the 2025 Senior Notes, excluding accrued interest, totaled $4.8 million and the Company recognized a $0.2 million gain on the extinguishment of debt during the year ended December 31, 2022. During 2021, the Company made a number of open market repurchases of its 2025 Senior Notes that resulted in the extinguishment of $55.5 million in principal. Total cash consideration paid to repurchase the principal amount outstanding of the 2025 Senior Notes, excluding accrued interest, totaled $37.5 million and the Company recognized a $17.5 million gain on the extinguishment of debt during the year ended December 31, 2021. 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 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. 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. 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. On February 18, 2020, in connection with its entry into a $300.0 million uncommitted receivables purchase facility (the “Receivables Facility”), the Company amended the Revolving Credit Agreement and entered into a related intercreditor agreement to allow it to sell certain Eligible Receivables (as defined in the Revolving Credit Agreement) derived from the sale of refined product over truck racks. Under the Receivables Facility, the Company sells such receivables to a bank subject to bank approval and certain conditions. The sales of receivables under the Receivables Facility are absolute and irrevocable but subject to certain repurchase obligations under certain circumstances. On May 7, 2020, the Company further amended the Revolving Credit Facility, to increase PBF Holding’s ability to incur certain secured debt from an amount equal to 10% of its total assets to 20% of its total assets. There were no outstanding borrowings under the Revolving Credit Facility as of December 31, 2022. Outstanding borrowings as of December 31, 2021 was $900.0 million. Issued letters of credit were $576.1 million and $380.1 million, as of December 31, 2022 and 2021, respectively. Precious Metal Catalyst Financing Arrangements Certain subsidiaries of the Company have entered into agreements whereby such subsidiary sold a portion of its precious metal catalysts to a major commercial bank and subsequently refinanced the precious metal catalysts under contractual arrangements. The volume of the precious metal catalysts and the interest rate are fixed over the term of each financing arrangement. At maturity, the Company must repurchase the applicable precious metal catalysts, or otherwise settle its obligation with the counterparty, at its then fair market value. The Company believes that there is a market for precious metal catalysts and that it will attempt to release such catalysts at maturity. The Company treated these transactions as financing arrangements, and the related payments are recorded as interest expense over the agreements’ terms. 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 value of the underlying precious metal catalysts. The fair value of these repurchase obligations as reflected in the fair value of long-term debt outstanding table below is measured using Level 2 inputs. Details of the catalyst financing arrangements at each of the Company’s refineries as of December 31, 2022 are included in the following table: Refinery Metal Annual interest rate Expiration date (1) Delaware City Palladium 4.60 % September 2023 __________________ (1) This catalyst financing arrangement is included in Long-term debt as of December 31, 2022 as the Company has the ability and intent to finance this debt through availability under other credit facilities if the catalyst financing arrangement is not renewed at maturity. In total, aggregate annual catalyst financing fees were approximately $0.2 million and $2.0 million as of December 31, 2022 and 2021, respectively. Debt Maturities Debt maturing in the next five years and thereafter is as follows (in millions): Year Ending December 31, 2023 $ 4.0 2024 — 2025 664.5 2026 — 2027 — Thereafter 801.6 Total debt outstanding $ 1,470.1

OTHER LONG-TERM LIABILITIES

OTHER LONG-TERM LIABILITIES	12 Months Ended
	Dec. 31, 2022
Other Liabilities Disclosure [Abstract]
OTHER LONG-TERM LIABILITIES	OTHER LONG-TERM LIABILITIES Other long-term liabilities consisted of the following: (in millions) December 31, 2022 December 31, 2021 Environmental liabilities $ 141.5 $ 141.0 Defined benefit pension plan liabilities 82.2 46.7 Contingent consideration 65.7 29.4 Deferred Compensation 50.5 — Post-retirement medical plan liabilities 13.9 18.2 Early railcar return liability 1.9 6.0 Other 15.4 9.7 Total other long-term liabilities $ 371.1 $ 251.0

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2022
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONS 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 announced their intention to acquire all of the publicly held common units in PBFX representing limited partner interests in the 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 Merger Transaction closed on November 30, 2022 and PBFX became an indirect wholly-owned subsidiary of PBF Energy and PBF LLC. At the effective time of the Merger, pursuant to the terms of the Merger Agreement, each PBFX Public Common Unit was converted into the right to receive: (i) 0.27 of a share of Class A Common Stock, par value $0.001 per share, of PBF Energy, (ii) $9.25 in cash, without interest, and (iii) any cash in lieu of fractional shares of PBF Energy Common Stock to which the holder thereof became entitled upon surrender of such PBFX Public Common Units in accordance with the Merger Agreement. Such Merger Agreement consideration totaled $303.7 million in cash and resulted in the issuance of 8,864,684 PBF Energy common shares. The PBFX Common Units owned by PBF LLC and PBFX Holdings and the non-economic general partner interest remain outstanding and were unaffected by the Merger. There was no change in ownership of the non-economic general partner interest. Transactions and Agreements with PBFX PBF Holding 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 (as defined in the table below, and collectively referred to as the “Contribution Agreements”), PBF Holding 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 PBF Holding. There were no agreements entered into during the years ended December 31, 2022, 2021 and 2020. Commercial Agreements with PBFX PBF Holding has entered into long-term, fee-based commercial agreements with PBFX relating to assets associated with the Contribution Agreements described above, 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 PBF Holding and PBF Holding has committed to provide PBFX with minimum fees based on minimum monthly throughput volumes. PBF Holding believes the terms and conditions under these agreements, as well as the Omnibus Agreement (as defined below) and the Services Agreement (as defined below) each 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 years ended December 31, 2021 and 2020. The commercial agreements entered into during the year ended December 31, 2022 (as defined in the table below) with PBFX include: Agreements Initiation Date Initial Term Renewals (a) MVC Force Majeure Transportation and Terminaling Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility (b) 12/12/2014 10 years 2 x 5 4,400 bpd PBF Holding or PBFX can declare Delaware Pipeline Services Agreement 5/15/2015 10 years, 8 months 2 x 5 50,000 bpd Delaware Pipeline Services Agreement- Magellan Connection 11/1/2016 2 years, 5 months See note (c) See note (c) Delaware City Truck Loading Services Agreement- Gasoline 5/15/2015 10 years, 8 months 2 x 5 30,000 bpd Delaware City Truck Loading Services Agreement- LPGs 5/15/2015 10 years, 8 months 2 x 5 5,000 bpd East Coast Terminals Terminaling Services Agreements (d) 5/1/2016 Various (e) Evergreen 15,000 bpd (f) East Coast Terminals Tank Lease Agreements 5/1/2016 Various (e) Evergreen 350,000 barrels (g) Torrance Valley Pipeline Transportation Services Agreement- North Pipeline (b) 8/31/2016 10 years 2 x 5 50,000 bpd Torrance Valley Pipeline Transportation Services Agreement- South Pipeline (b) 8/31/2016 10 years 2 x 5 75,000 bpd (h) Torrance Valley Pipeline Transportation Services Agreement- Midway Storage Tank (b) 8/31/2016 10 years 2 x 5 55,000 barrels (g) Torrance Valley Pipeline Transportation Services Agreement- Emidio Storage Tank (b) 8/31/2016 10 years 2 x 5 900,000 barrels per month Torrance Valley Pipeline Transportation Services Agreement- Belridge Storage Tank (b) 8/31/2016 10 years 2 x 5 770,000 barrels per month Paulsboro Natural Gas Pipeline Services Agreement (b) 8/4/2017 15 years Evergreen 60,000 dekatherms per day Knoxville Terminals Agreement- Terminaling Services 4/16/2018 5 years Evergreen Various (i) Knoxville Terminals Agreement- Storage Services 4/16/2018 5 years Evergreen 115,334 barrels (g) Toledo Rail Loading Agreement (b) 7/31/2018 7 years, 5 months 2 x 5 Various (j) Chalmette Terminal Throughput Agreement 7/31/2018 1 year Evergreen N/A Chalmette Rail Unloading Agreement 7/31/2018 7 years, 5 months 2 x 5 7,600 bpd DSL Ethanol Throughput Agreement (b) 7/31/2018 7 years, 5 months 2 x 5 5,000 bpd Delaware City Terminaling Services Agreement 1/1/2022 4 years 2 x 5 95,000 bpd Toledo Truck Unloading & Terminaling Agreement (b) 4/1/2022 9 months Evergreen See note (k) Storage Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility (b) 12/12/2014 10 years 2 x 5 3,849,271 barrels (g) PBF Holding or PBFX can declare Chalmette Storage Agreement (b) See note (l) 10 years 2 x 5 625,000 barrels (g) East Coast Storage Assets Terminal Storage Agreement (b) 1/1/2019 8 years Evergreen 2,953,725 barrels (g) ____________________ (a) PBF Holding has the option to extend the agreements for up to two additional five-year terms, as applicable. (b) These commercial agreements with PBFX are considered leases. (c) In connection with the inclusion of an additional destination at the Magellan connection under the Delaware Pipeline Services Agreement, PBF Holding and Delaware Pipeline Company LLC agreed to a two-year, five-month MVC (the “Magellan MVC”) under the Delaware Pipeline Services Agreement. The Magellan MVC expired on March 31, 2019, subsequent to which PBFX has been billing actual throughput on the Magellan connection. (d) Subsequent to the PBFX acquisition of the Toledo, Ohio refined products terminal assets (the “Toledo Products Terminal”), the Toledo Products Terminal was added to the East Coast Terminals Terminaling Services Agreements. (e) The East Coast Terminals related party agreements include varying initial term lengths, ranging from one (f) The East Coast Terminals Terminaling Services Agreements have no MVCs and are billed based on actual volumes throughput, other than a terminaling services agreement between PBFX’s East Coast Terminals’ Paulsboro, New Jersey location and PBF Holding’s Paulsboro refinery with a 15,000 bpd MVC. (g) Reflects the overall capacity as stipulated by the storage agreement. The storage MVC is subject to the effective operating capacity of each tank, which can be impacted by routine tank maintenance and other factors. PBF Holding’s available shell capacity may be subject to change as agreed to by PBF Holding and PBFX. (h) In connection with the acquisition of Torrance Valley Pipeline Company LLC on May 31, 2019, the Torrance Valley Pipeline Transportation Services Agreement- South Pipeline was amended and restated to increase the MVC from 70,000 bpd to 75,000 bpd. (i) The minimum throughput revenue commitment for the Knoxville Terminals Agreement- Terminaling Services is $0.9 million for year one, $1.8 million for year two and $2.7 million for year three and thereafter. (j) Under the Toledo Rail Loading Agreement, PBF Holding has minimum throughput commitments for (i) 30 railcars per day of products and (ii) 11.5 railcars per day of premium products. The Toledo Rail Loading Agreement also specifies a maximum throughput rate of 50 railcars per day. (k) The Toledo Truck Unloading & Terminaling Agreement MVC was 5,500 bpd through December 31, 2022. Effective January 1, 2023, the MVC decreased to 1,000 bpd. (l) The Chalmette Storage Services Agreement was entered into on February 15, 2017 and commenced on November 1, 2017. Omnibus Agreement In addition to the commercial agreements described above, PBF Holding entered into an omnibus agreement with PBFX, PBF GP and PBF LLC, which has been amended and restated in connection with certain of the Contribution Agreements with PBFX, PBF GP and PBF LLC (as amended, the “Omnibus Agreement”) for the provision of executive management services and support for accounting and finance, legal, human resources, information technology, environmental, health and safety, and other administrative functions, as well as (i) PBF LLC’s agreement not to compete with PBFX under certain circumstances, subject to certain exceptions, (ii) PBFX’s right of first offer for ten years to acquire certain logistics assets retained by PBF Energy following the PBFX Offering, including certain logistics assets that PBF LLC or its subsidiaries may construct or acquire in the future, subject to certain exceptions, and (iii) a license to use the PBF Logistics trademark and name. The annual fee under the Omnibus Agreement for the year ended December 31, 2022 was $8.3 million, inclusive of obligations under the Omnibus Agreement to reimburse PBF Holding for certain compensation and benefit costs of employees who devoted more than 50% of their time to PBFX for the year ended December 31, 2022. The Company currently estimates to receive an annual fee of $8.3 million, inclusive of estimated obligations under the Omnibus Agreement to reimburse PBF Holding for certain compensation and benefit costs of employees who devote more than 50% of their time to PBFX for the year ending December 31, 2023. Services Agreement Additionally, PBF Holding and certain of its subsidiaries entered into an operation and management services and secondment agreement with PBFX (as amended, the “Services Agreement”), pursuant to which PBF Holding and its subsidiaries provide PBFX with the personnel necessary for PBFX to perform its obligations under the commercial agreements. PBFX reimburses PBF Holding 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. For the year ended December 31, 2022, PBFX paid an annual fee of $8.7 million to PBF Holding pursuant to the Services Agreement and is estimated to pay the same annual fee to PBF Holding pursuant to the Services Agreement for the year ending December 31, 2022. The Services Agreement will terminate upon the termination of the Omnibus Agreement, provided that PBFX may terminate any service on 30-days’ notice. Summary of Transactions with PBFX A summary of our affiliate transactions with PBFX is as follows: Year Ended December 31, (in millions) 2022 2021 2020 Reimbursements under affiliate agreements: Services Agreement $ 8.7 $ 8.7 $ 8.7 Omnibus Agreement 8.3 7.3 7.6 Total expenses under affiliate agreements 319.6 304.1 289.4 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 statements of operations.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES Other Commitments In addition to commitments related to lease obligations accounted for in accordance with Accounting Standards Codification (“ASC”) 842, Leases and disclosed in “Note 12 - Leases”, the Company is party to third party agreements which provide for the treatment of wastewater and the supply of hydrogen, nitrogen, oxygen, chemical, and steam for certain of its refineries as well as minimum volume commitments under certain affiliate agreements with PBFX. The fixed and determinable amounts related to obligations under these agreements are as follows: Year Ending December 31, (in millions) 2023 $ 152.6 2024 119.0 2025 114.7 2026 21.7 2027 21.7 Thereafter 186.2 Total obligations $ 615.9 Employment Agreements The Company has entered into various employment agreements with members of executive management and certain other key personnel that include automatic annual renewals, unless canceled. Under some of the agreements, certain of the executives would receive a lump sum payment of between 1.50 to 2.99 times their base salary and continuation of certain employee benefits for the same period upon termination by the Company “Without Cause”, or by the employee “For Good Reason”, or upon a “Change in Control”, as defined in the agreements. Upon death or disability, certain of the Company’s executives, or their estates, would receive a lump sum payment of at least one half of their base salary. 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 $117.0 million as of December 31, 2022 ($118.5 million as of December 31, 2021) 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 The aggregate environmental liability reflected in the Company’s Consolidated Balance Sheets was $155.6 million and $155.3 million at December 31, 2022 and December 31, 2021, respectively, of which $141.5 million and $141.0 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. Applicable Federal and State Regulatory Requirements The Company’s operations and many of the products it manufactures are subject to certain specific requirements of the Clean Air Act (the “CAA”) and related state and local regulations. The CAA contains provisions that require capital expenditures for the installation of certain air pollution control devices at the Company’s refineries. Subsequent rule making authorized by the CAA or similar laws or new agency interpretations of existing rules, may necessitate additional expenditures in future years. The Company is required to comply with the RFS. Pursuant to the Energy Policy Act of 2005 and the Energy Independence and Security Act of 2007, EPA has issued the RFS, implementing mandates to blend renewable fuels into the petroleum fuels produced and sold in the United States. Under the RFS, the volume of renewable fuels that obligated refineries must blend into their finished petroleum fuels historically has increased on an annual basis. In addition, certain states have passed legislation that requires minimum biodiesel blending in finished distillates. On October 13, 2010, EPA raised the maximum amount of ethanol allowed under federal law from 10% to 15% for cars and light trucks manufactured since 2007. The maximum amount allowed under federal law currently remains at 10% ethanol for all other vehicles. Existing laws and regulations could change, and the minimum volumes of renewable fuels that must be blended with refined petroleum fuels may increase. Because we do not currently produce renewable fuels, increasing the volume of renewable fuels that must be blended into our products displaces an increasing volume of our refinery’s product pool, potentially resulting in lower earnings and profitability. In addition, in order to meet certain of these and future EPA requirements, we may be required to purchase RINs, which may have fluctuating costs based on market conditions. Our RINs purchase obligation is dependent on our actual shipment of on-road transportation fuels domestically and the amount of blending achieved which can cause variability in our profitability. On June 3, 2022, EPA finalized the volumes of renewable fuels that obligated refineries must blend into their final petroleum fuels for years 2020, 2021 and 2022. On December 1, 2022, EPA proposed volume requirements and percentage standards under the RFS program for 2023, 2024, and 2025, as well as making a series of .important modifications to strengthen and expand the RFS program. As a result, we could also experience fluctuating compliance costs in the future if the volumes finalized by EPA differ from what has been proposed. EPA published a Final Rule to the Clean Water Act Section 316(b) in August 2014 regarding cooling water intake structures, which includes requirements for petroleum refineries. The purpose of this rule is to prevent fish from being trapped against cooling water intake screens (impingement) and to prevent fish from being drawn through cooling water systems (entrainment). Facilities will be required to implement best technology available as soon as possible, but state agencies have the discretion to establish implementation time lines. The Company has evaluated, and continues to evaluate, the impact of this regulation, and at this time does not expect this regulation to materially impact the Company’s financial position, results of operations or cash flows. The Company is subject to greenhouse gas emission control regulations in the state of California pursuant to AB 32. AB 32 imposes a statewide cap on greenhouse gas emissions, including emissions from transportation fuels, with the aim of returning the state to 1990 emission levels by 2020. AB 32 is implemented through two market mechanisms including the Low Carbon Fuel Standard (“LCFS”) and Cap and Trade. The Company is responsible for the AB 32 obligations related to the Torrance refinery beginning on July 1, 2016 and the Martinez refinery beginning on February 1, 2020 and must purchase emission credits to comply with these obligations. Additionally, in September 2016, the state of California enacted Senate Bill 32 (“SB 32”) which further reduces greenhouse gas emissions targets to 40 percent below 1990 levels by 2030. California Air Resources Board also amended the LCFS in 2018 to require a 20% reduction by 2030. The Company recovers the majority of these costs from its customers, and does not expect these obligations to materially impact the Company’s financial position, results of operations, or cash flows. To the degree there are unfavorable changes to AB 32 or SB 32 regulations or the Company is unable to recover such compliance costs from customers, these regulations could have a material adverse effect on our financial position, results of operations and cash flows. The Company is subject to obligations to purchase RINs. On February 15, 2017, the Company received a notification that EPA records indicated that PBF Holding used potentially invalid RINs that were in fact verified under EPA’s RIN Quality Assurance Program (“QAP”) by an independent auditor as QAP A RINs. Under the regulations, use of potentially invalid QAP A RINs provided the user with an affirmative defense from civil penalties provided certain conditions are met. The Company has asserted the affirmative defense and if accepted by EPA will not be required to replace these RINs and will not be subject to civil penalties under the program. It is reasonably possible that EPA will not accept the Company’s defense and may assess penalties in these matters but any such amount is not expected to have a material impact on the Company’s financial position, results of operations or cash flows. As of January 1, 2011, the Company is required to comply with EPA’s Control of Hazardous Air Pollutants From Mobile Sources, or MSAT2, regulations on gasoline that impose reductions in the benzene content of its produced gasoline. The Company purchases benzene credits to meet these requirements when necessary. The Company may implement capital projects to reduce the amount of benzene credits that the Company needs to purchase. In additions, the RFS mandate the blending of prescribed percentages of renewable fuels (e.g., ethanol and biofuels) into the Company’s produced gasoline and diesel. These requirements, other requirements of the CAA and other presently existing or future environmental regulations may cause the Company to make substantial capital expenditures as well as the purchase of credits at significant cost, to enable its refineries to produce products that meet applicable requirements. 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 the Company’s sites are subject to these laws and the Company 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 the Company’s current normal operations, it has 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. The Company is also currently subject to certain other existing environmental claims and proceedings. The Company believes that it is unlikely that future costs related to any of these other known contingent liability exposures would have a material impact on its financial position, results of operations or cash flows. Contingent Consideration In connection with the Martinez Acquisition, the Sale and Purchase Agreement dated June 11, 2019 includes an earn-out provision based on certain earnings thresholds of the Martinez refinery. Pursuant to the agreement, the Company will make payments to the 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”). The Company recorded the 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 Consolidated Balance Sheets. Subsequent changes in the fair value of the Martinez Contingent Consideration are recorded in the Consolidated Statements of Operations. The fair value of the Martinez Contingent Consideration was estimated to be $147.3 million as of December 31, 2022 (of which $81.6 million is included within Accrued expenses) and $29.4 million as of December 31, 2021 (all of which was included within Other long-term liabilities) on the Company’s Consolidated Balance Sheets. Tax Receivable Agreement PBF Energy (the Company’s indirect parent) entered into a tax receivable agreement with the PBF LLC Series A and PBF LLC Series B unitholders (the “Tax Receivable Agreement”) that provides for the payment by PBF Energy to such persons of an amount equal to 85% of the amount of the benefits, if any, that PBF Energy is deemed to realize as a result of (i) increases in tax basis, as described below, and (ii) certain other tax benefits related to entering into the Tax Receivable Agreement, including tax benefits attributable to payments under the Tax Receivable Agreement. For purposes of the Tax Receivable Agreement, the benefits deemed realized by PBF Energy will be computed by comparing the actual income tax liability of PBF Energy (calculated with certain assumptions) to the amount of such taxes that PBF Energy would have been required to pay had there been no increase to the tax basis of the assets of PBF LLC as a result of purchases or exchanges of PBF LLC Series A Units for shares of PBF Energy Class A common stock and had PBF Energy not entered into the Tax Receivable Agreement. The term of the Tax Receivable Agreement will continue until all such tax benefits have been utilized or expired unless: (i) PBF Energy exercises its right to terminate the Tax Receivable Agreement, (ii) PBF Energy breaches any of its material obligations under the Tax Receivable Agreement or (iii) certain changes of control occur, in which case all obligations under the Tax Receivable Agreement will generally be accelerated and due as calculated under certain assumptions. The payment obligations under the Tax Receivable Agreement are obligations of PBF Energy and not of PBF LLC or PBF Holding. In general, PBF Energy expects to obtain funding for these annual payments from PBF LLC, primarily through tax distributions, which PBF LLC makes on a pro-rata basis to its owners. Such owners include PBF Energy, which holds a 99.3% interest in PBF LLC as of December 31, 2022 (99.2% as of December 31, 2021). PBF LLC generally obtains funding to pay its tax distributions by causing PBF Holding to distribute cash to PBF LLC and from distributions it receives from PBFX. As of December 31, 2022 PBF Energy recognized $338.6 million liability for the Tax Receivable Agreement obligation, reflecting the estimate of the undiscounted amounts that PBF Energy expects to pay under the agreement, net of the impact of any deferred tax asset valuation allowance recognized in accordance with ASC 470, Income Taxes ( $48.3 million as of December 31, 2021).

LEASES (Notes)

LEASES (Notes)	12 Months Ended
	Dec. 31, 2022
Leases [Abstract]
LEASES	LEASES Lease Position as of December 31, 2022 and December 31, 2021 The table below presents the lease related assets and liabilities recorded on the Company’s Consolidated Balance Sheets as of December 31, 2022 and December 31, 2021: (in millions) Classification on the Balance Sheet December 31, 2022 December 31, 2021 Assets Operating lease assets - third party Lease right of use assets - third party $ 610.9 $ 635.8 Operating lease assets - affiliate Lease right of use assets - affiliate 421.6 485.4 Finance lease assets Lease right of use assets - third party 67.4 81.2 Total lease right of use assets $ 1,099.9 $ 1,202.4 Liabilities Current liabilities: Operating lease liabilities - third party Current operating lease liabilities - third party $ 60.5 $ 64.8 Operating lease liabilities - affiliate Current operating lease liabilities - affiliate 104.5 90.7 Finance lease liabilities - third party Accrued expenses 11.7 11.1 Noncurrent liabilities: Operating lease liabilities - third party Long-term operating lease liabilities - third party 551.8 570.3 Operating lease liabilities - affiliate Long-term operating lease liabilities - affiliate 317.2 394.7 Finance lease liabilities - third party Long-term financing lease liabilities - third party 57.9 70.6 Total lease liabilities $ 1,103.6 $ 1,202.2 Lease Costs The table below presents certain information related to costs for the Company’s leases for the year ended December 31, 2022 and December 31, 2021: Lease Costs (in millions) December 31, 2022 December 31, 2021 Components of total lease costs: Finance lease costs Amortization of right of use assets $ 12.6 $ 16.1 Interest on lease liabilities 5.3 4.6 Operating lease costs 301.5 299.1 Short-term lease costs 88.0 59.3 Variable lease costs 52.4 31.6 Total lease costs $ 459.8 $ 410.7 Sale-leaseback Transactions On April 17, 2020, the Company closed on the sale of five hydrogen plants to Air Products in a sale-leaseback transaction for gross cash proceeds of $530.0 million and recognized a gain of $471.1 million. In connection with the sale, the Company entered into a transition services agreement through which Air Products will exclusively supply hydrogen, steam, carbon dioxide and other products (the “Products”) to the Martinez, Torrance and Delaware City refineries for a specified period (not expected to exceed 18 months). The transition services agreement also requires certain maintenance and operating activities to be provided by PBF Holding, for which the Company will be reimbursed, during the term of the agreement. In August 2020, the parties executed long-term supply agreements through which Air Products will supply the Products for a term of fifteen years at these same refineries. As a result of these transactions, the Company recorded lease right of use assets and corresponding operating lease liabilities of approximately $504.0 million. There were no net gains or losses on any sale-leaseback transactions for the year ended December 31, 2022. Other Information The table below presents supplemental cash flow information related to leases for the year ended December 31, 2022 and December 31, 2021 (in millions): Years Ended December 31, 2022 2021 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows for operating leases $ 300.5 $ 297.9 Operating cash flows for finance leases 5.3 4.6 Financing cash flows for finance leases 11.3 17.8 Supplemental non-cash quantification of assets acquired or remeasured under operating and financing leases 82.8 (106.6) Lease Term and Discount Rate The table below presents certain information related to the weighted average remaining lease term and weighted average discount rate for the Company’s leases as of December 31, 2022: Weighted average remaining lease term - operating leases 9.4 years Weighted average remaining lease term - finance leases 5.6 years Weighted average discount rate - operating leases 13.6 % Weighted average discount rate - finance leases 7.2 % Undiscounted Cash Flows The table below reconciles the fixed component of the undiscounted cash flows for each of the periods presented to the lease liabilities recorded on the Consolidated Balance Sheets as of December 31, 2022: Amounts due in the year ended December 31, (in millions) Finance Leases Operating Leases 2023 $ 16.1 $ 282.6 2024 15.5 262.4 2025 13.9 213.7 2026 13.6 176.8 2027 13.6 105.7 Thereafter 11.5 823.4 Total minimum lease payments 84.2 1,864.6 Less: effect of discounting 14.6 830.6 Present value of future minimum lease payments 69.6 1,034.0 Less: current obligations under leases 11.7 165.0 Long-term lease obligations $ 57.9 $ 869.0 As of December 31, 2022, the Company has entered into certain leases that have not yet commenced. Such leases include a 2-year lease for an oil tanker, with future lease payments estimated to total approximately $48.9 million. No other such pending leases, either individually or in the aggregate, are material. There are no material lease arrangements in which the Company is the lessor. seven
LEASES	LEASES Lease Position as of December 31, 2022 and December 31, 2021 The table below presents the lease related assets and liabilities recorded on the Company’s Consolidated Balance Sheets as of December 31, 2022 and December 31, 2021: (in millions) Classification on the Balance Sheet December 31, 2022 December 31, 2021 Assets Operating lease assets - third party Lease right of use assets - third party $ 610.9 $ 635.8 Operating lease assets - affiliate Lease right of use assets - affiliate 421.6 485.4 Finance lease assets Lease right of use assets - third party 67.4 81.2 Total lease right of use assets $ 1,099.9 $ 1,202.4 Liabilities Current liabilities: Operating lease liabilities - third party Current operating lease liabilities - third party $ 60.5 $ 64.8 Operating lease liabilities - affiliate Current operating lease liabilities - affiliate 104.5 90.7 Finance lease liabilities - third party Accrued expenses 11.7 11.1 Noncurrent liabilities: Operating lease liabilities - third party Long-term operating lease liabilities - third party 551.8 570.3 Operating lease liabilities - affiliate Long-term operating lease liabilities - affiliate 317.2 394.7 Finance lease liabilities - third party Long-term financing lease liabilities - third party 57.9 70.6 Total lease liabilities $ 1,103.6 $ 1,202.2 Lease Costs The table below presents certain information related to costs for the Company’s leases for the year ended December 31, 2022 and December 31, 2021: Lease Costs (in millions) December 31, 2022 December 31, 2021 Components of total lease costs: Finance lease costs Amortization of right of use assets $ 12.6 $ 16.1 Interest on lease liabilities 5.3 4.6 Operating lease costs 301.5 299.1 Short-term lease costs 88.0 59.3 Variable lease costs 52.4 31.6 Total lease costs $ 459.8 $ 410.7 Sale-leaseback Transactions On April 17, 2020, the Company closed on the sale of five hydrogen plants to Air Products in a sale-leaseback transaction for gross cash proceeds of $530.0 million and recognized a gain of $471.1 million. In connection with the sale, the Company entered into a transition services agreement through which Air Products will exclusively supply hydrogen, steam, carbon dioxide and other products (the “Products”) to the Martinez, Torrance and Delaware City refineries for a specified period (not expected to exceed 18 months). The transition services agreement also requires certain maintenance and operating activities to be provided by PBF Holding, for which the Company will be reimbursed, during the term of the agreement. In August 2020, the parties executed long-term supply agreements through which Air Products will supply the Products for a term of fifteen years at these same refineries. As a result of these transactions, the Company recorded lease right of use assets and corresponding operating lease liabilities of approximately $504.0 million. There were no net gains or losses on any sale-leaseback transactions for the year ended December 31, 2022. Other Information The table below presents supplemental cash flow information related to leases for the year ended December 31, 2022 and December 31, 2021 (in millions): Years Ended December 31, 2022 2021 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows for operating leases $ 300.5 $ 297.9 Operating cash flows for finance leases 5.3 4.6 Financing cash flows for finance leases 11.3 17.8 Supplemental non-cash quantification of assets acquired or remeasured under operating and financing leases 82.8 (106.6) Lease Term and Discount Rate The table below presents certain information related to the weighted average remaining lease term and weighted average discount rate for the Company’s leases as of December 31, 2022: Weighted average remaining lease term - operating leases 9.4 years Weighted average remaining lease term - finance leases 5.6 years Weighted average discount rate - operating leases 13.6 % Weighted average discount rate - finance leases 7.2 % Undiscounted Cash Flows The table below reconciles the fixed component of the undiscounted cash flows for each of the periods presented to the lease liabilities recorded on the Consolidated Balance Sheets as of December 31, 2022: Amounts due in the year ended December 31, (in millions) Finance Leases Operating Leases 2023 $ 16.1 $ 282.6 2024 15.5 262.4 2025 13.9 213.7 2026 13.6 176.8 2027 13.6 105.7 Thereafter 11.5 823.4 Total minimum lease payments 84.2 1,864.6 Less: effect of discounting 14.6 830.6 Present value of future minimum lease payments 69.6 1,034.0 Less: current obligations under leases 11.7 165.0 Long-term lease obligations $ 57.9 $ 869.0 As of December 31, 2022, the Company has entered into certain leases that have not yet commenced. Such leases include a 2-year lease for an oil tanker, with future lease payments estimated to total approximately $48.9 million. No other such pending leases, either individually or in the aggregate, are material. There are no material lease arrangements in which the Company is the lessor. seven

EQUITY STRUCTURE

EQUITY STRUCTURE	12 Months Ended
	Dec. 31, 2022
Equity [Abstract]
EQUITY STRUCTURE	EQUITY STRUCTURE PBF Holding has no common stock outstanding. As of December 31, 2022, 100% of the membership interests of PBF Holding were owned by PBF LLC, and PBF Finance had 100 shares of common stock outstanding, all of which were held by PBF Holding. The following sections represent the equity structure of the Company’s indirect and direct parents, PBF Energy and PBF LLC, respectively. PBF Energy Capital Structure PBF Energy Class A Common Stock Holders of Class A common stock are entitled to receive dividends when and if declared by the Board of Directors of PBF Energy out of funds legally available therefore, subject to any statutory or contractual restrictions on the payment of dividends and to any restrictions on the payment of dividends imposed by the terms of any outstanding preferred stock. Upon PBF Energy’s dissolution or liquidation or the sale of all or substantially all of the assets, after payment in full of all amounts required to be paid to creditors and to the holders of preferred stock having liquidation preferences, if any, the holders of shares of Class A common stock will be entitled to receive pro rata remaining assets available for distribution. Holders of shares of Class A common stock do not have preemptive, subscription, redemption or conversion rights. PBF Energy Class B Common Stock Holders of shares of Class B common stock are entitled, without regard to the number of shares of Class B common stock held by such holder, to one vote for each PBF LLC Series A Unit beneficially owned by such holder. Accordingly, the members of PBF LLC other than PBF Energy collectively have a number of votes in PBF Energy that is equal to the aggregate number of PBF LLC Series A Units that they hold. Holders of shares of Class A common stock and Class B common stock vote together as a single class on all matters presented to stockholders for their vote or approval, except as otherwise required by applicable law. Holders of Class B common stock do not have any right to receive dividends or to receive a distribution upon a liquidation or winding up of PBF Energy. PBF Energy Preferred Stock Authorized preferred stock may be issued in one or more series, with designations, powers and preferences as shall be designated by the Board of Directors. PBF LLC Capital Structure PBF LLC Series A Units The allocation of profits and losses and distributions to PBF LLC Series A unitholders is governed by the limited liability company agreement of PBF LLC. These allocations are made on a pro rata basis with PBF LLC Series C Units. PBF LLC Series A unitholders do not have voting rights. PBF LLC Series B Units The PBF LLC Series B Units are intended to be “profit interests” within the meaning of Revenue Procedures 93-27 and 2001-43 of the Internal Revenue Service (“IRS”) and have a stated value of zero at issuance. The PBF LLC Series B Units are held by certain of the Company’s current and former officers, have no voting rights and are designed to increase in value only after the Company’s financial sponsors achieve certain levels of return on their investment in PBF LLC Series A Units. Accordingly, the amounts paid to the holders of PBF LLC Series B Units, if any, will reduce only the amounts otherwise payable to the PBF LLC Series A Units held by the Company’s financial sponsors, and will not reduce or otherwise impact any amounts payable to PBF Energy (the holder of PBF LLC Series C Units), the holders of PBF Energy’s Class A common stock or any other holder of PBF LLC Series A Units. The maximum number of PBF LLC Series B Units authorized to be issued is 1,000,000. PBF LLC Series C Units The PBF LLC Series C Units rank on a parity with the PBF LLC Series A Units as to distribution rights, voting rights and rights upon liquidation, winding up or dissolution. PBF LLC Series C Units are held solely by PBF Energy. Noncontrolling Interest

STOCK-BASED COMPENSATION

STOCK-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2022
Share-Based Payment Arrangement [Abstract]
STOCK-BASED COMPENSATION	STOCK-BASED COMPENSATION Stock-based compensation expense included in general and administrative expenses consisted of the following: Years Ended December 31, (in millions) 2022 2021 2020 PBF Energy options $ 19.1 $ 17.3 $ 16.1 PBF Energy restricted shares 11.6 2.8 5.3 PBF Energy performance awards 13.4 10.2 7.9 $ 44.1 $ 30.3 $ 29.3 PBF Energy options PBF Energy grants stock o ptions which represent the right to purchase share of PBF Energy’s common stock at its fair market value, which is the closing price of PBF Energy’s common stock on the date of grant. Stock options have a maximum term of ten years from the date they are granted, and vest over a requisite service period of three years, or four years for grants prior to November 2020, subject to acceleration in certain circumstances. The Company uses the Black-Scholes option-pricing model to estimate the fair value of stock options granted, which requires the input of subjective assumptions. The Black-Scholes option-pricing model values used to value stock option awards granted were determined based on the following weighted average assumptions: December 31, 2022 December 31, 2021 December 31, 2020 Expected life (in years) 6.00 6.00 6.08 Expected volatility 87.6 % 83.8 % 69.1 % Dividend yield 0.00 % 0.00 % 1.41 % Risk-free rate of return 3.24 % 1.37 % 0.81 % Exercise price $ 29.16 $ 13.91 $ 13.58 Weighted average fair value per option granted $ 21.68 $ 9.84 $ 5.49 The following table summarizes activity for PBF Energy options for 2022: Number of Weighted Weighted Stock-based awards, outstanding at January 1, 2022 15,049,759 $ 24.48 6.51 Granted 22,000 29.16 10.00 Exercised (4,208,685) 24.54 — Forfeited (210,800) 22.65 — Outstanding at December 31, 2022 10,652,274 $ 24.50 5.96 Exercisable and vested at December 31, 2022 7,826,241 $ 27.01 5.26 Total expected to vest as of December 31, 2022 10,652,274 $ 24.50 5.96 At December 31, 2022 the total intrinsic value of stock options outstanding and exercisable were $173.5 million and $107.8 million, respectively. The total intrinsic value of stock options exercised during the years ended December 31, 2022, 2021 and 2020 was $63.1 million, $0.4 million and $0.0 million, respectively. Unrecognized compensation expense related to PBF Energy options at December 31, 2022 was $17.3 million, which will be recognized from 2023 through 2025. Restricted Stock Awards The Company grants restricted stock to employees and non-employee directors. In general, restricted stock granted to our employees vest over a requisite services period of three years, subject to acceleration in certain circumstances. Restricted stock recipients who received grants subsequent to May 2017 have voting rights; however, dividends are accrued and will be paid upon vesting. Restricted stock units granted to non-employee directors are considered to vest immediately at the time of the grant for accounting purposes, as they are non-forfeitable, but are issued in equal annual installments on each of the first three anniversaries of the grant date. The non-vested shares are not transferable and are held by our transfer agent. The fair values of restricted stock are equal to the market price of our common stock on the grant date. The following table summarizes activity for PBF Energy restricted stock: Number of Weighted Average Nonvested at January 1, 2022 155,687 $ 16.09 Granted 659,165 35.73 Vested (109,402) 19.42 Forfeited — — Nonvested at December 31, 2022 705,450 $ 33.92 Unrecognized compensation expense related to PBF Energy Restricted Class A common stock at December 31, 2022 was $12.0 million, which will be recognized from 2023 through 2025. The following table reflects activity related to our restricted stock: December 31, 2022 December 31, 2021 December 31, 2020 Weighted-average grant-date fair value per share of restricted stock granted $ 35.73 $ 16.13 $ 9.82 Fair value of restricted stock vested (in millions) $ 3.3 $ 3.1 $ 4.2 Performance Awards The Company grants performance share awards, which are paid in stock, and performance share unit awards, which are paid in cash, (collectively, the “performance awards”) to certain key employees. Performance awards granted to employees prior to November 1, 2020 are based on a three-year performance cycle (the “performance cycle”) with four measurement periods, and performance awards granted to employees after November 1, 2020, are based on a three-year performance cycle having a single measurement period. The performance awards will vest on the last day of the performance cycle, subject to forfeiture or acceleration under certain circumstances set forth in the award agreement. The number of performance awards that will ultimately vest is based on the Company’s total shareholder return over the performance cycle. The number of shares ultimately issued or cash paid under these awards can range from zero to 200% of target award amounts. Performance Share Unit Awards The performance share unit awards are accounted for as equity awards, for which the fair value was determined on the grant date by application of a Monte Carlo valuation model. The grant date fair value was calculated using a Monte Carlo valuation model with the following assumptions: December 31, 2022 December 31, 2021 December 31, 2020 Expected life (in years) 3.08 3.12 2.89 - 3.14 Expected volatility 65.16 % 83.78% 39.88% - 82.63% Dividend yield 2.18 % 0.00% 0.00% - 4.28% Risk-free rate of return 3.90 % 0.87% 0.26% - 1.34% Weighted average grant-date fair value per PSU $ 45.91 $ 18.73 $ 10.77 The risk-free interest rate for the remaining performance period as of the grant date is based on a linear interpolation of published yields of traded U.S. Treasury Interest-Only STRIP Bonds. The dividend yield assumption is based on the annualized most recent quarterly dividend divided by the stock price on the grant date. The assumption for the expected volatility of the Company’s stock price reflects the average of PBF Energy’s common stock historical and implied volatility. The following table summarizes activity for PBF Energy performance share awards: Number of Weighted Average Nonvested at January 1, 2022 745,525 $ 13.93 Granted 190,463 45.91 Vested (37,784) 27.71 Forfeited (111,678) 13.92 Nonvested at December 31, 2022 786,526 $ 21.02 In 2022, 2021 and 2020, PSU’s with a fair value of $2.0 million, $1.8 million and $0.8 million, respectively, were vested. As of December 31, 2022, unrecognized compensation cost related to performance share unit awards was $13.3 million, which is expected to be recognized over a weighted average period of 2.55 years. Performance Unit awards The performance unit awards are dollar denominated with a target value of $1.00, with actual payout of up to $2.00 per unit (or 200 percent of target). The performance unit awards are settled in cash based on the payout amount determined at the end of the performance cycle. The Company accounts for the performance unit awards as liability awards which the Company recorded at fair market value on the date of grant. Subsequently, the performance unit awards will be marked-to-market at the end of each fiscal quarter by application of a Monte Carlo simulation model. The following table summarizes activity for PBF Energy performance unit awards: Number of Nonvested at January 1, 2022 20,178,013 Granted 15,614,603 Vested (1,231,770) Forfeited (3,105,896) Nonvested at December 31, 2022 31,454,950 In 2022, 2021 and 2020, Performance Units with a fair value of $1.5 million, $5.2 million and $3.2 million, respectively, were vested. As of December 31, 2022, unrecognized compensation cost related to performance unit awards was $21.5 million, which is expected to be recognized over a weighted average period of 2.28 years.

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	12 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
EMPLOYEE BENEFIT PLANS	EMPLOYEE BENEFIT PLANS Defined Contribution Plan The Company’s defined contribution plan covers all employees. Employees are eligible to participate as of the first day of the month following 30 days of service. Participants can make basic contributions up to 50 percent of their annual salary subject to IRS limits. The Company matches participants’ contributions at the rate of 200 percent of the first 3 percent of each participant’s total basic contribution based on the participant’s total annual salary. The Company’s contribution to the qualified defined contribution plans was $33.4 million, $27.8 million, and $32.7 million for the years ended December 31, 2022, 2021 and 2020, respectively. Defined Benefit and Post-Retirement Medical Plans The Company sponsors a noncontributory defined benefit pension plan (the “Qualified Plan”) with a policy to fund pension liabilities in accordance with the limits imposed by the Employee Retirement Income Security Act of 1974 and Federal income tax laws. In addition, the Company sponsors a supplemental pension plan covering certain employees, which provides incremental payments that would have been payable from the Company’s principal pension plan, were it not for limitations imposed by income tax regulations (the “Supplemental Plan”). The funded status is measured as the difference between plan assets at fair value and the projected benefit obligation which is to be recognized in the Consolidated Balance Sheets. The plan assets and benefit obligations are measured as of the Consolidated Balance Sheet date. The non-union Delaware City employees and all Paulsboro, Toledo, Chalmette, Torrance and Martinez employees became eligible to participate in the Company’s defined benefit plans as of the respective acquisition dates. The union Delaware City employees became eligible to participate in the Company’s defined benefit plans upon commencement of normal operations. The Company did not assume any of the employees’ pension liability accrued prior to the respective acquisitions. The Company formed the Post-Retirement Medical Plan on December 31, 2010 to provide health care coverage continuation from date of retirement to age 65 for qualifying employees associated with the Paulsboro acquisition. The Company credited the qualifying employees with their prior service under Valero Energy Corporation which resulted in the recognition of a liability for the projected benefit obligation. The Post-Retirement Medical Plan includes all corporate and refinery employees. The changes in the benefit obligation, the changes in fair value of plan assets, and the funded status of the Company’s Pension and Post-Retirement Medical Plans as of and for the years ended December 31, 2022 and 2021 were as follows: Pension Plans Post-Retirement (in millions) 2022 2021 2022 2021 Change in benefit obligation: Benefit obligation at beginning of year $ 353.3 $ 329.3 $ 18.2 $ 22.0 Service cost 55.6 57.5 0.8 1.1 Interest cost 7.9 5.3 0.3 0.3 Plan amendments — — — — Benefit payments (18.9) (31.2) (1.4) (1.2) Actuarial gain (40.9) (7.6) (4.0) (4.0) Projected benefit obligation at end of year $ 357.0 $ 353.3 $ 13.9 $ 18.2 Change in plan assets: Fair value of plan assets at beginning of year $ 306.3 $ 255.8 $ — $ — Actual return on plan assets (51.0) 27.7 — — Benefits paid (18.9) (31.2) (1.4) (1.2) Employer contributions 37.8 54.0 1.4 1.2 Fair value of plan assets at end of year $ 274.2 $ 306.3 $ — $ — Reconciliation of funded status: Fair value of plan assets at end of year $ 274.2 $ 306.3 $ — $ — Less benefit obligations at end of year 357.0 353.3 13.9 18.2 Funded status at end of year $ (82.8) $ (47.0) $ (13.9) $ (18.2) The accumulated benefit obligation for the defined benefit plans approximated $321.0 million and $298.9 million at December 31, 2022 and 2021, respectively. Benefit payments, which reflect expected future services that the Company expects to pay are as follows for the years ended December 31: (in millions) Pension Benefits Post-Retirement 2023 $ 25.7 $ 1.7 2024 21.3 1.5 2025 26.0 1.5 2026 29.4 1.5 2027 33.0 1.4 Years 2028-2032 207.8 6.3 The Company’s funding policy for its defined benefit plans is to contribute amounts sufficient to meet legal funding requirements, plus any additional amounts that may be appropriate considering the funded status of the plans, tax consequences, the cash flow generated by the Company and other factors. The Company plans to contribute approximately $33.6 million to the Company’s Pension Plans during 2023. The components of net periodic benefit cost were as follows for the years ended December 31, 2022, 2021 and 2020: Pension Benefits Post-Retirement (in millions) 2022 2021 2020 2022 2021 2020 Components of net periodic benefit cost: Service cost $ 55.6 $ 57.5 $ 59.0 $ 0.8 $ 1.1 $ 1.0 Interest cost 7.9 5.3 6.9 0.3 0.3 0.4 Expected return on plan assets (17.5) (14.2) (12.5) — — — Amortization of prior service cost and actuarial loss 0.1 0.1 0.3 0.4 0.7 0.6 Net periodic benefit cost $ 46.1 $ 48.7 $ 53.7 $ 1.5 $ 2.1 $ 2.0 Lump sum payments made by the Supplemental Plan to employees retiring in 2022, 2021 and 2020 did not exceed the Plan’s total service and interest costs expected for those years. The pre-tax amounts recognized in other comprehensive (income) loss for the years ended December 31, 2022, 2021, and 2020 were as follows: Pension Benefits Post-Retirement (in millions) 2022 2021 2020 2022 2021 2020 Prior service costs $ — $ — $ — $ — $ — $ 1.8 Net actuarial loss (gain) 27.6 (21.1) (5.9) (4.0) (4.0) 1.9 Amortization of losses and prior service cost (0.1) (0.1) (0.3) (0.4) (0.7) (0.6) Total changes in other comprehensive (income) loss $ 27.5 $ (21.2) $ (6.2) $ (4.4) $ (4.7) $ 3.1 The pre-tax amounts in accumulated other comprehensive income (loss) as of December 31, 2022 and 2021 that have not yet been recognized as components of net periodic costs were as follows: Pension Benefits Post-Retirement (in millions) 2022 2021 2022 2021 Prior service costs $ (0.5) $ (0.5) $ (3.5) $ (4.3) Net actuarial (loss) gain (14.8) 12.7 11.4 7.8 Total $ (15.3) $ 12.2 $ 7.9 $ 3.5 The weighted average assumptions used to determine the benefit obligations as of December 31, 2022 and 2021 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2022 2021 2022 2021 2022 2021 Discount rate - benefit obligations 5.22 % 2.78 % 5.24 % 2.73 % 5.15 % 2.46 % Rate of compensation increase 4.27 % 4.26 % 4.50 % 4.50 % — — The weighted average assumptions used to determine the net periodic benefit costs for the years ended December 31, 2022, 2021 and 2020 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2022 2021 2020 2022 2021 2020 2022 2021 2020 Discount rates: Effective rate for service cost 2.80% 2.40% 2.94% 2.73% 2.26% 2.79% 2.80% 2.35% 2.86% Effective rate for interest cost 2.33% 1.74% 2.50% 2.24% 1.53% 2.33% 1.91% 1.28% 2.21% Effective rate for interest on service cost 2.45% 1.92% 2.59% 2.29% 1.75% 2.42% 2.65% 2.11% 2.68% Cash balance interest credit rate 2.06% 1.57% 2.19% 2.06% 1.57% 2.19% N/A N/A N/A Expected long-term rate of return on plan assets 5.50% 5.25% 5.75% N/A N/A N/A N/A N/A N/A Rate of compensation increase 4.26% 4.28% 4.28% 4.50% 4.50% 4.50% N/A N/A N/A The assumed health care cost trend rates as of December 31, 2022 and 2021 were as follows: Post-Retirement 2022 2021 Health care cost trend rate assumed for next year 6.4 % 5.2 % Rate to which the cost trend rate was assumed to decline (the ultimate trend rate) 4.0 % 4.0 % Year that the rate reaches the ultimate trend rate 2046 2046 The table below presents the fair values of the assets of the Company’s Qualified Plan as of December 31, 2022 and 2021 by level of fair value hierarchy. Assets consist of collective trusts and are measured at fair value based on the closing net asset value (“NAV”) as determined by the fund manager and reported daily. As noted above, the Company’s post-retirement medical plan is funded on a pay-as-you-go basis and has no assets. Fair Value Measurements Using December 31, (in millions) 2022 2021 Equities: Domestic equities $ 73.0 $ 73.9 Developed international equities 34.9 37.7 Global low volatility equities 18.4 24.1 Emerging market equities 20.8 24.8 Fixed-income 106.2 121.6 Real Estate 18.9 23.2 Cash and cash equivalents 2.0 1.0 Total $ 274.2 $ 306.3 The Company’s investment strategy for its Qualified Plan is to achieve a reasonable return on assets that supports the plan’s interest credit rating, subject to a moderate level of portfolio risk that provides liquidity. Consistent with these financial objectives as of December 31, 2022, the plan’s target allocations for plan assets are 54% invested in equity securities, 40% fixed income investments and 6% in real estate. Equity securities include international stocks and a blend of U.S. growth and value stocks of various sizes of capitalization. Fixed income securities include bonds and notes issued by the U.S. government and its agencies, corporate bonds, and mortgage-backed securities. The aggregate asset allocation is reviewed on an annual basis. The overall expected long-term rate of return on plan assets for the Qualified Plan is based on the Company’s view of long-term expectations and asset mix.

REVENUES

REVENUES	12 Months Ended
	Dec. 31, 2022
Revenues [Abstract]
REVENUES	REVENUES Revenue Recognition In accordance with FASB ASC Topic 606, Revenue from Contracts with Customers (“ASC 606”), revenue is recognized when control of the promised goods or services is transferred to the Company’s customers, in an amount that reflects the consideration to which the Company expects to be entitled in exchange for those goods or services. 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: Year Ended December 31, (in millions) 2022 2021 2020 Gasoline and distillates $ 41,465.0 $ 23,489.5 $ 12,799.4 Asphalt and blackoils 2,123.8 1,217.8 777.9 Feedstocks and other 1,863.0 1,310.1 935.5 Chemicals 903.8 889.8 351.5 Lubricants 425.0 294.8 180.7 Total Revenues $ 46,780.6 $ 27,202.0 $ 15,045.0 The majority of 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 ASC 606. 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 $37.5 million and $40.3 million as of December 31, 2022 and December 31, 2021, 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. Significant Judgment and Practical Expedients For performance obligations related to sales of products, the Company has determined that customers are able to direct the use of, and obtain substantially all of the benefits from, the products at the point in time that the products are delivered. The Company has determined that the transfer of control upon delivery to the customer’s requested destination accurately depicts the transfer of goods. Upon the delivery of the products and transfer of control, the Company generally has the present right to payment and the customers bear the risks and rewards of ownership of the products. The Company has elected the practical expedient to not disclose the value of unsatisfied performance obligations for (i) contracts with an original expected length of one year or less and (ii) contracts for which the Company recognizes revenue at the amount to which it has the right to invoice for services performed.

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
INCOME TAXES	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 two subsidiaries acquired in connection with the acquisition of Chalmette Refining and PBF Ltd. that 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 (benefit) expense in the PBF Holding Consolidated Statements of Operations consists of the following: (in millions) December 31, 2022 December 31, 2021 December 31, 2020 Current income tax expense (benefit) $ 0.5 $ 0.5 $ (1.2) Deferred income tax (benefit) expense (3.2) (14.5) 7.3 Total income tax (benefit) expense $ (2.7) $ (14.0) $ 6.1 A summary of the components of PBF Holding’s deferred tax assets and deferred tax liabilities consists of the following: (in millions) December 31, 2022 December 31, 2021 Deferred tax assets Net operating loss carry forwards $ 2.2 $ 0.3 Other 0.6 0.5 Total deferred tax assets 2.8 0.8 Valuation allowance — — Total deferred tax assets, net 2.8 0.8 Deferred tax liabilities Property, plant and equipment 16.0 16.3 Inventory 7.8 8.7 Total deferred tax liabilities 23.8 25.0 Net deferred tax liability $ (21.0) $ (24.2)

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Dec. 31, 2022
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	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 December 31, 2022 and 2021. 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 Consolidated Balance Sheets. As of December 31, 2022 Fair Value Hierarchy (in millions) Level 1 Level 2 Level 3 Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Assets: Money market funds $ 106.5 $ — $ — $ 106.5 N/A $ 106.5 Commodity contracts 33.8 15.7 — 49.5 (35.6) 13.9 Derivatives included within inventory intermediation agreement obligations — 25.1 — 25.1 — 25.1 Liabilities: Commodity contracts 20.6 11.8 3.2 35.6 (35.6) — Catalyst obligations — 4.0 — 4.0 — 4.0 Renewable energy credit and emissions obligations — 1,361.1 — 1,361.1 — 1,361.1 Contingent consideration obligation — — 147.3 147.3 — 147.3 As of December 31, 2021 Fair Value Hierarchy (in millions) Level 1 Level 2 Level 3 Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Assets: Money market funds $ 260.9 $ — $ — $ 260.9 N/A $ 260.9 Commodity contracts 71.5 — — 71.5 (71.5) — Derivatives included within inventory intermediation agreement obligations — 19.7 — 19.7 — 19.7 Liabilities: Commodity contracts 79.7 3.8 — 83.5 (71.5) 12.0 Catalyst obligations — 58.4 — 58.4 — 58.4 Renewable energy credit and emissions obligations — 953.9 — 953.9 — 953.9 Contingent consideration obligation — — 29.4 29.4 — 29.4 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 our liability for the purchase of (i) biofuel credits (primarily RINs in the U.S.) needed to satisfy our obligation to blend biofuels into the products we produce and (ii) emission credits under the AB 32 and similar programs (collectively, the cap-and-trade systems). To the degree we are unable to blend biofuels (such as ethanol and biodiesel) at percentages required under the biofuel programs, we must purchase biofuel credits to comply with these programs. Under the cap-and-trade systems, we must purchase emission credits to comply with these systems. The liability for environmental credits is in part based on our 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. The environmental credit obligations are categorized in Level 2 of the fair value hierarchy and are 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 obligation at December 31, 2022 is categorized in Level 3 of the fair value hierarchy and is 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 December 31, 2022 and 2021, $18.6 million and $20.7 million, respectively, were included within Deferred charges and other assets, net for these non-qualified pension plan assets. 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: Year Ended December 31, (in millions) 2022 2021 Balance at beginning of period $ 29.4 $ — Additions — — Settlements (15.0) — Unrealized loss included in earnings 136.1 29.4 Balance at end of period $ 150.5 $ 29.4 There were no transfers between levels during the years ended December 31, 2022 and 2021, respectively. Fair value of debt The table below summarizes the carrying value and fair value of debt as of December 31, 2022 and 2021. December 31, 2022 December 31, 2021 (in millions) Carrying Fair Carrying Fair 2025 Senior Secured Notes (a) $ — $ — $ 1,250.0 $ 1,192.7 2028 Senior Notes (a) 801.6 703.7 826.5 520.9 2025 Senior Notes (a) 664.5 656.0 669.5 475.9 Revolving Credit Facility (b) — — 900.0 900.0 Catalyst financing arrangements (c) 4.0 4.0 58.4 58.4 1,470.1 1,363.7 3,704.4 3,147.9 Unamortized premium — n/a 0.5 n/a Less - Unamortized deferred financing costs (35.2) n/a (31.6) n/a Long-term debt $ 1,434.9 $ 1,363.7 $ 3,673.3 $ 3,147.9 _______________ (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.

DERIVATIVES

DERIVATIVES	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVES	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 December 31, 2022, there were 1,945,994 barrels of crude oil and feedstocks (2,081,783 barrels at December 31, 2021) outstanding under these derivative instruments designated as fair value hedges. As of December 31, 2022, there were 780,734 barrels of intermediates and refined products (2,070,550 barrels at December 31, 2021) 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 December 31, 2022, there were 17,890,000 barrels of crude oil and 12,175,200 barrels of refined products (36,246,000 and 5,819,000, respectively, as of December 31, 2021), 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 December 31, 2022 and December 31, 2021 and the line items in the Consolidated Balance Sheets in which fair values are reflected. Description Balance Sheet Location Fair Value (in millions) Derivatives designated as hedging instruments: December 31, 2022: Derivatives included within the inventory intermediation agreement obligations Accrued expenses $ 25.1 December 31, 2021: Derivatives included within the inventory intermediation agreement obligations Accrued expenses $ 19.7 Derivatives not designated as hedging instruments: December 31, 2022: Commodity contracts Accounts receivable $ 13.9 December 31, 2021: Commodity contracts Accounts receivable $ (12.0) The following table provides information regarding gains or losses recognized in income on derivative instruments and the line items in the Consolidated Statements of Operations in which such gains and losses are reflected. Description Location of Gain or (Loss) Recognized in Gain or (Loss) (in millions) Derivatives designated as hedging instruments: For the year ended December 31, 2022: Derivatives included within the inventory intermediation agreement obligations Cost of products and other $ 5.4 For the year ended December 31, 2021: Derivatives included within the inventory intermediation agreement obligations Cost of products and other $ 8.4 For the year ended December 31, 2020: Derivatives included within the inventory intermediation agreement obligations Cost of products and other $ 12.6 Derivatives not designated as hedging instruments: For the year ended December 31, 2022: Commodity contracts Cost of products and other $ (31.5) For the year ended December 31, 2021: Commodity contracts Cost of products and other $ (83.4) For the year ended December 31, 2020: Commodity contracts Cost of products and other $ 44.4 Hedged items designated in fair value hedges: For the year ended December 31, 2022: Crude oil, intermediate and refined product inventory Cost of products and other $ (5.4) For the year ended December 31, 2021: Crude oil, intermediate and refined product inventory Cost of products and other $ (8.4) For the year ended December 31, 2020: Crude oil, intermediate and refined product inventory Cost of products and other $ (12.6)

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2022
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS Dividend Declared On February 16, 2023, PBF Energy announced a dividend of $0.20 per share on outstanding PBF Energy Class A common stock. The dividend is payable on March 16, 2023 to PBF Energy Class A common stockholders of record as of March 1, 2023. Renewable Diesel Joint Venture On February 16, 2023, we announced that PBF LLC entered into a definitive agreement with Eni Sustainable Mobility, a subsidiary of Eni SpA (“Eni”), to partner in a 50-50 joint venture, St. Bernard Renewables LLC, (“SBR”) which will own the renewable diesel facility that is currently under construction at our Chalmette refinery. Upon consummation of the transaction, which is subject to customary closing conditions, including regulatory approvals, Eni will contribute capital totaling $835.0 million, excluding working capital, plus up to an additional $50.0 million that is subject to the achievement of project milestones. The Company will continue to manage project execution and will serve as the operator of the facility once construction is complete. SBR’s renewable fuel operations are scheduled to commence in the first half of 2023.

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Principles of Consolidation and Presentation	Principles of Consolidation and PresentationThese Consolidated Financial Statements include the accounts of PBF Holding and its consolidated subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation.
Cost Classifications	Cost Classifications Cost of products and other consists of the cost of crude oil, other feedstocks, blendstocks and purchased refined products and the related in-bound freight and transportation costs. Operating expenses (excluding depreciation and amortization) consists of direct costs of labor, maintenance and services, utilities, property taxes, environmental compliance costs and other direct operating costs incurred in connection with our refining operations. Such expenses exclude depreciation related to refining and logistics assets that are integral to the refinery production process, which is presented separately as Depreciation and amortization expense as a component of Cost of sales on the Company’s Consolidated Statements of Operations.
Use of Estimates	Use of Estimates The preparation of the financial statements in conformity with accounting principles generally accepted in the United States (“GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures. Actual results could differ from those estimates.
Impairment Assessment of Long-Lived Assets and Definite-Lived Intangibles	Impairment Assessment of Long-Lived Assets and Definite-Lived IntangiblesThe Company evaluates long-lived assets for impairment on a continual basis and reassesses the reasonableness of their related useful lives whenever events or changes in circumstances warrant assessment. Possible triggering events may include, among other things, significant adverse changes in the business climate, market conditions, environmental regulations or a determination that it is more likely than not that an asset or an asset group will be sold or retired before its estimated useful life. These possible triggering events of impairment may impact the Company’s assumptions related to future throughput levels, future operating revenues, expenses and gross margin, levels of anticipated capital expenditures and remaining useful life. Long-lived assets are tested for recoverability whenever events or changes in circumstances indicate that the carrying amount of the asset may not be recoverable. A long-lived asset is not recoverable if its carrying amount exceeds the sum of the undiscounted cash flows expected to result from its use, early retirement or disposition. Cash flows for long-lived assets/asset groups are determined at the lowest level for which identifiable cash flows exist. The cash flows from the refinery asset groups are evaluated individually regardless of product mix or fuel type produced. If a long-lived asset is not recoverable, an impairment loss is recognized for the amount by which the carrying amount of the long-lived asset exceeds its fair value, with fair value determined based on discounted estimated net cash flows or other appropriate methods. The Company’s assumptions incorporate inherent uncertainties that are at times difficult to predict and could result in impairment charges or accelerated depreciation in future periods if actual results materially differ from the estimated assumptions used.
Business Combinations	Business Combinations We use the acquisition method of accounting for the recognition of assets acquired and liabilities assumed in business combinations at their estimated fair values as of the date of acquisition. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired is recorded as goodwill. Significant judgment is required in estimating the fair value of assets acquired. As a result, in the case of significant acquisitions, we obtain the assistance of third-party valuation specialists in estimating fair values of tangible and intangible assets based on available historical information and on expectations and assumptions about the future, considering the perspective of marketplace participants. While management believes those expectations and assumptions are reasonable, they are inherently uncertain. Unanticipated market or macroeconomic events and circumstances may occur, which could affect the accuracy or validity of the estimates and assumptions. Certain of the Company’s acquisitions may include earn-out provisions or other forms of contingent consideration. As of the acquisition date, the Company records contingent consideration, as applicable, at the estimated fair value of expected future payments associated with the earn-out. Any changes to the recorded fair value of contingent consideration, subsequent to the measurement period, will be recognized as earnings in the period in which it occurs.
Cash and Cash Equivalents	Cash and Cash Equivalents The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents. The carrying amount of the cash equivalents approximates fair value due to the short-term maturity of those instruments.
Concentrations of Credit Risk	Concentrations of Credit Risk For the years ended December 31, 2022 and December 31, 2021, only one customer, Shell plc (“Shell”), accounted for 10% or more of the Company’s revenues (approximately 14% and 15%, respectively).
Revenue Recognition	Revenue Recognition The Company sells various refined products primarily through its refinery subsidiaries and recognizes revenue related to the sale of products when control of the promised goods or services is transferred to the customers, in an amount that reflects the consideration the Company expects to be entitled to in exchange for those goods or services. Refer to “Note 16 - Revenues” for further discussion of the Company’s revenue recognition policy.
Allowance for Doubtful Accounts	Accounts receivable are carried at invoiced amounts. An allowance for doubtful accounts is established, if required, to report such amounts at their estimated net realizable value. In estimating probable losses, management reviews accounts that are past due and determines if there are any known disputes.
Excise Taxes	Excise taxes on sales of refined products that are collected from customers and remitted to various governmental agencies are reported on a net basis.
Inventory	Inventory Inventories are carried at the lower of cost or market. The cost of crude oil, feedstocks, blendstocks and refined products are determined under the last-in first-out (“LIFO”) method using the dollar value LIFO method with increments valued based on average purchase prices during the year. The cost of supplies and other inventories is determined principally on the weighted average cost method.
RINs	RINs The Company is subject to obligations to purchase Renewable Identification Numbers (“RINs”) required to comply with the renewable fuel standard implemented by Environmental Protection Agency (“EPA”), which sets annual quotas for the quantity of renewable fuels (such as ethanol) that must be blended into motor fuels consumed in the United States (the “RFS”). The Company’s overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by EPA. 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.
Leases	Leases The Company leases office space, office equipment, refinery facilities and equipment, railcars and other logistics assets primarily under non-cancelable operating leases, with terms typically ranging from one The Company determines whether a contract is or contains a lease at inception of the contract and whether that lease meets the classification criteria of a finance or operating lease. When available, the Company uses the rate implicit in the lease to discount lease payments to present value; however, most of the Company’s leases do not provide a readily determinable implicit rate. Therefore, the Company must discount lease payments based on an estimate of its incremental borrowing rate.
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment additions are recorded at cost. The Company capitalizes costs associated with the preliminary, pre-acquisition and development/construction stages of a major construction project. The Company capitalizes the interest cost associated with major construction projects based on the effective interest rate of total borrowings. The Company also capitalizes costs incurred in the acquisition and development of software for internal use, including the costs of software, materials, consultants and payroll-related costs for employees incurred in the application development stage. Depreciation is computed using the straight-line method over the following estimated useful lives: Process units and equipment 5-25 years Pipeline and equipment 5-25 years Buildings 25 years Computers, furniture and fixtures 3-7 years Leasehold improvements 20 years Railcars 50 years Maintenance and repairs are charged to operating expenses as they are incurred. Improvements and betterments, which extend the lives of the assets, are capitalized.
Deferred Charges and Other Assets, Net	Deferred Charges and Other Assets, Net Deferred charges and other assets include refinery turnaround costs, catalyst, precious metal catalysts, linefill, deferred financing costs and intangible assets. Refinery turnaround costs, which are incurred in connection with planned major maintenance activities, are capitalized when incurred and amortized on a straight-line basis over the period of time estimated to lapse until the next turnaround occurs. The amortization period generally ranges from 3 to 6 years; however, based upon the specific facts and circumstances, different periods of deferral occur. Precious metal catalysts, linefill and certain other intangibles are considered indefinite-lived assets as they are not expected to deteriorate in their prescribed functions. Such assets are assessed for impairment in connection with the Company’s review of its long-lived assets. Deferred financing costs are capitalized when incurred and amortized over the life of the loan (generally 1 to 8 years).
Finite-Lived Intangible Assets	Intangible assets with finite lives primarily consist of emission credits and permits and are amortized over their estimated useful lives (generally 1 to 10 years).
Asset Retirement Obligations	Asset Retirement Obligations The Company records an asset retirement obligation at fair value for the estimated cost to retire a tangible long-lived asset at the time the Company incurs that liability, which is generally when the asset is purchased, constructed, or leased. The Company records the liability when it has a legal or contractual obligation to incur costs to retire the asset and when a reasonable estimate of the fair value of the liability can be made. If a reasonable estimate cannot be made at the time the liability is incurred, the Company will record the liability when sufficient information is available to estimate the liability’s fair value. Certain of the Company’s asset retirement obligations are based on its legal obligation to perform remedial activity at its refinery sites when it permanently ceases operations of the long-lived assets. The Company therefore considers the settlement date of these obligations to be indeterminable. Accordingly, the Company cannot calculate an associated asset retirement liability for these obligations at this time. The Company will measure and recognize the fair value of these asset retirement obligations when the settlement date is determinable.
Environmental Matters	Environmental Matters Liabilities for future remediation costs are recorded when environmental assessments and/or remedial efforts are probable and the costs can be reasonably estimated. Other than for assessments, the timing and magnitude of these accruals generally are based on the completion of investigations or other studies or a commitment to a formal plan of action. Environmental liabilities are based on best estimates of probable future costs using currently available technology and applying current regulations, as well as the Company’s own internal environmental policies. The measurement of environmental remediation liabilities may be discounted to reflect the time value of money if the aggregate amount and timing of cash payments of the liabilities are fixed or reliably determinable. The actual settlement of the Company’s liability for environmental matters could materially differ from its estimates due to a number of uncertainties such as the extent of contamination, changes in environmental laws and regulations, potential improvements in remediation technologies and the participation of other responsible parties.
Stock-Based Compensation	Stock-Based Compensation Stock-based compensation includes the accounting effect of options to purchase PBF Energy Class A common stock granted by PBF Energy to certain PBF Holding employees, Series A warrants issued or granted by PBF LLC to employees in connection with their acquisition of PBF LLC Series A units, options to acquire Series A units of PBF LLC granted by PBF LLC to certain employees, Series B units of PBF LLC that were granted to certain members of management and restricted PBF LLC Series A Units and restricted PBF Energy Class A common stock granted to certain directors and officers. The estimated fair value of the options to purchase PBF Energy Class A common stock and the PBF LLC Series A warrants and options, is based on the Black-Scholes option pricing model and the fair value of the PBF LLC Series B units is estimated based on a Monte Carlo simulation model. The estimated fair value is amortized as stock-based compensation expense on a straight-line method over the vesting period and included in General and administrative expense with forfeitures recognized in the period they occur. PBF Energy grants performance share unit awards and performance unit awards to certain key employees. Performance awards granted to employees prior to November 1, 2020 are based on a three-year performance cycle with four measurement periods and performance awards granted to employees after November 1, 2020 are based on a three-year performance cycle having a single measurement period. The payout for each, which ranges from zero to 200%, is based on the relative ranking of the total shareholder return (“TSR”) of PBF Energy’s common stock as compared to the TSR of a selected group of industry peer companies over an average of four measurement periods. The performance share unit awards and performance unit awards are each measured at fair value based on Monte Carlo simulation models. The performance share unit awards will be settled in PBF Energy Class A common stock and are accounted for as equity awards and the performance unit awards will be settled in cash and are accounted for as liability awards.
Income Taxes	Income Taxes As PBF Holding is a limited liability company treated as a “flow-through” entity for income tax purposes, there is no benefit or expense for federal or state income tax in the accompanying financial statements apart from the income taxes attributable to two subsidiaries acquired in connection with the acquisition of Chalmette Refining, L.L.C. (“Chalmette Refining”) and the Company’s wholly-owned Canadian subsidiary, PBF Energy Limited (“PBF Ltd.”). These subsidiaries are treated as C-corporations for tax purposes, with the tax provision calculated based on the effective tax rate for the periods presented. The State tax returns for all years since 2018 are subject to examination by the respective tax authorities.
Pension and Other Post-Retirement Benefits	Pension and Other Post-Retirement Benefits The Company recognizes an asset for the overfunded status or a liability for the underfunded status of its pension and post-retirement benefit plans. The funded status is recorded within Other long-term liabilities or Other non-current assets. Changes in the plans’ funded status are recognized in other comprehensive income in the period the change occurs.
Fair Value Measurement	Fair Value Measurement A fair value hierarchy (Level 1, Level 2, or Level 3) is used to categorize fair value amounts based on the quality of inputs used to measure fair value. Accordingly, fair values derived from Level 1 inputs utilize quoted prices in active markets for identical assets or liabilities. Fair values derived from Level 2 inputs are based on quoted prices for similar assets and liabilities in active markets, and inputs other than quoted prices that are either directly or indirectly observable for the asset or liability. Level 3 inputs are unobservable inputs for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability. The Company uses appropriate valuation techniques based on the available inputs to measure the fair values of its applicable assets and liabilities. When available, the Company measures fair value using Level 1 inputs because they generally provide the most reliable evidence of fair value. In some valuations, the inputs may fall into different levels in the hierarchy. In these cases, the asset or liability level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurements.
Financial Instruments	Financial Instruments The estimated fair value of financial instruments has been determined based on the Company’s assessment of available market information and appropriate valuation methodologies. The Company’s non-derivative financial instruments that are included in current assets and current liabilities are recorded at cost in the Consolidated Balance Sheets. The estimated fair value of these financial instruments approximates their carrying value due to their short-term nature. Derivative instruments are recorded at fair value in the Consolidated Balance Sheets. The Company’s commodity contracts are measured and recorded at fair value using Level 1 inputs based on quoted prices in an active market, Level 2 inputs based on quoted market prices for similar instruments, or Level 3 inputs based on third-party sources and other available market based data. The Company’s catalyst obligations and derivatives related to the Company’s crude oil and feedstocks and refined product purchase obligations are measured and recorded at fair value using Level 2 inputs on a recurring basis, based on observable market prices for similar instruments.
Derivative Instruments	Derivative Instruments The Company is exposed to market risk, primarily related to changes in commodity prices for the crude oil and feedstocks used in the refining process as well as the prices of the refined products sold and the risk associated with the price of credits needed to comply with various governmental and regulatory environmental compliance programs. The accounting treatment for commodity and environmental compliance contracts depends on the intended use of the particular contract and on whether or not the contract meets the definition of a derivative. All derivative instruments, not designated as normal purchases or sales, are recorded in the Consolidated Balance Sheets as either assets or liabilities measured at their fair values. Changes in the fair value of derivative instruments that either are not designated or do not qualify for hedge accounting treatment or normal purchase or normal sale accounting are recognized in earnings. Contracts qualifying for the normal purchase and sales exemption are accounted for upon settlement. Cash flows related to derivative instruments that are not designated or do not qualify for hedge accounting treatment are included in operating activities. The Company designates certain derivative instruments as fair value hedges of a particular risk associated with a recognized asset or liability. At the inception of the hedge designation, the Company documents the relationship between the hedging instrument and the hedged item, as well as its risk management objective and strategy for undertaking various hedge transactions. Derivative gains and losses related to these fair value hedges, including hedge ineffectiveness, are recorded in cost of sales along with the change in fair value of the hedged asset or liability attributable to the hedged risk. Cash flows related to derivative instruments that are designated as fair value hedges are included in operating activities. Economic hedges are hedges not designated as fair value or cash flow hedges for accounting purposes that are used to (i) manage price volatility in certain refinery feedstock and refined product inventories, and (ii) manage price volatility in certain forecasted refinery feedstock purchases and refined product sales. These instruments are recorded at fair value and changes in the fair value of the derivative instruments are recognized currently in cost of sales. Derivative accounting is complex and requires management judgment in the following respects: identification of derivatives and embedded derivatives, determination of the fair value of derivatives, documentation of hedge relationships, assessment and measurement of hedge ineffectiveness and election and designation of the normal purchases and sales exemption. All of these judgments, depending upon their timing and effect, can have a significant impact on the Company’s earnings.
Recently Issued Accounting Pronouncements	Recently Issued Accounting Pronouncements In March 2020, the Financial Accounting Standards Board (“FASB”) 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 relationship 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.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Property, Plant and Equipment, Useful Lives	Depreciation is computed using the straight-line method over the following estimated useful lives: Process units and equipment 5-25 years Pipeline and equipment 5-25 years Buildings 25 years Computers, furniture and fixtures 3-7 years Leasehold improvements 20 years Railcars 50 years

INVENTORIES (Tables)

INVENTORIES (Tables)	12 Months Ended
	Dec. 31, 2022
Inventory Disclosure [Abstract]
Schedule of Inventories	Inventories consisted of the following: December 31, 2022 (in millions) Titled Inventory Inventory Intermediation Agreement Total Crude oil and feedstocks $ 1,195.2 $ 140.9 $ 1,336.1 Refined products and blendstocks 1,244.7 40.9 1,285.6 Warehouse stock and other 141.9 — 141.9 $ 2,581.8 $ 181.8 $ 2,763.6 Lower of cost or market adjustment — — — Total inventories $ 2,581.8 $ 181.8 $ 2,763.6 December 31, 2021 (in millions) Titled Inventory Inventory Intermediation Agreement Total Crude oil and feedstocks $ 953.5 $ 151.4 $ 1,104.9 Refined products and blendstocks 964.6 293.8 1,258.4 Warehouse stock and other 141.8 — 141.8 $ 2,059.9 $ 445.2 $ 2,505.1 Lower of cost or market adjustment — — — Total inventories $ 2,059.9 $ 445.2 $ 2,505.1

PROPERTY, PLANT AND EQUIPMENT_2

PROPERTY, PLANT AND EQUIPMENT, NET (Tables)	12 Months Ended
	Dec. 31, 2022
Property, Plant and Equipment [Abstract]
Summary of Property, Plant and Equipment, Net	Property, plant and equipment, net consisted of the following: (in millions) December 31, 2022 December 31, 2021 Land $ 418.8 $ 418.8 Processing units, pipelines and equipment 4,508.8 4,326.8 Buildings and leasehold improvements 107.8 107.3 Computers, furniture and fixtures 175.7 168.1 Construction in progress 825.1 328.1 6,036.2 5,349.1 Less - Accumulated depreciation (1,434.4) (1,234.3) Total property, plant and equipment, net $ 4,601.8 $ 4,114.8

DEFERRED CHARGES AND OTHER AS_2

DEFERRED CHARGES AND OTHER ASSETS, NET (Tables)	12 Months Ended
	Dec. 31, 2022
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Deferred Charges and Other Assets, Net	Deferred charges and other assets, net consisted of the following: (in millions) December 31, 2022 December 31, 2021 Deferred turnaround costs, net $ 619.5 $ 537.0 Catalyst, net (a) 199.7 166.8 Environmental credits 41.4 41.3 Linefill 27.4 27.4 Pension plan assets 18.6 20.7 Other 47.4 20.6 Total deferred charges and other assets, net $ 954.0 $ 813.8 (a) Catalyst, net includes $117.0 million and $113.0 million of indefinite-lived precious metal catalysts (both owned or financed as part of existing catalyst financing arrangements) as of December 31, 2022 and December 31, 2021, respectively.
Schedule of Intangible Assets, Net	Intangible assets, net, included in “Other” above, primarily consists of permits and emission credits. Our net balance as of December 31, 2022 and December 31, 2021 is shown below: (in millions) December 31, 2022 December 31, 2021 Intangible assets - gross $ 4.0 $ 4.0 Accumulated amortization (3.5) (3.5) Intangible assets - net $ 0.5 $ 0.5

ACCRUED EXPENSES (Tables)

ACCRUED EXPENSES (Tables)	12 Months Ended
	Dec. 31, 2022
Payables and Accruals [Abstract]
Schedule of Accrued Expenses	Accrued expenses consisted of the following: (in millions) December 31, 2022 December 31, 2021 Inventory-related accruals $ 1,417.4 $ 959.9 Renewable energy credit and emissions obligations (a) 1,361.1 953.9 Accrued salaries and benefits 172.9 57.1 Accrued transportation costs 127.3 91.0 Excise and sales tax payable 123.8 112.3 Accrued utilities 105.4 73.0 Inventory intermediation agreement (b) 98.3 280.1 Accrued capital expenditures 85.7 62.6 Contingent Consideration 81.6 — Accrued refinery maintenance and support costs 48.1 55.8 Accrued interest 20.1 32.8 Environmental liabilities 14.1 14.3 Current finance lease liabilities 11.7 11.1 Other 23.5 24.4 Total accrued expenses $ 3,691.0 $ 2,728.3 (a) The Company is subject to obligations to purchase RINs required to comply with the RFS. The Company’s overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by EPA. 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. The Company enters into forward purchase commitments in order to acquire its renewable energy and emissions credits at fixed prices. As of December 31, 2022, the Company had entered into approximately $899.2 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 a triennial period program which will be settled through 2024. (b) The Company has the obligation to repurchase the J. Aron Products that are held in its Storage Tanks in accordance with the Third Inventory Intermediation Agreement. As of December 31, 2022 and December 31, 2021, a liability is recognized based on the repurchase obligation under the Third Inventory Intermediation Agreement 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.

CREDIT FACILITIES AND DEBT (Tab

CREDIT FACILITIES AND DEBT (Tables)	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Summary of Long-term Debt Outstanding	Long-term debt outstanding consisted of the following: (in millions) December 31, 2022 December 31, 2021 2025 Senior Secured Notes $ — $ 1,250.0 2028 Senior Notes 801.6 826.5 2025 Senior Notes 664.5 669.5 Revolving Credit Facility — 900.0 Catalyst financing arrangements 4.0 58.4 1,470.1 3,704.4 Unamortized premium — 0.5 Unamortized deferred financing costs (35.2) (31.6) Long-term debt $ 1,434.9 $ 3,673.3
Schedule of Details of Catalyst Financing Arrangements	Details of the catalyst financing arrangements at each of the Company’s refineries as of December 31, 2022 are included in the following table: Refinery Metal Annual interest rate Expiration date (1) Delaware City Palladium 4.60 % September 2023 __________________
Schedule of Debt Maturing in the Next Five Years and Thereafter	Debt maturing in the next five years and thereafter is as follows (in millions): Year Ending December 31, 2023 $ 4.0 2024 — 2025 664.5 2026 — 2027 — Thereafter 801.6 Total debt outstanding $ 1,470.1

OTHER LONG-TERM LIABILITIES (Ta

OTHER LONG-TERM LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2022
Other Liabilities Disclosure [Abstract]
Schedule of Other Long-term Liabilities	Other long-term liabilities consisted of the following: (in millions) December 31, 2022 December 31, 2021 Environmental liabilities $ 141.5 $ 141.0 Defined benefit pension plan liabilities 82.2 46.7 Contingent consideration 65.7 29.4 Deferred Compensation 50.5 — Post-retirement medical plan liabilities 13.9 18.2 Early railcar return liability 1.9 6.0 Other 15.4 9.7 Total other long-term liabilities $ 371.1 $ 251.0

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2022
Related Party Transaction [Line Items]
Schedule of Related Party Transactions	The commercial agreements entered into during the year ended December 31, 2022 (as defined in the table below) with PBFX include: Agreements Initiation Date Initial Term Renewals (a) MVC Force Majeure Transportation and Terminaling Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility (b) 12/12/2014 10 years 2 x 5 4,400 bpd PBF Holding or PBFX can declare Delaware Pipeline Services Agreement 5/15/2015 10 years, 8 months 2 x 5 50,000 bpd Delaware Pipeline Services Agreement- Magellan Connection 11/1/2016 2 years, 5 months See note (c) See note (c) Delaware City Truck Loading Services Agreement- Gasoline 5/15/2015 10 years, 8 months 2 x 5 30,000 bpd Delaware City Truck Loading Services Agreement- LPGs 5/15/2015 10 years, 8 months 2 x 5 5,000 bpd East Coast Terminals Terminaling Services Agreements (d) 5/1/2016 Various (e) Evergreen 15,000 bpd (f) East Coast Terminals Tank Lease Agreements 5/1/2016 Various (e) Evergreen 350,000 barrels (g) Torrance Valley Pipeline Transportation Services Agreement- North Pipeline (b) 8/31/2016 10 years 2 x 5 50,000 bpd Torrance Valley Pipeline Transportation Services Agreement- South Pipeline (b) 8/31/2016 10 years 2 x 5 75,000 bpd (h) Torrance Valley Pipeline Transportation Services Agreement- Midway Storage Tank (b) 8/31/2016 10 years 2 x 5 55,000 barrels (g) Torrance Valley Pipeline Transportation Services Agreement- Emidio Storage Tank (b) 8/31/2016 10 years 2 x 5 900,000 barrels per month Torrance Valley Pipeline Transportation Services Agreement- Belridge Storage Tank (b) 8/31/2016 10 years 2 x 5 770,000 barrels per month Paulsboro Natural Gas Pipeline Services Agreement (b) 8/4/2017 15 years Evergreen 60,000 dekatherms per day Knoxville Terminals Agreement- Terminaling Services 4/16/2018 5 years Evergreen Various (i) Knoxville Terminals Agreement- Storage Services 4/16/2018 5 years Evergreen 115,334 barrels (g) Toledo Rail Loading Agreement (b) 7/31/2018 7 years, 5 months 2 x 5 Various (j) Chalmette Terminal Throughput Agreement 7/31/2018 1 year Evergreen N/A Chalmette Rail Unloading Agreement 7/31/2018 7 years, 5 months 2 x 5 7,600 bpd DSL Ethanol Throughput Agreement (b) 7/31/2018 7 years, 5 months 2 x 5 5,000 bpd Delaware City Terminaling Services Agreement 1/1/2022 4 years 2 x 5 95,000 bpd Toledo Truck Unloading & Terminaling Agreement (b) 4/1/2022 9 months Evergreen See note (k) Storage Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility (b) 12/12/2014 10 years 2 x 5 3,849,271 barrels (g) PBF Holding or PBFX can declare Chalmette Storage Agreement (b) See note (l) 10 years 2 x 5 625,000 barrels (g) East Coast Storage Assets Terminal Storage Agreement (b) 1/1/2019 8 years Evergreen 2,953,725 barrels (g) ____________________ (a) PBF Holding has the option to extend the agreements for up to two additional five-year terms, as applicable. (b) These commercial agreements with PBFX are considered leases. (c) In connection with the inclusion of an additional destination at the Magellan connection under the Delaware Pipeline Services Agreement, PBF Holding and Delaware Pipeline Company LLC agreed to a two-year, five-month MVC (the “Magellan MVC”) under the Delaware Pipeline Services Agreement. The Magellan MVC expired on March 31, 2019, subsequent to which PBFX has been billing actual throughput on the Magellan connection. (d) Subsequent to the PBFX acquisition of the Toledo, Ohio refined products terminal assets (the “Toledo Products Terminal”), the Toledo Products Terminal was added to the East Coast Terminals Terminaling Services Agreements. (e) The East Coast Terminals related party agreements include varying initial term lengths, ranging from one (f) The East Coast Terminals Terminaling Services Agreements have no MVCs and are billed based on actual volumes throughput, other than a terminaling services agreement between PBFX’s East Coast Terminals’ Paulsboro, New Jersey location and PBF Holding’s Paulsboro refinery with a 15,000 bpd MVC. (g) Reflects the overall capacity as stipulated by the storage agreement. The storage MVC is subject to the effective operating capacity of each tank, which can be impacted by routine tank maintenance and other factors. PBF Holding’s available shell capacity may be subject to change as agreed to by PBF Holding and PBFX. (h) In connection with the acquisition of Torrance Valley Pipeline Company LLC on May 31, 2019, the Torrance Valley Pipeline Transportation Services Agreement- South Pipeline was amended and restated to increase the MVC from 70,000 bpd to 75,000 bpd. (i) The minimum throughput revenue commitment for the Knoxville Terminals Agreement- Terminaling Services is $0.9 million for year one, $1.8 million for year two and $2.7 million for year three and thereafter. (j) Under the Toledo Rail Loading Agreement, PBF Holding has minimum throughput commitments for (i) 30 railcars per day of products and (ii) 11.5 railcars per day of premium products. The Toledo Rail Loading Agreement also specifies a maximum throughput rate of 50 railcars per day. (k) The Toledo Truck Unloading & Terminaling Agreement MVC was 5,500 bpd through December 31, 2022. Effective January 1, 2023, the MVC decreased to 1,000 bpd. (l) The Chalmette Storage Services Agreement was entered into on February 15, 2017 and commenced on November 1, 2017.
Contribution Agreements
Related Party Transaction [Line Items]
Schedule of Related Party Transactions	2020.
PBF Logistics LP | Commercial Agreements
Related Party Transaction [Line Items]
Schedule of Related Party Transactions	A summary of our affiliate transactions with PBFX is as follows: Year Ended December 31, (in millions) 2022 2021 2020 Reimbursements under affiliate agreements: Services Agreement $ 8.7 $ 8.7 $ 8.7 Omnibus Agreement 8.3 7.3 7.6 Total expenses under affiliate agreements 319.6 304.1 289.4

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Unrecorded Unconditional Purchase Obligations Disclosure	The fixed and determinable amounts related to obligations under these agreements are as follows: Year Ending December 31, (in millions) 2023 $ 152.6 2024 119.0 2025 114.7 2026 21.7 2027 21.7 Thereafter 186.2 Total obligations $ 615.9

LEASES (Tables)

LEASES (Tables)	12 Months Ended
	Dec. 31, 2022
Leases [Abstract]
Assets and Liabilities, Lessee	The table below presents the lease related assets and liabilities recorded on the Company’s Consolidated Balance Sheets as of December 31, 2022 and December 31, 2021: (in millions) Classification on the Balance Sheet December 31, 2022 December 31, 2021 Assets Operating lease assets - third party Lease right of use assets - third party $ 610.9 $ 635.8 Operating lease assets - affiliate Lease right of use assets - affiliate 421.6 485.4 Finance lease assets Lease right of use assets - third party 67.4 81.2 Total lease right of use assets $ 1,099.9 $ 1,202.4 Liabilities Current liabilities: Operating lease liabilities - third party Current operating lease liabilities - third party $ 60.5 $ 64.8 Operating lease liabilities - affiliate Current operating lease liabilities - affiliate 104.5 90.7 Finance lease liabilities - third party Accrued expenses 11.7 11.1 Noncurrent liabilities: Operating lease liabilities - third party Long-term operating lease liabilities - third party 551.8 570.3 Operating lease liabilities - affiliate Long-term operating lease liabilities - affiliate 317.2 394.7 Finance lease liabilities - third party Long-term financing lease liabilities - third party 57.9 70.6 Total lease liabilities $ 1,103.6 $ 1,202.2
Lease, Cost	The table below presents certain information related to costs for the Company’s leases for the year ended December 31, 2022 and December 31, 2021: Lease Costs (in millions) December 31, 2022 December 31, 2021 Components of total lease costs: Finance lease costs Amortization of right of use assets $ 12.6 $ 16.1 Interest on lease liabilities 5.3 4.6 Operating lease costs 301.5 299.1 Short-term lease costs 88.0 59.3 Variable lease costs 52.4 31.6 Total lease costs $ 459.8 $ 410.7
Cash Flow, Lessee	The table below presents supplemental cash flow information related to leases for the year ended December 31, 2022 and December 31, 2021 (in millions): Years Ended December 31, 2022 2021 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows for operating leases $ 300.5 $ 297.9 Operating cash flows for finance leases 5.3 4.6 Financing cash flows for finance leases 11.3 17.8 Supplemental non-cash quantification of assets acquired or remeasured under operating and financing leases 82.8 (106.6) Lease Term and Discount Rate The table below presents certain information related to the weighted average remaining lease term and weighted average discount rate for the Company’s leases as of December 31, 2022: Weighted average remaining lease term - operating leases 9.4 years Weighted average remaining lease term - finance leases 5.6 years Weighted average discount rate - operating leases 13.6 % Weighted average discount rate - finance leases 7.2 %
Lessee, Liability, Maturity	The table below reconciles the fixed component of the undiscounted cash flows for each of the periods presented to the lease liabilities recorded on the Consolidated Balance Sheets as of December 31, 2022: Amounts due in the year ended December 31, (in millions) Finance Leases Operating Leases 2023 $ 16.1 $ 282.6 2024 15.5 262.4 2025 13.9 213.7 2026 13.6 176.8 2027 13.6 105.7 Thereafter 11.5 823.4 Total minimum lease payments 84.2 1,864.6 Less: effect of discounting 14.6 830.6 Present value of future minimum lease payments 69.6 1,034.0 Less: current obligations under leases 11.7 165.0 Long-term lease obligations $ 57.9 $ 869.0
Finance Lease, Liability, Fiscal Year Maturity	The table below reconciles the fixed component of the undiscounted cash flows for each of the periods presented to the lease liabilities recorded on the Consolidated Balance Sheets as of December 31, 2022: Amounts due in the year ended December 31, (in millions) Finance Leases Operating Leases 2023 $ 16.1 $ 282.6 2024 15.5 262.4 2025 13.9 213.7 2026 13.6 176.8 2027 13.6 105.7 Thereafter 11.5 823.4 Total minimum lease payments 84.2 1,864.6 Less: effect of discounting 14.6 830.6 Present value of future minimum lease payments 69.6 1,034.0 Less: current obligations under leases 11.7 165.0 Long-term lease obligations $ 57.9 $ 869.0

STOCK-BASED COMPENSATION (Table

STOCK-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule of Stock-based Compensation Expense	Stock-based compensation expense included in general and administrative expenses consisted of the following: Years Ended December 31, (in millions) 2022 2021 2020 PBF Energy options $ 19.1 $ 17.3 $ 16.1 PBF Energy restricted shares 11.6 2.8 5.3 PBF Energy performance awards 13.4 10.2 7.9 $ 44.1 $ 30.3 $ 29.3
Schedule of Weighted Average Assumptions	December 31, 2022 December 31, 2021 December 31, 2020 Expected life (in years) 6.00 6.00 6.08 Expected volatility 87.6 % 83.8 % 69.1 % Dividend yield 0.00 % 0.00 % 1.41 % Risk-free rate of return 3.24 % 1.37 % 0.81 % Exercise price $ 29.16 $ 13.91 $ 13.58 Weighted average fair value per option granted $ 21.68 $ 9.84 $ 5.49
Schedule of Share-based payment Awards, Performance Awards, Valuation Assumptions	The grant date fair value was calculated using a Monte Carlo valuation model with the following assumptions: December 31, 2022 December 31, 2021 December 31, 2020 Expected life (in years) 3.08 3.12 2.89 - 3.14 Expected volatility 65.16 % 83.78% 39.88% - 82.63% Dividend yield 2.18 % 0.00% 0.00% - 4.28% Risk-free rate of return 3.90 % 0.87% 0.26% - 1.34% Weighted average grant-date fair value per PSU $ 45.91 $ 18.73 $ 10.77
Employee Stock Option
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Summary of Share-based Compensation Activity	The following table summarizes activity for PBF Energy options for 2022: Number of Weighted Weighted Stock-based awards, outstanding at January 1, 2022 15,049,759 $ 24.48 6.51 Granted 22,000 29.16 10.00 Exercised (4,208,685) 24.54 — Forfeited (210,800) 22.65 — Outstanding at December 31, 2022 10,652,274 $ 24.50 5.96 Exercisable and vested at December 31, 2022 7,826,241 $ 27.01 5.26 Total expected to vest as of December 31, 2022 10,652,274 $ 24.50 5.96
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Summary of Share-based Compensation Activity	The following table summarizes activity for PBF Energy restricted stock: Number of Weighted Average Nonvested at January 1, 2022 155,687 $ 16.09 Granted 659,165 35.73 Vested (109,402) 19.42 Forfeited — — Nonvested at December 31, 2022 705,450 $ 33.92 Unrecognized compensation expense related to PBF Energy Restricted Class A common stock at December 31, 2022 was $12.0 million, which will be recognized from 2023 through 2025. The following table reflects activity related to our restricted stock: December 31, 2022 December 31, 2021 December 31, 2020 Weighted-average grant-date fair value per share of restricted stock granted $ 35.73 $ 16.13 $ 9.82 Fair value of restricted stock vested (in millions) $ 3.3 $ 3.1 $ 4.2
Performance share units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Summary of Share-based Compensation Activity	The following table summarizes activity for PBF Energy performance share awards: Number of Weighted Average Nonvested at January 1, 2022 745,525 $ 13.93 Granted 190,463 45.91 Vested (37,784) 27.71 Forfeited (111,678) 13.92 Nonvested at December 31, 2022 786,526 $ 21.02
Performance Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Summary of Share-based Compensation Activity	The following table summarizes activity for PBF Energy performance unit awards: Number of Nonvested at January 1, 2022 20,178,013 Granted 15,614,603 Vested (1,231,770) Forfeited (3,105,896) Nonvested at December 31, 2022 31,454,950

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	12 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
Schedule of Changes in Benefit Obligations, Fair Value of Plan Assets, and Funded Status of Plan	The changes in the benefit obligation, the changes in fair value of plan assets, and the funded status of the Company’s Pension and Post-Retirement Medical Plans as of and for the years ended December 31, 2022 and 2021 were as follows: Pension Plans Post-Retirement (in millions) 2022 2021 2022 2021 Change in benefit obligation: Benefit obligation at beginning of year $ 353.3 $ 329.3 $ 18.2 $ 22.0 Service cost 55.6 57.5 0.8 1.1 Interest cost 7.9 5.3 0.3 0.3 Plan amendments — — — — Benefit payments (18.9) (31.2) (1.4) (1.2) Actuarial gain (40.9) (7.6) (4.0) (4.0) Projected benefit obligation at end of year $ 357.0 $ 353.3 $ 13.9 $ 18.2 Change in plan assets: Fair value of plan assets at beginning of year $ 306.3 $ 255.8 $ — $ — Actual return on plan assets (51.0) 27.7 — — Benefits paid (18.9) (31.2) (1.4) (1.2) Employer contributions 37.8 54.0 1.4 1.2 Fair value of plan assets at end of year $ 274.2 $ 306.3 $ — $ — Reconciliation of funded status: Fair value of plan assets at end of year $ 274.2 $ 306.3 $ — $ — Less benefit obligations at end of year 357.0 353.3 13.9 18.2 Funded status at end of year $ (82.8) $ (47.0) $ (13.9) $ (18.2)
Schedule of Expected Benefit Payments	Benefit payments, which reflect expected future services that the Company expects to pay are as follows for the years ended December 31: (in millions) Pension Benefits Post-Retirement 2023 $ 25.7 $ 1.7 2024 21.3 1.5 2025 26.0 1.5 2026 29.4 1.5 2027 33.0 1.4 Years 2028-2032 207.8 6.3
Schedule of Net Periodic Benefit Cost	The components of net periodic benefit cost were as follows for the years ended December 31, 2022, 2021 and 2020: Pension Benefits Post-Retirement (in millions) 2022 2021 2020 2022 2021 2020 Components of net periodic benefit cost: Service cost $ 55.6 $ 57.5 $ 59.0 $ 0.8 $ 1.1 $ 1.0 Interest cost 7.9 5.3 6.9 0.3 0.3 0.4 Expected return on plan assets (17.5) (14.2) (12.5) — — — Amortization of prior service cost and actuarial loss 0.1 0.1 0.3 0.4 0.7 0.6 Net periodic benefit cost $ 46.1 $ 48.7 $ 53.7 $ 1.5 $ 2.1 $ 2.0
Schedule of Pre-tax Amounts Recognized in Other Comprehensive Income (Loss)	The pre-tax amounts recognized in other comprehensive (income) loss for the years ended December 31, 2022, 2021, and 2020 were as follows: Pension Benefits Post-Retirement (in millions) 2022 2021 2020 2022 2021 2020 Prior service costs $ — $ — $ — $ — $ — $ 1.8 Net actuarial loss (gain) 27.6 (21.1) (5.9) (4.0) (4.0) 1.9 Amortization of losses and prior service cost (0.1) (0.1) (0.3) (0.4) (0.7) (0.6) Total changes in other comprehensive (income) loss $ 27.5 $ (21.2) $ (6.2) $ (4.4) $ (4.7) $ 3.1
Schedule of Pre-tax Amounts in Accumulated Other Comprehensive Loss Not Yet Recognized as Components of Net Periodic Costs	The pre-tax amounts in accumulated other comprehensive income (loss) as of December 31, 2022 and 2021 that have not yet been recognized as components of net periodic costs were as follows: Pension Benefits Post-Retirement (in millions) 2022 2021 2022 2021 Prior service costs $ (0.5) $ (0.5) $ (3.5) $ (4.3) Net actuarial (loss) gain (14.8) 12.7 11.4 7.8 Total $ (15.3) $ 12.2 $ 7.9 $ 3.5
Schedule of Assumptions Used	The weighted average assumptions used to determine the benefit obligations as of December 31, 2022 and 2021 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2022 2021 2022 2021 2022 2021 Discount rate - benefit obligations 5.22 % 2.78 % 5.24 % 2.73 % 5.15 % 2.46 % Rate of compensation increase 4.27 % 4.26 % 4.50 % 4.50 % — — The weighted average assumptions used to determine the net periodic benefit costs for the years ended December 31, 2022, 2021 and 2020 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2022 2021 2020 2022 2021 2020 2022 2021 2020 Discount rates: Effective rate for service cost 2.80% 2.40% 2.94% 2.73% 2.26% 2.79% 2.80% 2.35% 2.86% Effective rate for interest cost 2.33% 1.74% 2.50% 2.24% 1.53% 2.33% 1.91% 1.28% 2.21% Effective rate for interest on service cost 2.45% 1.92% 2.59% 2.29% 1.75% 2.42% 2.65% 2.11% 2.68% Cash balance interest credit rate 2.06% 1.57% 2.19% 2.06% 1.57% 2.19% N/A N/A N/A Expected long-term rate of return on plan assets 5.50% 5.25% 5.75% N/A N/A N/A N/A N/A N/A Rate of compensation increase 4.26% 4.28% 4.28% 4.50% 4.50% 4.50% N/A N/A N/A
Schedule of Assumed Health Care Cost Trend Rates	The assumed health care cost trend rates as of December 31, 2022 and 2021 were as follows: Post-Retirement 2022 2021 Health care cost trend rate assumed for next year 6.4 % 5.2 % Rate to which the cost trend rate was assumed to decline (the ultimate trend rate) 4.0 % 4.0 % Year that the rate reaches the ultimate trend rate 2046 2046
Schedule of Fair Value of Assets of the Company's Qualified Plan	The table below presents the fair values of the assets of the Company’s Qualified Plan as of December 31, 2022 and 2021 by level of fair value hierarchy. Assets consist of collective trusts and are measured at fair value based on the closing net asset value (“NAV”) as determined by the fund manager and reported daily. As noted above, the Company’s post-retirement medical plan is funded on a pay-as-you-go basis and has no assets. Fair Value Measurements Using December 31, (in millions) 2022 2021 Equities: Domestic equities $ 73.0 $ 73.9 Developed international equities 34.9 37.7 Global low volatility equities 18.4 24.1 Emerging market equities 20.8 24.8 Fixed-income 106.2 121.6 Real Estate 18.9 23.2 Cash and cash equivalents 2.0 1.0 Total $ 274.2 $ 306.3

REVENUES (Tables)

REVENUES (Tables)	12 Months Ended
	Dec. 31, 2022
Revenues [Abstract]
Revenues from External Customers for Each Product or Group of Similar Products	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: Year Ended December 31, (in millions) 2022 2021 2020 Gasoline and distillates $ 41,465.0 $ 23,489.5 $ 12,799.4 Asphalt and blackoils 2,123.8 1,217.8 777.9 Feedstocks and other 1,863.0 1,310.1 935.5 Chemicals 903.8 889.8 351.5 Lubricants 425.0 294.8 180.7 Total Revenues $ 46,780.6 $ 27,202.0 $ 15,045.0

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Components of Income Tax (Benefit) Expense	The reported income tax (benefit) expense in the PBF Holding Consolidated Statements of Operations consists of the following: (in millions) December 31, 2022 December 31, 2021 December 31, 2020 Current income tax expense (benefit) $ 0.5 $ 0.5 $ (1.2) Deferred income tax (benefit) expense (3.2) (14.5) 7.3 Total income tax (benefit) expense $ (2.7) $ (14.0) $ 6.1
Schedule of Deferred Tax Assets and Liabilities	A summary of the components of PBF Holding’s deferred tax assets and deferred tax liabilities consists of the following: (in millions) December 31, 2022 December 31, 2021 Deferred tax assets Net operating loss carry forwards $ 2.2 $ 0.3 Other 0.6 0.5 Total deferred tax assets 2.8 0.8 Valuation allowance — — Total deferred tax assets, net 2.8 0.8 Deferred tax liabilities Property, plant and equipment 16.0 16.3 Inventory 7.8 8.7 Total deferred tax liabilities 23.8 25.0 Net deferred tax liability $ (21.0) $ (24.2)

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	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 December 31, 2022 and 2021. 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 Consolidated Balance Sheets. As of December 31, 2022 Fair Value Hierarchy (in millions) Level 1 Level 2 Level 3 Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Assets: Money market funds $ 106.5 $ — $ — $ 106.5 N/A $ 106.5 Commodity contracts 33.8 15.7 — 49.5 (35.6) 13.9 Derivatives included within inventory intermediation agreement obligations — 25.1 — 25.1 — 25.1 Liabilities: Commodity contracts 20.6 11.8 3.2 35.6 (35.6) — Catalyst obligations — 4.0 — 4.0 — 4.0 Renewable energy credit and emissions obligations — 1,361.1 — 1,361.1 — 1,361.1 Contingent consideration obligation — — 147.3 147.3 — 147.3 As of December 31, 2021 Fair Value Hierarchy (in millions) Level 1 Level 2 Level 3 Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Assets: Money market funds $ 260.9 $ — $ — $ 260.9 N/A $ 260.9 Commodity contracts 71.5 — — 71.5 (71.5) — Derivatives included within inventory intermediation agreement obligations — 19.7 — 19.7 — 19.7 Liabilities: Commodity contracts 79.7 3.8 — 83.5 (71.5) 12.0 Catalyst obligations — 58.4 — 58.4 — 58.4 Renewable energy credit and emissions obligations — 953.9 — 953.9 — 953.9 Contingent consideration obligation — — 29.4 29.4 — 29.4
Schedule of Effect of Significant Unobservable Inputs	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: Year Ended December 31, (in millions) 2022 2021 Balance at beginning of period $ 29.4 $ — Additions — — Settlements (15.0) — Unrealized loss included in earnings 136.1 29.4 Balance at end of period $ 150.5 $ 29.4
Schedule of Fair value of Debt	The table below summarizes the carrying value and fair value of debt as of December 31, 2022 and 2021. December 31, 2022 December 31, 2021 (in millions) Carrying Fair Carrying Fair 2025 Senior Secured Notes (a) $ — $ — $ 1,250.0 $ 1,192.7 2028 Senior Notes (a) 801.6 703.7 826.5 520.9 2025 Senior Notes (a) 664.5 656.0 669.5 475.9 Revolving Credit Facility (b) — — 900.0 900.0 Catalyst financing arrangements (c) 4.0 4.0 58.4 58.4 1,470.1 1,363.7 3,704.4 3,147.9 Unamortized premium — n/a 0.5 n/a Less - Unamortized deferred financing costs (35.2) n/a (31.6) n/a Long-term debt $ 1,434.9 $ 1,363.7 $ 3,673.3 $ 3,147.9 _______________ (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.

DERIVATIVES (Tables)

DERIVATIVES (Tables)	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Fair Value of Derivative Instruments	The following tables provide information regarding the fair values of derivative instruments as of December 31, 2022 and December 31, 2021 and the line items in the Consolidated Balance Sheets in which fair values are reflected. Description Balance Sheet Location Fair Value (in millions) Derivatives designated as hedging instruments: December 31, 2022: Derivatives included within the inventory intermediation agreement obligations Accrued expenses $ 25.1 December 31, 2021: Derivatives included within the inventory intermediation agreement obligations Accrued expenses $ 19.7 Derivatives not designated as hedging instruments: December 31, 2022: Commodity contracts Accounts receivable $ 13.9 December 31, 2021: Commodity contracts Accounts receivable $ (12.0)
Schedule of Derivative Instruments, Gain (Loss) Recognized in Income	The following table provides information regarding gains or losses recognized in income on derivative instruments and the line items in the Consolidated Statements of Operations in which such gains and losses are reflected. Description Location of Gain or (Loss) Recognized in Gain or (Loss) (in millions) Derivatives designated as hedging instruments: For the year ended December 31, 2022: Derivatives included within the inventory intermediation agreement obligations Cost of products and other $ 5.4 For the year ended December 31, 2021: Derivatives included within the inventory intermediation agreement obligations Cost of products and other $ 8.4 For the year ended December 31, 2020: Derivatives included within the inventory intermediation agreement obligations Cost of products and other $ 12.6 Derivatives not designated as hedging instruments: For the year ended December 31, 2022: Commodity contracts Cost of products and other $ (31.5) For the year ended December 31, 2021: Commodity contracts Cost of products and other $ (83.4) For the year ended December 31, 2020: Commodity contracts Cost of products and other $ 44.4 Hedged items designated in fair value hedges: For the year ended December 31, 2022: Crude oil, intermediate and refined product inventory Cost of products and other $ (5.4) For the year ended December 31, 2021: Crude oil, intermediate and refined product inventory Cost of products and other $ (8.4) For the year ended December 31, 2020: Crude oil, intermediate and refined product inventory Cost of products and other $ (12.6)

DESCRIPTION OF THE BUSINESS A_2

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION (Details) - segment	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Description of Business [Line Items]
Percentage of ownership in PBF LLC	100%
Number of reportable segments	1
PBF Energy | Class A Common Stock
Description of Business [Line Items]
Percentage of ownership in PBF LLC	99.30%	99.20%

SUMMARY OF SIGNIFICANT ACCOUN_4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Concentration of Credit Risk) (Details) - Customer Concentration Risk - numberOfCustomer	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Revenues
Concentration Risk [Line Items]
Number of Customers to Account for More than 10%	1	1
Concentration Risk, Benchmark Description	10	10
Revenues | Royal Dutch Shell
Concentration Risk [Line Items]
Concentration risk percentage	14%	15%
Accounts Receivables
Concentration Risk [Line Items]
Number of Customers to Account for More than 10%	1	1
Concentration Risk, Benchmark Description	10	10
Accounts Receivables | Royal Dutch Shell
Concentration Risk [Line Items]
Concentration risk percentage	19%	26%

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Leases) (Details)	Dec. 31, 2022
Minimum
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term	20 years

SUMMARY OF SIGNIFICANT ACCOUN_6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Property, Plant, and Equipment) (Details)	12 Months Ended
	Dec. 31, 2022
Process units and equipment | Minimum
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Process units and equipment | Maximum
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Pipeline and equipment | Minimum
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Pipeline and equipment | Maximum
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Buildings
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Computers, furniture and fixtures | Minimum
Property, Plant and Equipment [Line Items]
Estimated useful lives	3 years
Computers, furniture and fixtures | Maximum
Property, Plant and Equipment [Line Items]
Estimated useful lives	7 years
Leasehold improvements
Property, Plant and Equipment [Line Items]
Estimated useful lives	20 years
Railcars
Property, Plant and Equipment [Line Items]
Estimated useful lives	50 years

SUMMARY OF SIGNIFICANT ACCOUN_7

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Deferred Charges and Other Assets, Net) (Details)	12 Months Ended
	Dec. 31, 2022
Minimum
Finite-Lived Intangible Assets [Line Items]
Refinery turnaround amortization period	3 years
Amortization over life of loan	1 year
Intangible assets estimated useful lives	1 year
Maximum
Finite-Lived Intangible Assets [Line Items]
Refinery turnaround amortization period	6 years
Amortization over life of loan	8 years
Intangible assets estimated useful lives	10 years

SUMMARY OF SIGNIFICANT ACCOUN_8

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Stock-Based Compensation) (Details) - Performance Share Units and Performance Unit Awards - number_period		12 Months Ended
	Oct. 31, 2020	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Requisite service period	3 years	3 years
Number of periods	4
Distribution percentage based on performance measurements, number of periods		4
Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distribution percentage based on performance measurements		0%
Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distribution percentage based on performance measurements		200%

SUMMARY OF SIGNIFICANT ACCOUN_9

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Income Taxes) (Details)	12 Months Ended
	Dec. 31, 2022 subsidiary
Accounting Policies [Abstract]
Number of subsidiaries acquired	2

CURRENT EXPECTED CREDIT LOSSES

CURRENT EXPECTED CREDIT LOSSES (Details) - USD ($)	Dec. 31, 2022	Dec. 31, 2021
Credit Loss [Abstract]
Allowance for doubtful accounts	$ 0	$ 0

INVENTORIES (Details)

INVENTORIES (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Inventory [Line Items]
Crude oil and feedstocks	$ 1,336,100,000	$ 1,104,900,000
Refined products and blendstocks	1,285,600,000	1,258,400,000
Warehouse stock and other	141,900,000	141,800,000
Inventory, Gross	2,763,600,000	2,505,100,000
Lower of cost or market adjustment	0	0	$ (669,600,000)
Total inventories	2,763,600,000	2,505,100,000
Income from operations	3,972,400,000	404,000,000	(1,611,400,000)
Inventory, LIFO reserve, effect on income	0	0	$ 83,000,000
Titled Inventory
Inventory [Line Items]
Crude oil and feedstocks	1,195,200,000	953,500,000
Refined products and blendstocks	1,244,700,000	964,600,000
Warehouse stock and other	141,900,000	141,800,000
Inventory, Gross	2,581,800,000	2,059,900,000
Lower of cost or market adjustment	0	0
Total inventories	2,581,800,000	2,059,900,000
Inventory Intermediation Agreement
Inventory [Line Items]
Crude oil and feedstocks	140,900,000	151,400,000
Refined products and blendstocks	40,900,000	293,800,000
Warehouse stock and other	0	0
Inventory, Gross	181,800,000	445,200,000
Lower of cost or market adjustment	0	0
Total inventories	$ 181,800,000	445,200,000
Adjustment
Inventory [Line Items]
Income from operations		$ 669,600,000

PROPERTY, PLANT AND EQUIPMENT_3

PROPERTY, PLANT AND EQUIPMENT, NET (Details) $ in Millions		12 Months Ended
	Apr. 17, 2020 USD ($) hydrogenPlant	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		$ 6,036.2	$ 5,349.1
Less - Accumulated depreciation		(1,434.4)	(1,234.3)
Total property, plant and equipment, net		4,601.8	4,114.8
Depreciation		200.4	192.3	$ 179.4
Impairment expense		0	0	91.8
Number of hydrogen plants sold | hydrogenPlant	5
Proceeds from sale of assets	$ 530	0	0	543.1
Gain on disposition of property plant equipment		(0.9)	0.2	477.8
Gain on disposition of property, plant and equipment, excluding oil and gas property and timber property		(0.9)	0.2	477.8
Air Products and Chemical, Inc.
Property, Plant and Equipment [Line Items]
Proceeds from sale of assets	$ 530
Gain on disposition of property plant equipment				471.1
Land
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		418.8	418.8
Processing units, pipelines and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		4,508.8	4,326.8
Buildings and leasehold improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		107.8	107.3
Computers, furniture and fixtures
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		175.7	168.1
Construction in progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		825.1	328.1
Capitalized interest		$ 24.8	$ 8.9
Construction in progress | East Coast Refining | Idled Processing Units
Property, Plant and Equipment [Line Items]
Impairment expense				11.9
Construction in progress | East Coast Refining | Capital Projects
Property, Plant and Equipment [Line Items]
Impairment expense				79.9
Torrance Refinery
Property, Plant and Equipment [Line Items]
Gain on disposition of property, plant and equipment, excluding oil and gas property and timber property				$ 8.1

DEFERRED CHARGES AND OTHER AS_3

DEFERRED CHARGES AND OTHER ASSETS, NET (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Deferred turnaround costs, net		$ 619,500	$ 537,000
Catalyst, net	[1]	199,700	166,800
Environmental credits		41,400	41,300
Linefill		27,400	27,400
Pension plan assets		18,600	20,700
Other		47,400	20,600
Total deferred charges and other assets, net		954,000	813,800
Amortization expense		261,500	220,600	$ 315,700
Accelerated amortization, deferred turnaround costs				$ 56,200
Intangible Assets, Net [Abstract]
Intangible assets - gross		4,000	4,000
Accumulated amortization		(3,500)	(3,500)
Intangible assets - net		500	500
Indefinitely-Lived Precious Metal
Catalyst, net		$ 117,000	$ 113,000
[1]Catalyst, net includes $117.0 million and $113.0 million of indefinite-lived precious metal catalysts (both owned or financed as part of existing catalyst financing arrangements) as of December 31, 2022 and December 31, 2021, respectively.

ACCRUED EXPENSES (Details)

ACCRUED EXPENSES (Details) - USD ($) $ in Millions		Dec. 31, 2022	Dec. 31, 2021
Accrued Expenses:
Inventory-related accruals		$ 1,417.4	$ 959.9
Renewable energy credit and emissions obligations	[1]	1,361.1	953.9
Accrued salaries and benefits		172.9	57.1
Accrued transportation costs		127.3	91
Excise and sales tax payable		123.8	112.3
Accrued utilities		105.4	73
Inventory intermediation agreements	[2]	98.3	280.1
Accrued capital expenditures		85.7	62.6
Contingent Consideration		81.6	0
Accrued refinery maintenance and support costs		48.1	55.8
Accrued interest		20.1	32.8
Environmental liabilities		14.1	14.3
Current finance lease liabilities		11.7	11.1
Other		23.5	24.4
Total accrued expenses		$ 3,691	$ 2,728.3
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]		Total accrued expenses	Total accrued expenses
Forward Purchase Commitments for Renewable Energy Credit Obligations		$ 899.2
[1]The Company is subject to obligations to purchase RINs required to comply with the RFS. The Company’s overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by EPA. 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. The Company enters into forward purchase commitments in order to acquire its renewable energy and emissions credits at fixed prices. As of December 31, 2022, the Company had entered into approximately $899.2 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 a triennial period program which will be settled through 2024.[2]The Company has the obligation to repurchase the J. Aron Products that are held in its Storage Tanks in accordance with the Third Inventory Intermediation Agreement. As of December 31, 2022 and December 31, 2021, a liability is recognized based on the repurchase obligation under the Third Inventory Intermediation Agreement 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.

CREDIT FACILITIES AND DEBT (Sum

CREDIT FACILITIES AND DEBT (Summary of Long-Term Debt) (Details) - USD ($) $ in Millions		Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 1,470.1	$ 3,704.4
Unamortized premium		0	0.5
Unamortized deferred financing costs		(35.2)	(31.6)
Long-term debt		1,434.9	3,673.3
Revolving Credit Facility
Debt Instrument [Line Items]
Long-term line of credit		0	900
2025 Senior Secured Notes
Debt Instrument [Line Items]
Long-term Debt		0	1,250
2028 Senior Notes
Debt Instrument [Line Items]
Long-term Debt		801.6	826.5
2025 Senior Notes
Debt Instrument [Line Items]
Long-term Debt		664.5	669.5
Catalyst financing arrangements
Debt Instrument [Line Items]
Long-term Debt		$ 4	$ 58.4
Catalyst Financing Arrangement | Delaware City
Debt Instrument [Line Items]
Annual interest rate	[1]	4.60%
[1]This catalyst financing arrangement is included in Long-term debt as of December 31, 2022 as the Company has the ability and intent to finance this debt through availability under other credit facilities if the catalyst financing arrangement is not renewed at maturity.

CREDIT FACILITIES AND DEBT (Nar

CREDIT FACILITIES AND DEBT (Narrative) (Details) $ in Millions

1 Months Ended

12 Months Ended

May 26, 2022 USD ($)

Dec. 21, 2020 USD ($)

May 13, 2020 USD ($)

Jan. 24, 2020 USD ($)

May 30, 2017 USD ($)

Oct. 31, 2012

Dec. 31, 2022 USD ($)

Dec. 31, 2021 USD ($)

Dec. 31, 2020 USD ($)

May 02, 2023 USD ($)

May 25, 2022 USD ($)

May 07, 2020

May 06, 2020

Feb. 18, 2020 USD ($)

Feb. 09, 2012

Debt Instrument [Line Items]

Uncommitted receivables purchase facility, maximum borrowing

$ 300

(Loss) gain on extinguishment of debt

$ (66.1)

$ 79.9

$ (22.2)

Revolving Loan

Debt Instrument [Line Items]

Long-term line of credit

0

900

Catalyst Financing Arrangement

Debt Instrument [Line Items]

Annual catalyst financing fees

0.2

2

Line of Credit | Revolving Loan

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 4,300

Line of credit, available increase in borrowing capacity

500

Maximum borrowing capacity, as a percentage of aggregate borrowing capacity

10%

Alternative maximum borrowing capacity

$ 100

Effective consolidated fixed charge coverage ratio during period

1

Line of credit, incur certain secured debt, percentage of total assets

20%

10%

Long-term line of credit

0

900

Letters of credit outstanding, amount

576.1

380.1

Line of Credit | Revolving Loan | Tranche A

Debt Instrument [Line Items]

Maximum borrowing capacity

1,550

Line of Credit | Revolving Loan | Tranche B

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 2,750

Line of Credit | Revolving Loan | Subsequent Event | Scenario, Forecast

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 2,750

Line of Credit | Revolving Loan | Maximum

Debt Instrument [Line Items]

Line of credit, commitment fee, percent

0.25%

Line of Credit | Revolving Loan | Base Rate | Minimum

Debt Instrument [Line Items]

Basis spread on variable rate

0.25%

Line of Credit | Revolving Loan | Base Rate | Maximum

Debt Instrument [Line Items]

Basis spread on variable rate

1%

Line of Credit | Revolving Loan | Company Credit Rating | Minimum

Debt Instrument [Line Items]

Basis spread on variable rate

1%

Line of Credit | Revolving Loan | Company Credit Rating | Maximum

Debt Instrument [Line Items]

Basis spread on variable rate

1.75%

Line of Credit | Revolving Loan | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate | Minimum

Debt Instrument [Line Items]

Basis spread on variable rate

1.25%

Line of Credit | Revolving Loan | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate | Maximum

Debt Instrument [Line Items]

Basis spread on variable rate

2%

2025 Senior Secured Notes

Debt Instrument [Line Items]

Long-term Debt

0

1,250

2028 Senior Notes

Debt Instrument [Line Items]

Long-term Debt

$ 801.6

826.5

Debt, redemption price, percent (up to)

35%

Redemption price as a percentage

106%

Initial 2025 Senior Secured Notes

Debt Instrument [Line Items]

Long-term Debt

$ 1,000

Annual interest rate

9.25%

Proceeds from debt, net

$ 982.9

Additional 2025 Senior Secured Notes

Debt Instrument [Line Items]

Long-term Debt

$ 250

Annual interest rate

9.25%

Proceeds from debt, net

$ 245.7

Debt , issued

100.25%

2025 Senior Notes

Debt Instrument [Line Items]

Long-term Debt

$ 725

Annual interest rate

7.25%

Proceeds from debt, net

$ 711.6

Redemption price as a percentage

100%

Extinguishment of debt, amount

$ 5

55.5

Repayments of long-term debt

4.8

37.5

0

(Loss) gain on extinguishment of debt

0.2

17.5

2028 Senior Notes

Debt Instrument [Line Items]

Long-term Debt

$ 1,000

Annual interest rate

6%

Proceeds from debt, net

$ 987

Extinguishment of debt, amount

24.9

173.5

Repayments of long-term debt

21.1

109.3

0

(Loss) gain on extinguishment of debt

3.6

62.4

2020 Senior Secured Notes

Debt Instrument [Line Items]

Annual interest rate

8.25%

2023 Senior Notes

Debt Instrument [Line Items]

Annual interest rate

7%

Repayments of long-term debt

$ 0

0

517.5

2025 Senior Secured Notes

Debt Instrument [Line Items]

Redemption price as a percentage

104.625%

Repayments of long-term debt

$ 1,307.4

$ 0

$ 0

(Loss) gain on extinguishment of debt

$ 69.9

CREDIT FACILITIES AND DEBT (Deb

CREDIT FACILITIES AND DEBT (Debt Maturities) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Long-term Debt, Fiscal Year Maturity [Abstract]
2023	$ 4
2024	0
2025	664.5
2026	0
2027	0
Thereafter	801.6
Long-term Debt	$ 1,470.1	$ 3,704.4

OTHER LONG-TERM LIABILITIES (De

OTHER LONG-TERM LIABILITIES (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Other Long-Term Liabilities [Abstract]
Environmental liabilities	$ 141.5	$ 141
Defined benefit pension plan liabilities	82.2	46.7
Contingent consideration	65.7	29.4
Deferred Compensation	50.5	0
Post-retirement medical plan liabilities	13.9	18.2
Early railcar return liability	1.9	6
Other	15.4	9.7
Other long-term liabilities	$ 371.1	$ 251

RELATED PARTY TRANSACTIONS (Nar

RELATED PARTY TRANSACTIONS (Narrative) (Details) - USD ($)		12 Months Ended
	Nov. 30, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Series B Units | Guarantor, Affiliated Entity
Related Party Transaction [Line Items]
Distribution to unitholders		$ 0	$ 0	$ 0
Acquisition of PBF Logistics Common Units Held by Public Member
Related Party Transaction [Line Items]
Acquisition of noncontrolling interests consideration transferred equity interests issued and issuable entity shares issued per acquiree share (in shares)	0.27
Par value (in dollars per share)	$ 0.001
Business acquisition, share price (in dollars per share)	$ 9.25
Acquisition of PBF Logistics Common Units Held by Public Member | PBF Energy
Related Party Transaction [Line Items]
Payments for repurchase of redeemable noncontrolling interest		$ 303,700,000
Stock issued during period, shares, acquisition of noncontrolling interest (in shares)		8,864,684

RELATED PARTY TRANSACTIONS (Com

RELATED PARTY TRANSACTIONS (Commercial Agreements) (Details) $ in Millions

6 Months Ended

12 Months Ended

33 Months Ended

Apr. 01, 2022 bbl / d

Jan. 01, 2022 bbl / d renewal

May 31, 2019 bbl / d

Jan. 01, 2019 bbl

Jul. 31, 2018 bbl / d Railcars_per_day renewal

Apr. 16, 2018 USD ($) bbl

Nov. 01, 2017 bbl renewal

Aug. 04, 2017 dekatherm_per_day

Nov. 01, 2016

Aug. 31, 2016 bbl / d renewal bbl

May 01, 2016 bbl / d

May 15, 2015 bbl / d renewal

Dec. 12, 2014 bbl / d renewal bbl

Jan. 24, 2013 bbl

Jun. 30, 2024 bbl / d

Dec. 31, 2022 renewal

May 30, 2019 bbl / d

Related Party Transaction [Line Items]

Number of Contract Renewals

2

Term of renewal

5 years

Toledo Storage Facility Storage and Terminaling Services Agreement | Toledo Terminaling Facility | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1]

10 years

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

[1]

4,400

Toledo Storage Facility Storage and Terminaling Services Agreement | Toledo Storage Facility | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1]

10 years

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Maximum Storage Capacity | bbl

[1],[2]

3,849,271

Delaware Pipeline Services Agreement | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

10 years 8 months

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

50,000

Delaware Pipeline Services Agreement- Magellan Connection | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[3]

2 years 5 months

Delaware City Truck Loading Services Agreement | Refined Clean Product | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

10 years 8 months

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

30,000

Delaware City Truck Loading Services Agreement | LPGs | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

10 years 8 months

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

5,000

East Coast Terminals Terminaling Services Agreements | PBF Logistics LP

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

[4],[5],[6]

15,000

East Coast Terminals Tank Lease Agreements | PBF Logistics LP

Related Party Transaction [Line Items]

Oil And Gas Plant, Maximum Storage Capacity | bbl

[2],[6]

350,000

Torrance Valley Pipeline Transportation Services Agreement | Torrance Valley Pipeline - North | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1]

10 years

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

[1]

50,000

Torrance Valley Pipeline Transportation Services Agreement | Torrance Valley Pipeline - South | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1]

10 years

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

75,000

75,000

[1],[7]

70,000

Torrance Valley Pipeline Transportation Services Agreement | Torrance Valley Pipeline - Midway Storage Tanks | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1]

10 years

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Maximum Storage Capacity | bbl

[1],[2]

55,000

Torrance Valley Pipeline Transportation Services Agreement | Torrance Valley Pipeline - Emidio Storage Tanks | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1]

10 years

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

[1]

900,000

Torrance Valley Pipeline Transportation Services Agreement | Torrance Valley Pipeline - Belridge Storage Tanks | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1]

10 years

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

[1]

770,000

Paulsboro Natural Gas Pipeline Services Agreement | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1]

15 years

Oil And Gas Plant, Maximum Storage Capacity | dekatherm_per_day

[1]

60,000

Knoxville Terminals Agreement | Terminaling Service | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[8]

5 years

Knoxville Terminals Agreement | Terminaling Service | PBF Logistics LP | Agreement Period One

Related Party Transaction [Line Items]

Oil and Gas Plant, Collaborative Agreement, Minimum Revenue Commitment | $

0.9

Knoxville Terminals Agreement | Terminaling Service | PBF Logistics LP | Agreement Period Two

Related Party Transaction [Line Items]

Oil and Gas Plant, Collaborative Agreement, Minimum Revenue Commitment | $

1.8

Knoxville Terminals Agreement | Terminaling Service | PBF Logistics LP | Agreement Period Three

Related Party Transaction [Line Items]

Oil and Gas Plant, Collaborative Agreement, Minimum Revenue Commitment | $

2.7

Knoxville Terminals Agreement | Storage Services | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

5 years

Oil And Gas Plant, Maximum Storage Capacity | bbl

[2]

115,334

Toledo Rail Loading Agreement | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1],[9]

7 years 5 months

Number of Contract Renewals

2

Term of renewal

5 years

Oil and Gas Plant, Collaborative Agreement, Maximum Throughput Capacity | Railcars_per_day

50

Toledo Rail Loading Agreement | Product | PBF Logistics LP

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | Railcars_per_day

30

Toledo Rail Loading Agreement | Premium Product | PBF Logistics LP

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | Railcars_per_day

11.5

Chalmette Terminal Throughput Agreement | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

1 year

Chalmette Rail Unloading Agreement | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

7 years 5 months

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

7,600

DSL Ethanol Throughput Agreement | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1]

7 years 5 months

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

[1]

5,000

Delaware City Terminaling Services Agreement | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

4 years

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

95,000

Toledo Truck Unloading & Terminaling Agreement | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[10]

9 months

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

5,500

Toledo Truck Unloading & Terminaling Agreement | PBF Logistics LP | Scenario, Forecast

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

1,000

Chalmette Storage Agreement | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1],[11]

10 years

Number of Contract Renewals

2

Term of renewal

5 years

Oil And Gas Plant, Maximum Storage Capacity | bbl

[1],[2]

625,000

East Coast Storage Assets Terminal Storage Agreement | PBF Logistics LP

Related Party Transaction [Line Items]

Initial Term

[1]

8 years

Oil And Gas Plant, Maximum Storage Capacity | bbl

[1],[2]

2,953,725

East Coast Terminals commercial agreements | PBF Logistics LP | Minimum

Related Party Transaction [Line Items]

Initial Term

1 year

East Coast Terminals commercial agreements | PBF Logistics LP | Maximum

Related Party Transaction [Line Items]

Initial Term

5 years

[1]These commercial agreements with PBFX are considered leases.[2]Reflects the overall capacity as stipulated by the storage agreement. The storage MVC is subject to the effective operating capacity of each tank, which can be impacted by routine tank maintenance and other factors. PBF Holding’s available shell capacity may be subject to change as agreed to by PBF Holding and PBFX.[3]In connection with the inclusion of an additional destination at the Magellan connection under the Delaware Pipeline Services Agreement, PBF Holding and Delaware Pipeline Company LLC agreed to a two-year, five-month MVC (the “Magellan MVC”) under the Delaware Pipeline Services Agreement. The Magellan MVC expired on March 31, 2019, subsequent to which PBFX has been billing actual throughput on the Magellan connection.[4]Subsequent to the PBFX acquisition of the Toledo, Ohio refined products terminal assets (the “Toledo Products Terminal”), the Toledo Products Terminal was added to the East Coast Terminals Terminaling Services Agreements.[5]The East Coast Terminals Terminaling Services Agreements have no MVCs and are billed based on actual volumes throughput, other than a terminaling services agreement between PBFX’s East Coast Terminals’ Paulsboro, New Jersey location and PBF Holding’s Paulsboro refinery with a 15,000 bpd MVC.[6]The East Coast Terminals related party agreements include varying initial term lengths, ranging from one

RELATED PARTY TRANSACTIONS (Omn

RELATED PARTY TRANSACTIONS (Omnibus and Services Agreements) (Details) - PBF Logistics LP - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Fifth Amended and Restated Omnibus Agreement
Related Party Transaction [Line Items]
Initial Term		10 years
Selling, general and administrative expenses from transactions with related party		$ 8.3
Fifth Amended and Restated Omnibus Agreement | Subsequent Event
Related Party Transaction [Line Items]
Selling, general and administrative expenses from transactions with related party	$ 8.3
Services Agreement
Related Party Transaction [Line Items]
Selling, general and administrative expenses from transactions with related party		$ 8.7

RELATED PARTY TRANSACTIONS (Sum

RELATED PARTY TRANSACTIONS (Summary of Transactions with PBFX) (Details) $ in Millions

6 Months Ended

12 Months Ended

33 Months Ended

Apr. 01, 2022 bbl / d

May 31, 2019 bbl / d

Jul. 31, 2018 Railcars_per_day renewal

Apr. 16, 2018 USD ($)

Aug. 31, 2016 bbl / d renewal

May 01, 2016 bbl / d

Jun. 30, 2024 bbl / d

Dec. 31, 2022 USD ($) renewal

Dec. 31, 2021 USD ($)

Dec. 31, 2020 USD ($)

May 30, 2019 bbl / d

Related Party Transaction [Line Items]

Number of Contract Renewals | renewal

2

Term of renewal

5 years

PBF Logistics LP | East Coast Terminals commercial agreements | Minimum

Related Party Transaction [Line Items]

Initial Term

1 year

PBF Logistics LP | East Coast Terminals commercial agreements | Maximum

Related Party Transaction [Line Items]

Initial Term

5 years

PBF Logistics LP | East Coast Terminals Terminaling Services Agreements

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

[1],[2],[3]

15,000

PBF Logistics LP | Torrance Valley Pipeline Transportation Services Agreement | Torrance Valley Pipeline - South

Related Party Transaction [Line Items]

Number of Contract Renewals | renewal

2

Term of renewal

5 years

Initial Term

[4]

10 years

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

75,000

75,000

[4],[5]

70,000

PBF Logistics LP | Knoxville Terminals Agreement | Terminaling Service

Related Party Transaction [Line Items]

Initial Term

[6]

5 years

PBF Logistics LP | Knoxville Terminals Agreement | Agreement Period One | Terminaling Service

Related Party Transaction [Line Items]

Oil and Gas Plant, Collaborative Agreement, Minimum Revenue Commitment

0.9

PBF Logistics LP | Knoxville Terminals Agreement | Agreement Period Two | Terminaling Service

Related Party Transaction [Line Items]

Oil and Gas Plant, Collaborative Agreement, Minimum Revenue Commitment

1.8

PBF Logistics LP | Knoxville Terminals Agreement | Agreement Period Three | Terminaling Service

Related Party Transaction [Line Items]

Oil and Gas Plant, Collaborative Agreement, Minimum Revenue Commitment

2.7

PBF Logistics LP | Toledo Rail Loading Agreement

Related Party Transaction [Line Items]

Number of Contract Renewals | renewal

2

Term of renewal

5 years

Initial Term

[4],[7]

7 years 5 months

Oil and Gas Plant, Collaborative Agreement, Maximum Throughput Capacity | Railcars_per_day

50

PBF Logistics LP | Toledo Rail Loading Agreement | Product

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | Railcars_per_day

30

PBF Logistics LP | Toledo Rail Loading Agreement | Premium Product

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | Railcars_per_day

11.5

PBF Logistics LP | Toledo Truck Unloading & Terminaling Agreement

Related Party Transaction [Line Items]

Initial Term

[8]

9 months

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

5,500

PBF Logistics LP | Toledo Truck Unloading & Terminaling Agreement | Scenario, Forecast

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d

1,000

General and Administrative Expense | PBF Logistics LP | Services Agreement

Related Party Transaction [Line Items]

Total expenses under affiliate agreements

$ 8.7

$ 8.7

$ 8.7

General and Administrative Expense | PBF Logistics LP | Omnibus Agreement

Related Party Transaction [Line Items]

Total expenses under affiliate agreements

8.3

7.3

7.6

Cost of Sales [Member] | PBF Logistics LP

Related Party Transaction [Line Items]

Total expenses under affiliate agreements

$ 319.6

$ 304.1

$ 289.4

[1]Subsequent to the PBFX acquisition of the Toledo, Ohio refined products terminal assets (the “Toledo Products Terminal”), the Toledo Products Terminal was added to the East Coast Terminals Terminaling Services Agreements.[2]The East Coast Terminals Terminaling Services Agreements have no MVCs and are billed based on actual volumes throughput, other than a terminaling services agreement between PBFX’s East Coast Terminals’ Paulsboro, New Jersey location and PBF Holding’s Paulsboro refinery with a 15,000 bpd MVC.[3]The East Coast Terminals related party agreements include varying initial term lengths, ranging from one

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES (Future Minimum Rental Payments) (Details) $ in Millions	Dec. 31, 2022 USD ($)
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2023	$ 152.6
2024	119
2025	114.7
2026	21.7
2027	21.7
Thereafter	186.2
Total obligations	$ 615.9

COMMITMENTS AND CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES (Narrative) (Details) $ in Millions		12 Months Ended
	Feb. 01, 2020 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Environmental Matters
Environmental liabilities		$ 155.6	$ 155.3
Environmental liabilities, Lont-Term		$ 141.5	141
Tax Receivable Agreement [Abstract]
Percent of tax benefit received from increases in tax basis paid to stockholders		85%
Percentage of ownership in PBF LLC		100%
Payable to related parties, tax receivable agreement		$ 338.6	$ 48.3
Environmental Loss Contingency, Statement of Financial Position [Extensible Enumeration]		Accrued expenses	Accrued expenses
Martinez Acquistion
Contingent Consideration
Initial Term	4 years
Business combination, contingent consideration, liability			$ 29.4
Tax Receivable Agreement [Abstract]
Business combination, contingent consideration, initial estimate	$ 77.3
Martinez Acquisition
Contingent Consideration
Business combination, contingent consideration, liability		$ 147.3
Martinez Acquisition | Accrued expenses
Contingent Consideration
Business combination, contingent consideration, liability		$ 81.6
PBF Energy | Class A Common Stock
Tax Receivable Agreement [Abstract]
Percentage of ownership in PBF LLC		99.30%	99.20%
Environmental Issue | Torrance Refinery
Environmental Matters
Environmental liabilities		$ 117	$ 118.5
Executive | Minimum
Employment Agreements
Potential lump sum payment as a multiple of base salary		1.50
Executive | Maximum
Employment Agreements
Potential lump sum payment as a multiple of base salary		2.99

LEASES (Lease Assets and Liabil

LEASES (Lease Assets and Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Total lease right of use assets	Total lease right of use assets
Finance lease assets	$ 67.4	$ 81.2
Total lease right of use assets	1,099.9	1,202.4
Current operating lease liabilities	165
Current finance lease liabilities	11.7	11.1
Long-term lease obligations	869
Finance Lease, Liability, Noncurrent	57.9	70.6
Total lease liabilities	$ 1,103.6	$ 1,202.2
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Accrued expenses	Accrued expenses
Third Party Lease
Operating Lease, Right-of-Use Asset	$ 610.9	$ 635.8
Total lease right of use assets	678.3	717
Current operating lease liabilities	60.5	64.8
Long-term lease obligations	551.8	570.3
Finance Lease, Liability, Noncurrent	57.9	70.6
Lease with Affiliate
Operating Lease, Right-of-Use Asset	421.6	485.4
Total lease right of use assets	421.6	485.4
Current operating lease liabilities	104.5	90.7
Long-term lease obligations	$ 317.2	$ 394.7

LEASES (Narrative) (Details)

LEASES (Narrative) (Details) $ in Millions		12 Months Ended
	Apr. 17, 2020 USD ($) hydrogenPlant	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Aug. 01, 2020 USD ($)
Lessee, Lease, Description [Line Items]
Number of hydrogen plants sold | hydrogenPlant	5
Proceeds from sale of assets	$ 530	$ 0	$ 0	$ 543.1
Gain on disposition of property plant equipment		(0.9)	0.2	477.8
Operating lease, liability		1,034
Net gains (losses) on sale-leaseback transactions		$ 0
Lessee, lease not yet commenced, term of contract		2 years
Lessee, leases not yet commenced, liability		$ 48.9
Operating lease costs		$ 301.5	299.1
Air Products and Chemical, Inc.
Lessee, Lease, Description [Line Items]
Proceeds from sale of assets	$ 530
Gain on disposition of property plant equipment				$ 471.1
Air Products and Chemical, Inc. | Transition Service Agreement
Lessee, Lease, Description [Line Items]
Supply commitment, period	18 months
Minimum
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term		1 year
Maximum
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term		20 years
Hydrogen Supply | Air Products and Chemical, Inc.
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term					15 years
Operating lease, right-of-use asset					$ 504
Operating lease, liability					$ 504
Lease with Affiliate
Lessee, Lease, Description [Line Items]
Operating lease, right-of-use asset		$ 421.6	485.4
Operating lease costs		$ 129.9	$ 129.1
Lease with Affiliate | Minimum
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term		7 years
Lease with Affiliate | Maximum
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term		15 years

LEASES (Lease Cost) (Details)

LEASES (Lease Cost) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Finance lease costs, Amortization of lease right of use assets	$ 12.6	$ 16.1
Finance lease costs, Interest on lease liabilities	5.3	4.6
Operating lease costs	301.5	299.1
Short-term lease costs	88	59.3
Variable lease costs	52.4	31.6
Total lease costs	$ 459.8	$ 410.7

LEASES (Supplemental Cash Flow

LEASES (Supplemental Cash Flow and Other Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Leases - Supplemental Cash Flow and Other Information [Abstract]
Operating cash flows for operating leases	$ 300.5	$ 297.9
Operating cash flows for finance leases	5.3	4.6
Financing cash flows for finance leases	11.3	17.8
Supplemental non-cash quantification of assets acquired or remeasured under operating and financing leases	$ 82.8	$ (106.6)
Weighted average remaining lease term - operating leases	9 years 4 months 24 days
Weighted average remaining lease term - finance leases	5 years 7 months 6 days
Weighted average discount rate - operating leases	13.60%
Weighted average discount rate - finance leases	7.20%

LEASES (Maturity of Lease Liabi

LEASES (Maturity of Lease Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Finance Leases
2023	$ 16.1
2024	15.5
2025	13.9
2026	13.6
2027	13.6
Thereafter	11.5
Total minimum lease payments	84.2
Less: effect of discounting	14.6
Present value of future minimum lease payments	69.6
Less: current obligations under leases	11.7	$ 11.1
Long-term lease obligations	57.9	$ 70.6
Operating Leases
2023	282.6
2024	262.4
2025	213.7
2026	176.8
2027	105.7
Thereafter	823.4
Total minimum lease payments	1,864.6
Less: effect of discounting	830.6
Present value of future minimum lease payments	1,034
Less: current obligations under leases	165
Long-term lease obligations	$ 869

EQUITY STRUCTURE (Details)

EQUITY STRUCTURE (Details)	12 Months Ended
	Dec. 31, 2022 USD ($) subsidiary vote shares	Dec. 31, 2021 USD ($)
Class of Stock [Line Items]
Shares outstanding (in shares)	0
Percentage of ownership in PBF LLC	100%
Number of subsidiaries acquired | subsidiary	2
Net income (loss) attributable to noncontrolling interest | $	$ 1,400,000	$ 2,300,000
Collins Pipeline Company And T&M Terminal Company
Class of Stock [Line Items]
Noncontrolling interest, ownership percentage by parent	80%
PBF Energy | Class B Common Stock
Class of Stock [Line Items]
Number of votes per share | vote	1
PBF Finance Corporation
Class of Stock [Line Items]
Shares outstanding (in shares)	100
PBF LLC | Series B Units
Class of Stock [Line Items]
Equity unit, stated value per share | $	$ 0
Number of units authorized (in shares)	1,000,000

STOCK-BASED COMPENSATION (Share

STOCK-BASED COMPENSATION (Share-Based Compensation Expense) (Details) - General and Administrative Expense - PBF Energy - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	$ 44.1	$ 30.3	$ 29.3
Employee Stock Option
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	19.1	17.3	16.1
Restricted Stock
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	11.6	2.8	5.3
Performance Shares
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	$ 13.4	$ 10.2	$ 7.9

STOCK-BASED COMPENSATION (Weigh

STOCK-BASED COMPENSATION (Weighted Average Assumptions) (Details) - PBF Energy - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Employee Stock Option
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life (in years)	6 years	6 years	6 years 29 days
Expected volatility	87.60%	83.80%	69.10%
Dividend yield	0%	0%	1.41%
Risk-free rate of return	3.24%	1.37%	0.81%
Exercise price (in dollars per share)	$ 29.16	$ 13.91	$ 13.58
Weighted average fair value per unit (in dollars per share)	21.68	$ 9.84	5.49
Granted (in dollars per share)	$ 29.16
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life (in years)	3 years 29 days	3 years 1 month 13 days
Expected volatility	65.16%	83.78%
Dividend yield	2.18%	0%
Risk-free rate of return	3.90%	0.87%
Granted (in dollars per share)	$ 45.91	$ 18.73	$ 10.77
Performance Share Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life (in years)			2 years 10 months 20 days
Expected volatility			39.88%
Dividend yield			0%
Risk-free rate of return			0.26%
Performance Share Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life (in years)			3 years 1 month 20 days
Expected volatility			82.63%
Dividend yield			4.28%
Risk-free rate of return			1.34%

STOCK-BASED COMPENSATION (Sha_2

STOCK-BASED COMPENSATION (Share-Based Compensation Activity) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Weighted Average Remaining Contractual Life (in years)
Total estimated fair value, vested in period	$ 3.3	$ 3.1	$ 4.2
Employee Stock Option | PBF Energy
Options & Restricted Stock
Options, beginning balance (in shares)	15,049,759
Granted (in shares)	22,000
Exercised/Vested (in shares)	(4,208,685)
Forfeited (in shares)	(210,800)
Options, ending balance (in shares)	10,652,274	15,049,759
Options exercisable and vested (in shares)	7,826,241
Options expected to vest (in shares)	10,652,274
Weighted Average Exercise Price
Weighted average exercise price (in dollars per share)	$ 24.50	$ 24.48
Granted (in dollars per share)	29.16
Exercised (in dollars per share)	24.54
Forfeited (in dollars per share)	22.65
Weighted average exercise price, exercisable and vested (in dollars per share)	27.01
Weighted average exercise price, expected to vest (in dollars per share)	$ 24.50
Weighted Average Remaining Contractual Life (in years)
Weighted average remaining contractual term, outstanding (in years)	5 years 11 months 15 days	6 years 6 months 3 days
Weighted average remaining contractual term, granted (in years)	10 years
Weighted average remaining contractual term, exercisable and vested (in years)	5 years 3 months 3 days
Weighted average remaining contractual term, expected to vest (in years)	5 years 11 months 15 days
Restricted Stock | PBF Energy
Options & Restricted Stock
Options, beginning balance (in shares)	155,687
Granted (in shares)	659,165
Exercised/Vested (in shares)	(109,402)
Forfeited (in shares)	0
Options, ending balance (in shares)	705,450	155,687
Weighted Average Exercise Price
Weighted average exercise price (in dollars per share)	$ 33.92	$ 16.09
Granted (in dollars per share)	35.73	$ 16.13	$ 9.82
Exercised (in dollars per share)	19.42
Forfeited (in dollars per share)	$ 0
Performance Share Units | PBF Energy
Options & Restricted Stock
Options, beginning balance (in shares)	745,525
Granted (in shares)	190,463
Options, ending balance (in shares)	786,526	745,525
Weighted Average Exercise Price
Weighted average exercise price (in dollars per share)	$ 21.02	$ 13.93
Granted (in dollars per share)	45.91	$ 18.73	$ 10.77
Exercised (in dollars per share)	27.71
Forfeited (in dollars per share)	$ 13.92
Weighted Average Remaining Contractual Life (in years)
Total estimated fair value, vested in period	$ 2	$ 1.8	$ 0.8

STOCK-BASED COMPENSATION (Summa

STOCK-BASED COMPENSATION (Summary of Unit Activity) (Details) - PBF Energy - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Performance Units
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number (in shares)	31,454,950	20,178,013
Granted (in shares)	15,614,603
Vested (in shares)	(1,231,770)
Forfeited (in shares)	(3,105,896)
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Number (in shares)	31,454,950	20,178,013
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number (in shares)	786,526	745,525
Granted (in shares)	190,463
Vested (in shares)	(37,784)
Forfeited (in shares)	(111,678)
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Number (in shares)	786,526	745,525
Weighted Average Grant Date Fair Value [Abstract]
Weighted average exercise price (in dollars per share)	$ 21.02	$ 13.93
Granted (in dollars per share)	45.91	18.73	$ 10.77
Exercised (in dollars per share)	27.71
Weighted average exercise price (in dollars per share)	$ 21.02	$ 13.93

STOCK-BASED COMPENSATION (Narra

STOCK-BASED COMPENSATION (Narrative) (Details)		12 Months Ended			14 Months Ended
	Oct. 31, 2020 number_period	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total estimated fair value, vested in period		$ 3,300,000	$ 3,100,000	$ 4,200,000
Employee Stock Option | PBF Energy
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expiration period		10 years
Vesting period		4 years			3 years
Total intrinsic value of stock options outstanding		$ 173,500,000
Total intrinsic value of stock options exercisable		107,800,000
Total intrinsic value of stock options exercised during period		63,100,000	400,000	0
Unrecognized compensation expense		$ 17,300,000
Restricted Stock | PBF Energy
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period		3 years
Unrecognized compensation expense		$ 12,000,000
Performance Share Units and Performance Unit Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Requisite service period	3 years	3 years
Number of periods | number_period	4
Performance Share Units and Performance Unit Awards | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distribution percentage based on performance measurements		0%
Performance Share Units and Performance Unit Awards | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distribution percentage based on performance measurements		200%
Performance Share Units and Performance Unit Awards | PBF Energy
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Requisite service period					3 years
Number of periods | number_period	4
Performance Share Units and Performance Unit Awards | PBF Energy | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distribution percentage based on performance measurements		0%
Performance Share Units and Performance Unit Awards | PBF Energy | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distribution percentage based on performance measurements		200%
Performance share units | PBF Energy
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense		$ 13,300,000
Unrecognized compensation expense, period for recognition		2 years 6 months 18 days
Performance Units | PBF Energy
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense		$ 21,500,000
Unrecognized compensation expense, period for recognition		2 years 3 months 10 days
Total estimated fair value, vested in period		$ 1,500,000	$ 5,200,000	$ 3,200,000
Share-based compensation, performance unit, Payout, at target		1
Performance Units | PBF Energy | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, performance unit, Payout, at target		$ 2

EMPLOYEE BENEFIT PLANS (Changes

EMPLOYEE BENEFIT PLANS (Changes in Benefit Obligations, Fair Value of Plan Assets, and Funded Status of Plan) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Pension Plans
Change in benefit obligation:
Benefit obligation at beginning of year	$ 353.3	$ 329.3
Service cost	55.6	57.5	$ 59
Interest cost	7.9	5.3	6.9
Plan amendments	0	0
Benefit payments	(18.9)	(31.2)
Actuarial gain	(40.9)	(7.6)
Projected benefit obligation at end of year	357	353.3	329.3
Change in plan assets:
Fair value of plan assets at beginning of year	306.3	255.8
Actual return on plan assets	(51)	27.7
Benefits paid	(18.9)	(31.2)
Employer contributions	37.8	54
Fair value of plan assets at end of year	274.2	306.3	255.8
Reconciliation of funded status:
Fair value of plan assets at end of year	274.2	306.3	255.8
Less benefit obligations at end of year	357	353.3	329.3
Funded status at end of year	(82.8)	(47)
Post-Retirement Medical Plan
Change in benefit obligation:
Benefit obligation at beginning of year	18.2	22
Service cost	0.8	1.1	1
Interest cost	0.3	0.3	0.4
Plan amendments	0	0
Benefit payments	(1.4)	(1.2)
Actuarial gain	(4)	(4)
Projected benefit obligation at end of year	13.9	18.2	22
Change in plan assets:
Fair value of plan assets at beginning of year	0	0
Actual return on plan assets	0	0
Benefits paid	(1.4)	(1.2)
Employer contributions	1.4	1.2
Fair value of plan assets at end of year	0	0	0
Reconciliation of funded status:
Fair value of plan assets at end of year	0	0	0
Less benefit obligations at end of year	13.9	18.2	$ 22
Funded status at end of year	$ (13.9)	$ (18.2)

EMPLOYEE BENEFIT PLANS (Expecte

EMPLOYEE BENEFIT PLANS (Expected Benefit Payments) (Details) $ in Millions	Dec. 31, 2022 USD ($)
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
2023	$ 25.7
2024	21.3
2025	26
2026	29.4
2027	33
Years 2028-2032	207.8
Post-Retirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
2023	1.7
2024	1.5
2025	1.5
2026	1.5
2027	1.4
Years 2028-2032	$ 6.3

EMPLOYEE BENEFIT PLANS (Net Per

EMPLOYEE BENEFIT PLANS (Net Periodic Benefit Cost) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 55.6	$ 57.5	$ 59
Interest cost	7.9	5.3	6.9
Expected return on plan assets	(17.5)	(14.2)	(12.5)
Amortization of prior service cost and actuarial loss	0.1	0.1	0.3
Net periodic benefit cost	46.1	48.7	53.7
Post-Retirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost	0.8	1.1	1
Interest cost	0.3	0.3	0.4
Expected return on plan assets	0	0	0
Amortization of prior service cost and actuarial loss	0.4	0.7	0.6
Net periodic benefit cost	$ 1.5	$ 2.1	$ 2

EMPLOYEE BENEFIT PLANS (Pre-tax

EMPLOYEE BENEFIT PLANS (Pre-tax Amounts Recognized in Other Comprehensive Income (Loss)) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Prior service costs	$ 0	$ 0	$ 0
Net actuarial loss (gain)	27.6	(21.1)	(5.9)
Amortization of losses and prior service cost	(0.1)	(0.1)	(0.3)
Total changes in other comprehensive (income) loss	27.5	(21.2)	(6.2)
Prior service costs	(0.5)	(0.5)
Net actuarial (loss) gain	(14.8)	12.7
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax	(15.3)	12.2
Post-Retirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Prior service costs	0	0	1.8
Net actuarial loss (gain)	(4)	(4)	1.9
Amortization of losses and prior service cost	(0.4)	(0.7)	(0.6)
Total changes in other comprehensive (income) loss	(4.4)	(4.7)	$ 3.1
Prior service costs	(3.5)	(4.3)
Net actuarial (loss) gain	11.4	7.8
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax	$ 7.9	$ 3.5

EMPLOYEE BENEFIT PLANS (Pre-t_2

EMPLOYEE BENEFIT PLANS (Pre-tax Amounts in AOCI Not Yet Recognized as Components of Net Periodic Costs) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Prior service costs	$ (0.5)	$ (0.5)
Net actuarial (loss) gain	(14.8)	12.7
Total	(15.3)	12.2
Post-Retirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Prior service costs	(3.5)	(4.3)
Net actuarial (loss) gain	11.4	7.8
Total	$ 7.9	$ 3.5

EMPLOYEE BENEFIT PLANS (Assumpt

EMPLOYEE BENEFIT PLANS (Assumptions Used) (Details)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Qualified Plan
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate - benefit obligations	5.22%	2.78%
Rate of compensation increase	4.27%	4.26%
Discount rates:
Effective rate for service cost	2.80%	2.40%	2.94%
Effective rate for interest cost	2.33%	1.74%	2.50%
Effective rate for interest on service cost	2.45%	1.92%	2.59%
Cash balance interest credit rate	2.06%	1.57%	2.19%
Expected long-term rate of return on plan assets	5.50%	5.25%	5.75%
Rate of compensation increase	4.26%	4.28%	4.28%
Supplemental Plan
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate - benefit obligations	5.24%	2.73%
Rate of compensation increase	4.50%	4.50%
Discount rates:
Effective rate for service cost	2.73%	2.26%	2.79%
Effective rate for interest cost	2.24%	1.53%	2.33%
Effective rate for interest on service cost	2.29%	1.75%	2.42%
Cash balance interest credit rate	2.06%	1.57%	2.19%
Rate of compensation increase	4.50%	4.50%	4.50%
Post-Retirement Medical Plan
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate - benefit obligations	5.15%	2.46%
Rate of compensation increase	0%	0%
Discount rates:
Effective rate for service cost	2.80%	2.35%	2.86%
Effective rate for interest cost	1.91%	1.28%	2.21%
Effective rate for interest on service cost	2.65%	2.11%	2.68%

EMPLOYEE BENEFIT PLANS (Assumed

EMPLOYEE BENEFIT PLANS (Assumed Health Care Cost Trend Rates) (Details) - Post-Retirement Medical Plan	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	6.40%	5.20%
Rate to which the cost trend rate was assumed to decline (the ultimate trend rate)	4%	4%
Year that the rate reaches the ultimate trend rate	2046	2046

EMPLOYEE BENEFIT PLANS (Fair Va

EMPLOYEE BENEFIT PLANS (Fair Value of Assets of the Company's Qualified Plan) (Details) - Pension Plans - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	$ 274.2	$ 306.3	$ 255.8
Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	274.2	306.3
Level 1 | Domestic equities
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	73	73.9
Level 1 | Developed international equities
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	34.9	37.7
Level 1 | Global low volatility equities
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	18.4	24.1
Level 1 | Emerging market equities
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	20.8	24.8
Level 1 | Fixed-income
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	106.2	121.6
Level 1 | Real Estate
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	18.9	23.2
Level 1 | Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	$ 2	$ 1

EMPLOYEE BENEFIT PLANS (Additio

EMPLOYEE BENEFIT PLANS (Additional Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Maximum age to receive health care coverage	65 years
Accumulated benefit obligation	$ 321	$ 298.9
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Required service period for employee participation	30 days
Basic contributions as a percentage of annual salary	50%
Company matching contribution, percent of match	200%
Company matching contribution, percent of employees' annual pay	3%
Contribution to the qualified defined contribution plans	$ 33.4	$ 27.8	$ 32.7
Estimated future contributions for 2023	$ 33.6
Pension Plans | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	54%
Pension Plans | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	40%
Pension Plans | Real Estate
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	6%

REVENUES (Schedule of Revenue f

REVENUES (Schedule of Revenue from External Customers) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Product Information [Line Items]
Revenues	$ 46,780.6	$ 27,202	$ 15,045
Deferred revenue	37.5	40.3
Gasoline and distillates
Product Information [Line Items]
Revenues	41,465	23,489.5	12,799.4
Asphalt and blackoils
Product Information [Line Items]
Revenues	2,123.8	1,217.8	777.9
Feedstocks and other
Product Information [Line Items]
Revenues	1,863	1,310.1	935.5
Chemicals
Product Information [Line Items]
Revenues	903.8	889.8	351.5
Lubricants
Product Information [Line Items]
Revenues	$ 425	$ 294.8	$ 180.7

INCOME TAXES (Narrative) (Detai

INCOME TAXES (Narrative) (Details)	12 Months Ended
	Dec. 31, 2022 subsidiary
Income Tax Disclosure [Abstract]
Number of subsidiaries acquired	2

INCOME TAXES (Components of Inc

INCOME TAXES (Components of Income Tax (Benefit) Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Current income tax expense (benefit)	$ 0.5	$ 0.5	$ (1.2)
Deferred income tax (benefit) expense	(3.2)	(14.5)	7.3
Total income tax (benefit) expense	$ (2.7)	$ (14)	$ 6.1

INCOME TAXES (Components of Def

INCOME TAXES (Components of Deferred Tax Assets and Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Deferred tax assets
Net operating loss carry forwards	$ 2.2	$ 0.3
Other	0.6	0.5
Total deferred tax assets	2.8	0.8
Valuation allowance	0	0
Total deferred tax assets, net	2.8	0.8
Deferred tax liabilities
Property, plant and equipment	16	16.3
Inventory	7.8	8.7
Total deferred tax liabilities	23.8	25
Net deferred tax liability	$ (21)	$ (24.2)

FAIR VALUE MEASUREMENTS (Measur

FAIR VALUE MEASUREMENTS (Measured on Recurring Basis) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Qualified Plan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Plan Assets, Amount	$ 274.2	$ 306.3	$ 255.8
Level 1 | Qualified Plan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Plan Assets, Amount	274.2	306.3
Level 1 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Plan Assets, Amount		20.7
Commodity contracts | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	35.6	83.5
Derivative, Collateral, Right to Reclaim Cash	(35.6)	(71.5)
Derivative Liability	0	12
Commodity contracts | Level 1 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	20.6	79.7
Commodity contracts | Level 2 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	11.8	3.8
Commodity contracts | Level 3 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	3.2	0
Catalyst financing arrangements | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	4	58.4
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability	4	58.4
Catalyst financing arrangements | Level 1 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0
Catalyst financing arrangements | Level 2 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	4	58.4
Catalyst financing arrangements | Level 3 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0
Renewable Energy Credit and Emissions Obligation | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	1,361.1	953.9
Derivative, Collateral, Right to Reclaim Cash	0	0
Renewable Energy Credit and Emissions Obligation | Level 1 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0
Renewable Energy Credit and Emissions Obligation | Level 2 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	1,361.1	953.9
Renewable Energy Credit and Emissions Obligation | Level 3 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0
Contingent Consideration | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	147.3	29.4
Derivative, Collateral, Right to Reclaim Cash	0	0
Contingent Consideration | Level 1 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0
Contingent Consideration | Level 2 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0
Contingent Consideration | Level 3 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	147.3	29.4
Money market funds | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	106.5	260.9
Money market funds | Level 1 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	106.5	260.9
Money market funds | Level 2 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Money market funds | Level 3 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Commodity contracts | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	49.5	71.5
Derivative, Collateral, Obligation to Return Cash	(35.6)	(71.5)
Derivative Asset	13.9	0
Commodity contracts | Level 1 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	33.8	71.5
Commodity contracts | Level 2 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	15.7	0
Commodity contracts | Level 3 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	0	0
Derivatives included within inventory intermediation agreement obligations | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	25.1	19.7
Derivative, Collateral, Obligation to Return Cash	0	0
Derivative Asset	25.1	19.7
Derivatives included within inventory intermediation agreement obligations | Level 1 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	0	0
Derivatives included within inventory intermediation agreement obligations | Level 2 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	25.1	19.7
Derivatives included within inventory intermediation agreement obligations | Level 3 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	0	$ 0
Other Assets | Qualified Plan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Plan Assets, Amount	$ 18.6

FAIR VALUE MEASUREMENTS (Change

FAIR VALUE MEASUREMENTS (Change in Fair Value at Level 3) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Transfers into Level 3	$ 0	$ 0
Contingent Consideration
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at beginning of period	29,400,000	0
Additions	0	0
Settlements	(15,000,000)	0
Unrealized loss included in earnings	136,100,000	29,400,000
Balance at end of period	$ 150,500,000	$ 29,400,000

FAIR VALUE MEASUREMENTS (Fair V

FAIR VALUE MEASUREMENTS (Fair Value and Carrying Value of Debt) (Details) - USD ($) $ in Millions		Dec. 31, 2022	Dec. 31, 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Gross		$ 1,470.1	$ 3,704.4
Unamortized deferred financing costs		(35.2)	(31.6)
Long-term debt		1,434.9	3,673.3
Long-term Debt, Fair Value		1,363.7	3,147.9
Long-term debt, Fair value		1,363.7	3,147.9
Unamortized premium		0	0.5
Revolving Credit Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term line of credit		0	900
Lines of Credit, Fair Value Disclosure	[1]	0	900
2025 Senior Secured Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		0	1,250
Long-term Debt, Fair Value	[2]	0	1,192.7
2028 Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		801.6	826.5
Long-term Debt, Fair Value	[2]	703.7	520.9
2025 Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		664.5	669.5
Long-term Debt, Fair Value	[2]	656	475.9
Catalyst financing arrangements
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		4	58.4
Long-term Debt, Fair Value	[3]	$ 4	$ 58.4
[1]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.[2]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.[3]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.

DERIVATIVES (Narrative) (Detail

DERIVATIVES (Narrative) (Details)	12 Months Ended
	Dec. 31, 2022 USD ($) bbl	Dec. 31, 2021 USD ($) bbl	Dec. 31, 2020 USD ($)
Derivative [Line Items]
Gain (loss) on fair value hedge ineffectiveness | $	$ 0	$ 0	$ 0
Crude Oil and Feedstock Inventory | Fair Value Hedging
Derivative [Line Items]
Derivative, nonmonetary notional amount	1,945,994	2,081,783
Intermediates and Refined Products Inventory | Fair Value Hedging | Designated as Hedging Instrument
Derivative [Line Items]
Derivative, nonmonetary notional amount	780,734	2,070,550
Crude Oil Commodity Contract | Not Designated as Hedging Instrument
Derivative [Line Items]
Derivative, nonmonetary notional amount	17,890,000	36,246,000
Refined Product Commodity Contract | Not Designated as Hedging Instrument
Derivative [Line Items]
Derivative, nonmonetary notional amount	12,175,200	5,819,000

DERIVATIVES (Fair Value of Deri

DERIVATIVES (Fair Value of Derivative Instruments) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Designated as Hedging Instrument | Derivatives included within inventory intermediation agreement obligations | Accrued expenses
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	$ 25.1	$ 19.7
Not Designated as Hedging Instrument | Commodity contracts | Accounts receivable
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	$ 13.9	$ (12)

DERIVATIVES (Gain (Loss) Recogn

DERIVATIVES (Gain (Loss) Recognized in Income) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Cost of Revenue	Cost of Revenue	Cost of Revenue
Gain (loss) on fair value hedge ineffectiveness	$ 0	$ 0	$ 0
Designated as Hedging Instrument | Derivatives included within inventory intermediation agreement obligations
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	5,400,000	8,400,000	12,600,000
Designated as Hedging Instrument | Intermediates and Refined Products Inventory | Fair Value Hedging
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	(5,400,000)	(8,400,000)	(12,600,000)
Not Designated as Hedging Instrument | Commodity Contract
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	$ (31,500,000)	$ (83,400,000)	$ 44,400,000

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - Subsequent Event - USD ($) $ / shares in Units, $ in Millions	Feb. 16, 2023	Feb. 15, 2023
Eni SpA
Subsequent Event [Line Items]
Percentage of Ownership in Joint Venture		50%
Proceeds from Divestiture of Interest in Joint Venture		$ 835
Contingent Proceeds from Divestiture of Interest in Joint Venture		$ 50
PBF Energy Inc.
Subsequent Event [Line Items]
Percentage of Ownership in Joint Venture		50%
Class A Common Stock
Subsequent Event [Line Items]
Dividends declared per share	$ 0.20