PBF Finance 10-K 2 Mar 22 2021 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2021	Feb. 25, 2022	Jun. 30, 2021
Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2021
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 2022
Entity Central Index Key	0001566011
Amendment Flag	false
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2021
PBF Finance Corporation [Member]
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, 2021
Audit Information [Abstract]
Auditor Location	Parsippany, New Jersey
Auditor Name	Deloitte & Touche LLP
Auditor Firm ID	34

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 1,305.7	$ 1,570.1
Accounts receivable	1,272	501.5
Accounts receivable - affiliate	4.1	4.9
Inventories	2,505.1	1,686.2
Prepaid and other current assets	71.7	56.4
Total current assets	5,158.6	3,819.1
Property, plant and equipment, net	4,114.8	4,023.1
Lease right of use assets	1,202.4	1,487.7
Deferred charges and other assets, net	813.8	862.7
Total assets	11,289.6	10,192.6
Current liabilities:
Accounts payable	906.3	402.3
Accounts payable - affiliate	61.7	53.2
Accrued expenses	2,728.3	1,881.8
Deferred revenue	40.3	45.1
Current operating lease liabilities	155.5
Current debt	0	7.4
Total current liabilities	3,892.1	2,553.7
Long-term debt	3,673.3	3,932.8
Deferred tax liabilities	24.2	38.7
Long-term operating lease liabilities	965
Long-term finance lease liabilities	70.6	68.3
Other long-term liabilities	251	267
Total liabilities	8,876.2	8,101.8
Commitments and contingencies (Note 12)
Equity:
Member’s equity	2,870.2	2,809.7
Retained earnings (accumulated deficit)	(489.3)	(723.4)
Accumulated other comprehensive income (loss)	20.3	(6.1)
Total PBF Holding Company LLC equity	2,401.2	2,080.2
Noncontrolling interest	12.2	10.6
Total equity	2,413.4	2,090.8
Total liabilities and equity	11,289.6	10,192.6
Third Party Lease [Member]
Current assets:
Lease right of use assets	717	916.7
Current liabilities:
Current operating lease liabilities	64.8	78.3
Long-term operating lease liabilities	570.3	755.9
Long-term finance lease liabilities	70.6	68.3
Lease with Affiliate [Member]
Current assets:
Lease right of use assets	485.4	571
Current liabilities:
Current operating lease liabilities	90.7	85.6
Long-term operating lease liabilities	$ 394.7	$ 485.4

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Statement [Abstract]
Revenues	$ 27,202	$ 15,045	$ 24,468.9
Cost and expenses:
Cost of products and other	24,114.3	14,548.2	21,667.7
Operating expenses (excluding depreciation and amortization expense as reflected below)	1,999.1	1,835.2	1,684.3
Depreciation and amortization expense	415.7	498	386.7
Cost of sales	26,529.1	16,881.4	23,738.7
General and administrative expenses (excluding depreciation and amortization expense as reflected below)	226.4	229	258.7
Depreciation and amortization expense	13.3	11.3	10.8
Change in fair value of contingent consideration	29.4	(79.3)	0
Impairment expense	0	91.8	0
Equity income in investee	0	0	(7.9)
Gain on sale of assets	(0.2)	(477.8)	(29.9)
Total cost and expenses	26,798	16,656.4	23,970.4
Income (loss) from operations	404	(1,611.4)	498.5
Other income (expense):
Interest expense, net	(275.1)	(210.3)	(108.7)
Change in fair value of catalyst obligations	8.5	(11.8)	(9.7)
Gain (loss) on extinguishment of debt	79.9	(22.2)	0
Other non-service components of net periodic benefit cost	7.8	4.3	(0.2)
Income (loss) before income taxes	225.1	(1,851.4)	379.9
Income tax (benefit) expense	(14)	6.1	(8.3)
Net income (loss)	239.1	(1,857.5)	388.2
Less: net income (loss) attributable to noncontrolling interests	2.3	(0.3)	0
Net income (loss) attributable to PBF Holding Company LLC	$ 236.8	$ (1,857.2)	$ 388.2

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 239.1	$ (1,857.5)	$ 388.2
Other comprehensive income (loss):
Unrealized (loss) gain on available for sale securities	(0.7)	(0.1)	0.4
Net gain on pension and other post-retirement benefits	27.1	3.7	13.8
Total other comprehensive income	26.4	3.6	14.2
Comprehensive income (loss)	265.5	(1,853.9)	402.4
Less: comprehensive income (loss) attributable to noncontrolling interests	2.3	(0.3)	0
Comprehensive income (loss) attributable to PBF Holding Company LLC	$ 263.2	$ (1,853.6)	$ 402.4

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total	Member's Equity [Member]	Accumulated Other Comprehensive Loss [Member]	Retained Earnings [Member]	Noncontrolling Interest [Member]
Beginning balance at Dec. 31, 2018	$ 3,529.8	$ 2,652.5	$ (23.9)	$ 890.3	$ 10.9
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Member distributions	(121.6)			(121.6)
Capital contributions from PBF LLC	228.5	228.5
Distribution of assets to PBF LLC	(0.3)	(0.3)
Distribution of TVPC investment	(168.8)	(168.8)
Stock based compensation	27.2	27.2
Comprehensive income (loss)	402.4		14.2	388.2
Ending 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 (loss)	(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 (loss)	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

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash flows from operating activities:
Net income (loss)	$ 239.1	$ (1,857.5)	$ 388.2
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation and amortization	444.3	523.8	404.4
Impairment expense	0	91.8	0
Stock-based compensation	30.3	29.3	30.5
Change in fair value of catalyst obligations	(8.5)	11.8	9.7
Deferred income taxes	(14.5)	7.3	(8.8)
Non-cash change in inventory repurchase obligations	(8.4)	(12.6)	25.4
Non-cash lower of cost or market inventory adjustment	(669.6)	268	(250.2)
Change in fair value of contingent consideration	29.4	(79.3)	0
(Gain) loss on extinguishment of debt	(79.9)	22.2	0
Pension and other post-retirement benefit costs	50.8	55.7	44.8
Income from equity method investee	0	0	(7.9)
Distributions from equity method investee	0	0	7.9
Gain on sale of assets	(0.2)	(477.8)	(29.9)
Changes in operating assets and liabilities:
Accounts receivable	(770.5)	325.1	(115.9)
Due to/from affiliates	9.3	6.7	12.6
Inventories	(149.3)	392.2	(8)
Prepaid and other current assets	(15.3)	(3)	4.4
Accounts payable	480.1	(200.6)	132
Accrued expenses	806.9	111.5	209.5
Deferred revenue	(4.8)	28.2	(0.2)
Other assets and liabilities	(76.9)	(62.8)	(58.9)
Net cash provided by (used in) operating activities	292.3	(820)	789.6
Cash flows from investing activities:
Expenditures for property, plant and equipment	(240.5)	(183.9)	(373.1)
Expenditures for deferred turnaround costs	(117.7)	(188.1)	(299.3)
Expenditures for other assets	(28.9)	(9.1)	(44.7)
Acquisition of Martinez refinery	0	(1,176.2)	0
Proceeds from sale of assets	0	543.1	36.3
Equity method investment - return of capital	0	0	0.6
Net cash used in investing activities	(387.1)	(1,014.2)	(680.2)
Cash flows from financing activities:
Contributions from PBF LLC	37	42.4	228.5
Proceeds from revolver borrowings	0	1,450	1,350
Repayments of revolver borrowings	0	(550)	(1,350)
Settlements of precious metal catalyst obligations	(31.7)	(8.8)	(6.5)
Proceeds from catalyst financing arrangements	0	51.9	0
Payments on financing leases	(17.8)	(12.4)	0
Deferred financing costs and other	0.5	(34.7)	(1.4)
Net cash (used in) provided by financing activities	(169.6)	2,641.2	92
Net change in cash and cash equivalents	(264.4)	807	201.4
Cash and cash equivalents, beginning of period	1,570.1	763.1	561.7
Cash and cash equivalents, end of period	1,305.7	1,570.1	763.1
Non-cash activities:
Accrued and unpaid capital expenditures	103.2	31.1	36
Assets acquired or remeasured under operating and financing leases	(106.6)	702	1,194.3
Fair value of the Martinez Contingent Consideration at acquisition	0	77.3	0
Distribution of assets to PBF Energy Company LLC	0	0	169.1
Cash paid during the year for:
Interest (net of capitalized interest of $8.9, $11.9 and $17.6 in 2021, 2020 and 2019, respectively)	265.4	162.9	107
Capitalized interest	8.9	11.9	17.6
Income taxes	1	1	1.2
Collins Pipeline Company And T&M Terminal Company [Member]
Cash flows from financing activities:
Payments of Capital Distribution	(0.7)	0	0
Members
Cash flows from financing activities:
Payments of Capital Distribution	(2.7)	(23.1)	(121.6)
2025 Senior Secured Notes
Cash flows from financing activities:
Proceeds from Issuance of Long-term Debt	0	1,250.6	0
2028 Senior Notes [Member]
Cash flows from financing activities:
Proceeds from Issuance of Long-term Debt	0	1,000	0
Repayments of Long-term Debt	(109.3)	0	0
2025 Senior Notes [Member]
Cash flows from financing activities:
Repayments of Long-term Debt	(37.5)	0	0
2023 Senior Notes [Member]
Cash flows from financing activities:
Repayments of Long-term Debt	0	(517.5)	0
Rail Term Loan [Member]
Cash flows from financing activities:
Repayments of Long-term Debt	$ (7.4)	$ (7.2)	$ (7)

DESCRIPTION OF THE BUSINESS AND

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION	12 Months Ended
	Dec. 31, 2021
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” or the “Company”), 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 99.2% of the outstanding economic interest in PBF LLC as of December 31, 2021. Collectively, PBF Holding and its consolidated subsidiaries are referred to hereinafter as the “Company”. On May 14, 2014, PBF Logistics LP (“PBFX”), a Delaware master limited partnership, completed its initial public offering (the “PBFX Offering”). PBF Logistics GP LLC (“PBF GP”) serves as the general partner of PBFX. PBF GP is wholly-owned by PBF LLC. In connection with the PBFX Offering, PBF Holding contributed to PBFX the assets and liabilities of certain crude oil terminaling assets. In a series of additional transactions subsequent to the PBFX Offering, PBF Holding distributed certain additional assets to PBF LLC, which in turn contributed those assets to PBFX (as described in “Note 11 - Related Party Transactions”). Substantially all of the Company’s operations are in the United States. As of December 31, 2021, 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. COVID-19 and Market Developments The impact of the unprecedented global health and economic crisis sparked by the coronavirus (“COVID-19”) pandemic, and variants thereof, and related adverse impact on economic and commercial activity resulted in a significant reduction in demand for refined petroleum and petrochemical products starting in the first quarter of 2020. This significant demand reduction has had an adverse impact on the Company’s results of operations and liquidity position. Demand for these products, however, started to recover throughout the year ended December 31, 2021 in connection with the lifting or easing of restrictions by many governmental authorities and the distribution of COVID-19 vaccines and other protective measures. The Company has adjusted throughput rates across its entire refining system to correlate with the gradual increases in demand, while still running below historic levels. It is impossible to estimate the duration or significance of the financial impact that will result from the COVID-19 pandemic. However, the extent of the impact of the COVID-19 pandemic on the Company’s business, financial condition, results of operations and liquidity will depend largely on future developments, including the duration and severity of the pandemic, and variants thereof, particularly within the geographic areas where the Company operates, the effectiveness of vaccine programs, and the related impact on overall economic activity, all of which cannot be predicted with certainty at this time.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2021
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 year ended December 31, 2021 and December 31, 2020, only one customer, Shell plc (“Shell”), accounted for 10% or more of the Company’s revenues (approximately 15% and 13%, respectively). For the year ended December 31, 2019 no single customer amounted to greater than or equal to 10% of the Company’s revenues. As of December 31, 2021 and December 31, 2020, only one customer, Shell, accounted for 10% or more of the Company’s total trade accounts receivable (approximately 26% and 17%, 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 17 - 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 “Renewable Fuel Standard”). 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). Investments in Equity Method Investments For equity investments that are not required to be consolidated under the variable or voting interest model, the Company evaluates the level of influence it is able to exercise over an entity’s operations to determine whether to use the equity method of accounting. The Company’s judgment regarding the level of control over an equity method investment includes considering key factors such as its ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Amounts recognized for equity method investments are included in equity method investments in the consolidated balance sheet and adjusted for the Company’s share of the net earnings and losses of the investee and cash distributions, which are included in the consolidated statements of operations and the consolidated statements of cash flows. Amounts recognized for earnings in excess of distributions of the Company’s equity method investments are included in the operating section of the consolidated statements of cash flows. The Company evaluates its equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. A loss is recorded in earnings in the current period to write down the carrying value of the investment to fair value if a decline in the value of an equity method investment is determined to be other than temporary. 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 0% 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 2016 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 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 currently 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 exception. 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 amendments in this ASU are effective for all entities at any time beginning on March 12, 2020 through December 31, 2022 and may be applied from the beginning of an interim period that includes the issuance date of the ASU. The Company does not expect that the adoption of this guidance will have a material impact on its Consolidated Financial Statements and related disclosures.

ACQUISITIONS

ACQUISITIONS	12 Months Ended
	Dec. 31, 2021
Business Combination and Asset Acquisition [Abstract]
ACQUISITIONS	ACQUISITIONS Martinez Acquisition On February 1, 2020, the Company acquired from Equilon Enterprises LLC d/b/a Shell Oil Products US (the "Seller"), the Martinez refinery and related logistics assets (collectively, the "Martinez Acquisition"), pursuant to a sale and purchase agreement dated June 11, 2019 (the “Sale and Purchase Agreement”). The Martinez refinery, located in Martinez, California, is a high-conversion, dual-coking facility that is strategically positioned in Northern California and provides for operating and commercial synergies with the Torrance refinery located in Southern California. In addition to refining assets, the Martinez Acquisition includes a number of onsite logistics assets, including a deep-water marine facility, product distribution terminals and refinery crude and product storage facilities. The aggregate purchase price for the Martinez Acquisition was $1,253.4 million, including final working capital of $216.1 million and the Martinez Contingent Consideration, as defined below. The transaction was financed through a combination of cash on hand, including proceeds from the $1.0 billion in aggregate principal amount of 6.0% senior unsecured notes due 2028 (the “2028 Senior Notes”), and borrowings under PBF Holding’s asset-based revolving credit facility (the “Revolving Credit Facility”). The Company accounted for the Martinez Acquisition as a business combination under GAAP whereby it recognizes assets acquired and liabilities assumed in an acquisition at their estimated fair values as of the date of acquisition. The total purchase consideration and the fair values of the assets and liabilities at the acquisition date were as follows: (in millions) Purchase Price Gross purchase price $ 960.0 Working capital, including post close adjustments 216.1 Contingent consideration (a) 77.3 Total consideration $ 1,253.4 _______________________ (a) The Martinez Acquisition included an obligation for the Company to make post-closing earn-out payments to the Seller based on certain earnings thresholds of the Martinez refinery (as set forth in the Sale and Purchase Agreement), for a period of up to four years following the acquisition closing date (the “Martinez Contingent Consideration”). The Company recorded the Martinez Contingent Consideration based on its estimated fair value of $77.3 million at the acquisition date, which was recorded within “Other long-term liabilities” within the Consolidated Balance Sheets. Subsequent changes in the fair value of the Martinez Contingent Consideration are recorded in the Consolidated Statements of Operations. The following table summarizes the final amounts recognized for assets acquired and liabilities assumed as of the acquisition date: (in millions) Fair Value Allocation Inventories $ 224.1 Prepaid and other current assets 5.4 Property, plant and equipment 987.9 Operating lease right of use assets (a) 7.8 Financing lease right of use assets (a) 63.5 Deferred charges and other assets, net 63.7 Accrued expenses (1.4) Current operating lease liabilities (1.9) Current financing lease liabilities (b) (6.0) Long-term operating lease liabilities (5.9) Long-term financing lease liabilities (57.5) Other long-term liabilities - environmental obligation (26.3) Fair value of net assets acquired $ 1,253.4 _____________________________ (a) Operating and Financing lease right of use assets are recorded in Lease right of use assets - third party within the Consolidated Balance Sheets. (b) Current financing lease liabilities are recorded in Accrued expenses within the Consolidated Balance Sheets. The Company’s Consolidated Financial Statements for the year ended December 31, 2021 include the results of operations of the Martinez refinery and related logistics assets subsequent to the Martinez Acquisition whereas the same period in 2020 includes the results of operations of such assets from the date of the Martinez Acquisition on February 1, 2020 to December 31, 2020. On an unaudited pro-forma basis, the revenues and net income (loss) of the Company, assuming the acquisition had occurred on January 1, 2019, are shown below. The unaudited pro-forma information does not purport to present what the Company’s actual results would have been had the Martinez Acquisition occurred on January 1, 2019, nor is the financial information indicative of the results of future operations. The unaudited pro-forma financial information includes the depreciation and amortization expense related to the Martinez Acquisition and interest expense associated with the related financing. Year Ended December 31, 2020 (Unaudited, in millions) Pro-forma revenues $ 15,408.8 Pro-forma net loss attributable to PBF Holding (1,888.5) Acquisition Expenses There were no acquisition costs for the years ended December 31, 2021 and December 31, 2019. The Company incurred acquisition-related costs consisting primarily of consulting and legal expenses related to completed, pending and non-consummated acquisitions of $11.1 million for the year ended December 31, 2020. These costs are included in General and administrative expenses within the Consolidated Statements of Operations.

Credit Losses

Credit Losses	12 Months Ended
	Dec. 31, 2021
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. Following the widespread market disruption that has resulted from the COVID-19 pandemic, including resurgences and variants of the virus and related governmental responses, the Company has been performing ongoing credit reviews of its customers including monitoring for any negative credit events such as customer bankruptcy or insolvency events. As a result, the Company has adjusted payment terms or limited available trade credit for certain customers, as well as for customers within industries that are deemed to be at higher risk. 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, 2021 and December 31, 2020, respectively.

INVENTORIES

INVENTORIES	12 Months Ended
	Dec. 31, 2021
Inventory Disclosure [Abstract]
INVENTORIES	INVENTORIES Inventories consisted of the following: 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 December 31, 2020 (in millions) Titled Inventory Inventory Intermediation Agreements Total Crude oil and feedstocks $ 1,018.9 $ — $ 1,018.9 Refined products and blendstocks 933.7 266.5 1,200.2 Warehouse stock and other 136.7 — 136.7 $ 2,089.3 $ 266.5 $ 2,355.8 Lower of cost or market adjustment (572.4) (97.2) (669.6) Total inventories $ 1,516.9 $ 169.3 $ 1,686.2 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. 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 monthly at the daily 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, 2021, the replacement value of inventories exceeded the LIFO carrying value. 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 lower of cost or market (“LCM”) inventory reserve at December 31, 2021 in comparison with an LCM inventory reserve of $669.6 million at December 31, 2020. During the year ended December 31, 2020, the Company recorded an adjustment to value its inventories to the lower of cost or market which decreased income from operations by $268.0 million, reflecting the net change in the LCM inventory reserve from $401.6 million at December 31, 2019 to $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 was no decrement recorded during the year ended 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 6 - 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, 2021
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, 2021 December 31, 2020 Land $ 418.8 $ 418.8 Processing units, pipelines and equipment 4,326.8 4,191.4 Buildings and leasehold improvements 107.3 106.2 Computers, furniture and fixtures 168.1 155.6 Construction in progress 328.1 195.4 5,349.1 5,067.4 Less - Accumulated depreciation (1,234.3) (1,044.3) Total property, plant and equipment, net $ 4,114.8 $ 4,023.1 Depreciation expense for the years ended December 31, 2021, 2020 and 2019 was $192.3 million, $179.4 million and $140.7 million, respectively. The Company capitalized $8.9 million and $11.9 million in interest during 2021 and 2020, respectively, in connection with construction in progress. East Coast Refining Reconfiguration On December 31, 2020, the Company reconfigured the Delaware 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 the fourth quarter of 2020. Capital Project Abandonments In connection with the Company’s ongoing 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 the fourth quarter of 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 13 - Leases” for further information. Torrance Land Sales On December 30, 2020 and August 1, 2019, the Company closed on third-party sales of parcels of real property acquired as part of the Torrance refinery, but not part of the refinery itself. The sales resulted in a gain of approximately $8.1 million and $33.1 million in the fourth quarter of 2020 and the third quarter of 2019, respectively, 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, 2021
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, 2021 December 31, 2020 Deferred turnaround costs, net $ 537.0 $ 598.2 Catalyst, net (a) 166.8 155.2 Environmental credits 41.3 39.6 Linefill 27.4 27.4 Pension plan assets 20.7 21.2 Intangible assets, net 0.5 0.5 Other 20.1 20.6 Total deferred charges and other assets, net $ 813.8 $ 862.7 (a) Catalyst, net includes $113.0 million and $115.2 million of indefinite-lived precious metal catalysts (both owned or financed as part of existing catalyst financing arrangements) as of December 31, 2021 and December 31, 2020, respectively. The Company recorded amortization expense related to deferred turnaround costs, catalyst and intangible assets of $220.6 million, $315.7 million and $256.8 million for the years ended December 31, 2021, 2020 and 2019, 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 primarily consists of permits and emission credits. Our net balance as of December 31, 2021 and December 31, 2020 is shown below: (in millions) December 31, 2021 December 31, 2020 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, 2021
Payables and Accruals [Abstract]
ACCRUED EXPENSES	ACCRUED EXPENSES Accrued expenses consisted of the following: (in millions) December 31, 2021 December 31, 2020 Inventory-related accruals $ 959.9 $ 695.0 Renewable energy credit and emissions obligations (a) 953.9 528.1 Inventory intermediation agreements (b) 280.1 225.8 Excise and sales tax payable 112.3 119.7 Accrued transportation costs 91.0 72.1 Accrued utilities 73.0 58.6 Accrued capital expenditures 62.6 14.4 Accrued salaries and benefits 57.1 40.1 Accrued refinery maintenance and support costs 55.8 35.7 Accrued interest 32.8 40.2 Environmental liabilities 14.3 11.4 Current finance lease liabilities 11.1 14.4 Customer deposits 3.5 4.0 Other 20.9 22.3 Total accrued expenses $ 2,728.3 $ 1,881.8 (a) The Company is subject to obligations to purchase RINs required to comply with the Renewable Fuel Standard. The Company’s overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by 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, 2021, the Company had entered into $520.0 million of such forward purchase commitments with respect to its total accrued renewable energy and emissions obligations. Final settlement of the Company’s RINs obligation for annual compliance years 2020 through 2022 are subject to final rule making by EPA. Currently, the 2020 obligation is anticipated to require settlement in 2022 and the 2021 and 2022 obligations are anticipated to require settlement in 2023. 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 inventory intermediation agreements with J. Aron. As of December 31, 2021 and December 31, 2020, a liability is recognized for the inventory intermediation agreements and is recorded at market price for the J. Aron owned inventory held in the Company’s Storage Tanks, with any change in the market price being recorded in Cost of products and other.

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, 2021 December 31, 2020 2025 Senior Secured Notes $ 1,250.0 $ 1,250.0 2028 Senior Notes 826.5 1,000.0 2025 Senior Notes 669.5 725.0 Revolving Credit Facility 900.0 900.0 PBF Rail Term Loan — 7.4 Catalyst financing arrangements 58.4 102.5 3,704.4 3,984.9 Less - Current debt — (7.4) Unamortized premium 0.5 0.6 Unamortized deferred financing costs (31.6) (45.3) Long-term debt $ 3,673.3 $ 3,932.8 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 are treated as a single series with the initial 2025 Senior Secured Notes and have 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 are guaranteed on a senior secured basis by substantially all of PBF Holding’s subsidiaries. The 2025 Senior Secured Notes and guarantees are 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 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 are 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 2028 Senior Notes and the 7.25% senior unsecured notes due 2025 (the “2025 Senior Notes”). The 2025 Senior Secured Notes and guarantees rank 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 are 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 are structurally subordinated to any existing or future indebtedness and other obligations of the Issuers’ non-guarantor subsidiaries. In addition, the 2025 Senior Secured 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 2025 Senior Secured Notes are rated investment grade. At any time prior to May 15, 2022, the Issuers may on any one or more occasions redeem up to 35% of the aggregate principal amount of the 2025 Senior Secured Notes in an amount not greater than the net cash proceeds of certain equity offerings at a redemption price equal to 109.250% of the principal amount of the 2025 Senior Secured Notes, plus any accrued and unpaid interest through the date of redemption. On or after May 15, 2022, the Issuers may redeem all or part of the 2025 Senior Secured 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 May 15, 2022, the Issuers may redeem all or part of the 2025 Senior Secured Notes at a “make-whole” redemption price described in the indenture, together with any accrued and unpaid interest to the date of redemption. In addition, the Issuers may redeem in the aggregate up to 35% of the original aggregate principal amount of the 2025 Senior Secured Notes using net proceeds of any loan received pursuant to a Regulatory Debt Facility (as defined in the indenture) at a redemption price equal to 104.625% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date as long as any such redemption occurs on or prior to 120 days after receipt of such net proceeds. 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 6.00% 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 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 PBF Holding’s 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 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 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 2, 2018, PBF Holding and certain of its wholly-owned subsidiaries, as borrowers or subsidiary guarantors, replaced the existing asset-based revolving credit facility dated as of August 15, 2014 with the new Revolving Credit Facility. The Revolving Credit Facility has a maximum commitment of $3.4 billion, a maturity date of May 2023 and redefines certain components of the Borrowing Base, as defined in the agreement governing the Revolving Credit Facility (the “Revolving Credit Agreement”), to make more funding available for working capital needs and other general corporate purposes. An accordion feature allows for commitments of up to $3.5 billion. Borrowings under the Revolving Credit Facility bear interest at the Alternative Base Rate plus the Applicable Margin or at the Adjusted LIBOR 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 Adjusted LIBOR 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. Outstanding borrowings under the Revolving Credit Facility as of December 31, 2021 and 2020 were $900.0 million. Issued letters of credit were $380.1 million and $184.4 million, as of December 31, 2021 and 2020, respectively. PBF Rail Term Loan On December 22, 2016, PBF Rail Logistics Company LLC (“PBF Rail”) entered into a $35.0 million term loan (the “PBF Rail Term Loan”). The PBF Rail Term Loan amortized monthly over its five year term and bore interest at a rate equal to one month LIBOR plus the margin as defined in the agreement governing the PBF Rail Term Loan (the “Rail Credit Agreement”). As security for the PBF Rail Term Loan, PBF Rail pledged, among other things: (i) certain Eligible Railcars; (ii) the Debt Service Reserve Account (as defined in the Rail Credit Agreement); and (iii) PBF Holding’s membership interest in PBF Rail. Additionally, the Rail Credit Agreement contained customary terms, events of default and covenants for transactions of this nature. PBF Rail may at any time repay the PBF Rail Term Loan without penalty in the event that railcars securing the loan are sold, scrapped or otherwise removed from the collateral pool. The PBF Rail Term Loan was repaid in full as of December 31, 2021. 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 substantial market for precious metal catalysts and that it will be able 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, 2021 are included in the following table: Refinery Metal Annual interest rate Expiration date (1) Paulsboro Platinum 1.47 % December 2022 Delaware City Palladium 3.70 % September 2022 Toledo Platinum 5.05 % September 2022 Chalmette Platinum 5.10 % November 2022 Chalmette Platinum 1.80 % November 2022 Torrance Platinum 1.78 % July 2022 Martinez Palladium 3.70 % September 2022 __________________ (1) These catalyst financing arrangements are included in Long-term debt as of December 31, 2021 as the Company has the ability and intent to finance this debt through availability under other credit facilities if the catalyst financing arrangements are not renewed at maturity. In total, aggregate annual catalyst financing fees were approximately $2.0 million and $2.7 million as of December 31, 2021 and 2020, respectively. Debt Maturities Debt maturing in the next five years and thereafter is as follows (in millions): Year Ending December 31, 2022 $ 58.4 2023 900.0 2024 — 2025 1,919.5 2026 — Thereafter 826.5 Total debt outstanding $ 3,704.4

OTHER LONG-TERM LIABILITIES

OTHER LONG-TERM LIABILITIES	12 Months Ended
	Dec. 31, 2021
Other Liabilities Disclosure [Abstract]
OTHER LONG-TERM LIABILITIES	OTHER LONG-TERM LIABILITIES Other long-term liabilities consisted of the following: (in millions) December 31, 2021 December 31, 2020 Environmental liabilities $ 141.0 $ 140.5 Defined benefit pension plan liabilities 46.7 73.5 Contingent consideration 29.4 — Post-retirement medical plan liabilities 18.2 22.0 Early railcar return liability 6.0 13.9 Other 9.7 17.1 Total other long-term liabilities $ 251.0 $ 267.0

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2021
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONS 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, 2021 and 2020. The Contribution Agreement entered into during the year ended 2019 includes the following: Contribution Agreement Effective Date Assets Contributed Total Consideration Contribution Agreement XI 4/24/2019 Remaining 50% equity interest in TVPC (a) $200.0 million (a) On April 24, 2019, PBFX entered into a contribution agreement with PBF LLC, pursuant to which the Company contributed to PBF LLC, which in turn contributed to PBFX, all of the issued and outstanding limited liability company interests of TVP Holding Company LLC (“TVP Holding”) for total consideration of $200.0 million (the “TVPC Acquisition”). Prior to the TVPC Acquisition, TVP Holding (then a subsidiary of PBF Holding) owned a 50% equity interest in Torrance Valley Pipeline Company LLC (“TVPC”). Subsequent to the closing of the TVPC Acquisition on May 31, 2019, PBFX owns 100% of the equity interest in TVPC. Refer to the Company’s 2019 Annual Report on Form 10-K (“Note 9 - Related Party Transactions” of the Notes to Consolidated Financial Statements) for a more complete description of the Contribution Agreements with PBFX that were entered into prior to 2019. 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. These commercial agreements (as defined in the table below) with PBFX include: Agreements Initiation Date Initial Term Renewals (a) MVC Force Majeure Transportation and Terminaling Amended and Restated Rail Agreements (b) 5/8/2014 7 years, 8 months N/A 125,000 bpd PBF Holding or PBFX can declare Toledo Truck Unloading & Terminaling Services Agreement (c) 5/8/2014 7 years, 8 months 2 x 5 5,500 bpd Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility (c) 12/12/2014 10 years 2 x 5 4,400 bpd 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 (d) See note (d) 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 (e) 5/1/2016 Various (f) Evergreen 15,000 bpd (g) East Coast Terminals Tank Lease Agreements 5/1/2016 Various (f) Evergreen 350,000 barrels (h) Torrance Valley Pipeline Transportation Services Agreement- North Pipeline (c) 8/31/2016 10 years 2 x 5 50,000 bpd Torrance Valley Pipeline Transportation Services Agreement- South Pipeline (c) 8/31/2016 10 years 2 x 5 75,000 bpd (i) Torrance Valley Pipeline Transportation Services Agreement- Midway Storage Tank (c) 8/31/2016 10 years 2 x 5 55,000 barrels (h) Torrance Valley Pipeline Transportation Services Agreement- Emidio Storage Tank (c) 8/31/2016 10 years 2 x 5 900,000 barrels per month Torrance Valley Pipeline Transportation Services Agreement- Belridge Storage Tank (c) 8/31/2016 10 years 2 x 5 770,000 barrels per month Paulsboro Natural Gas Pipeline Services Agreement (c) 8/4/2017 15 years Evergreen 60,000 dekatherms per day Knoxville Terminals Agreement- Terminaling Services 4/16/2018 5 years Evergreen Various (j) Knoxville Terminals Agreement- Storage Services 4/16/2018 5 years Evergreen 115,334 barrels (h) Toledo Rail Loading Agreement (c) 7/31/2018 7 years, 5 months 2 x 5 Various (k) 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 (c) 7/31/2018 7 years, 5 months 2 x 5 5,000 bpd Delaware City Terminaling Services Agreement (l) 1/1/2022 4 years 2 x 5 95,000 bpd Storage Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility (c) 12/12/2014 10 years 2 x 5 3,849,271 barrels (h) PBF Holding or PBFX can declare Chalmette Storage Agreement (c) See note (m) 10 years 2 x 5 625,000 barrels (h) East Coast Storage Assets Terminal Storage Agreement (c) 1/1/2019 8 years Evergreen 2,953,725 barrels (h) ____________________ (a) PBF Holding has the option to extend the agreements for up to two additional five-year terms, as applicable. (b) The Amended and Restated Rail Agreements, as amended and effective as of January 1, 2018, include the Amended and Restated Delaware City Rail Terminaling Services Agreement and the Amended and Restated Delaware West Ladder Rack Terminaling Services Agreement, each between Delaware City Terminaling Company LLC (“DCTC”) and PBF Holding, with the service fees thereunder being adjusted, including the addition of an ancillary fee paid by PBF Holding on an actual cost basis. In determining payments due under the Amended and Restated Rail Agreements, excess volumes throughput under the agreements shall apply against required payments in respect to the minimum throughput commitments on a quarterly basis and, to the extent not previously applied, on an annual basis against the MVCs. Effective January 1, 2019, the existing Amended and Restated Rail Agreements were further amended for the inclusion of services through certain rail infrastructure at the PBFX East Coast storage facility. (c) These commercial agreements with PBFX are considered leases. (d) 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. (e) 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. (f) The East Coast Terminals related party agreements include varying initial term lengths, ranging from one (g) 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. (h) 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. (i) In connection with the TVPC Acquisition 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. (j) 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. (k) 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. (l) The Delaware City Terminaling Services Agreement between DCTC and PBF Holding commenced on January 1, 2022 subsequent to the expiration of the Amended and Restated Rail Agreements and includes additional services provided by PBFX as operator of other rail facilities owned by PBF Holding’s subsidiaries. (m) 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, 2021 was $7.3 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, 2021. 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, 2022. 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, 2021, 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) 2021 2020 2019 Reimbursements under affiliate agreements: Services Agreement $ 8.7 $ 8.7 $ 8.6 Omnibus Agreement 7.3 7.6 7.7 Total expenses under affiliate agreements 304.1 289.4 300.9 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, 2021
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 ASC 842 and disclosed in “Note 13 - 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) 2022 $ 150.2 2023 125.2 2024 112.0 2025 108.3 2026 21.4 Thereafter 205.0 Total obligations $ 722.1 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 $118.5 million as of December 31, 2021 ($113.7 million as of December 31, 2020) and related primarily to remediation obligations to address existing soil and groundwater contamination and the related monitoring and clean-up activities. Costs related to these obligations are reassessed periodically or when changes to our remediation approach are identified. The current portion of the environmental liability is recorded in Accrued expenses and the non-current portion is recorded in Other long-term liabilities. The Company expects to make aggregate payments for this liability of approximately $49.2 million over the next five years. The aggregate environmental liability reflected in the Company’s Consolidated Balance Sheets was $155.3 million and $151.9 million at December 31, 2021 and December 31, 2020, respectively, of which $141.0 million and $140.5 million, respectively, were classified as Other long-term liabilities. These liabilities include remediation and monitoring costs expected to be incurred over an extended period of time. Estimated liabilities could increase in the future when the results of ongoing investigations become known, are considered probable and can be reasonably estimated. 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 Renewable Fuel Standard. Pursuant to the Energy Policy Act of 2005 and the Energy Independence and Security Act of 2007, EPA has issued the Renewable Fuel Standard, implementing mandates to blend renewable fuels into the petroleum fuels produced and sold in the United States. Under the Renewable Fuel Standard, 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 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. EPA’s proposed volumes of renewable fuels that obligated refineries must blend into their final petroleum fuels are expected to be finalized by the end of the first quarter of 2022. 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 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 Renewable Fuel Standard 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 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 Seller 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 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 value of the Martinez Contingent Consideration was estimated to be $29.4 million as of December 31, 2021 and zero as of December 31, 2020. 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 99.2% interest in PBF LLC as of December 31, 2021 (99.2% as of December 31, 2020). 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, 2021, PBF Energy recognized $48.3 million liability for the Tax Receivable Agreement, reflecting the estimate of the undiscounted amounts that PBF Energy expects to pay under the agreement, net of the impact of a deferred tax asset valuation allowance recognized in accordance with ASC 470, Income Taxes .

LEASES (Notes)

LEASES (Notes)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Lessee, Finance Leases	LEASES Lease Position as of December 31, 2021 and December 31, 2020 The table below presents the lease related assets and liabilities recorded on the Company’s Consolidated Balance Sheets as of December 31, 2021 and December 31, 2020: (in millions) Classification on the Balance Sheet December 31, 2021 December 31, 2020 Assets Operating lease assets - third party Lease right of use assets - third party $ 635.8 $ 836.3 Operating lease assets - affiliate Lease right of use assets - affiliate 485.4 571.0 Finance lease assets Lease right of use assets - third party 81.2 80.4 Total lease right of use assets $ 1,202.4 $ 1,487.7 Liabilities Current liabilities: Operating lease liabilities - third party Current operating lease liabilities - third party $ 64.8 $ 78.3 Operating lease liabilities - affiliate Current operating lease liabilities - affiliate 90.7 85.6 Finance lease liabilities - third party Accrued expenses 11.1 14.4 Noncurrent liabilities: Operating lease liabilities - third party Long-term operating lease liabilities - third party 570.3 755.9 Operating lease liabilities - affiliate Long-term operating lease liabilities - affiliate 394.7 485.4 Finance lease liabilities - third party Long-term financing lease liabilities - third party 70.6 68.3 Total lease liabilities $ 1,202.2 $ 1,487.9 Lease Costs The table below presents certain information related to costs for the Company’s leases for the year ended December 31, 2021 and December 31, 2020: Lease Costs (in millions) December 31, 2021 December 31, 2020 Components of total lease costs: Finance lease costs Amortization of right of use assets $ 16.1 $ 14.0 Interest on lease liabilities 4.6 4.3 Operating lease costs 299.1 291.2 Short-term lease costs 59.3 92.3 Variable lease costs 31.6 31.1 Total lease costs $ 410.7 $ 432.9 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, 2021. Other Information The table below presents supplemental cash flow information related to leases for the year ended December 31, 2021 and December 31, 2020 (in millions): Years Ended December 31, 2021 2020 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows for operating leases $ 297.9 $ 292.4 Operating cash flows for finance leases 4.6 4.3 Financing cash flows for finance leases 17.8 12.4 Supplemental non-cash amounts of lease liabilities arising from obtaining or remeasuring right-of-use assets (106.6) 702.0 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, 2021: Weighted average remaining lease term - operating leases 9.8 years Weighted average remaining lease term - finance leases 6.5 years Weighted average discount rate - operating leases 13.4 % Weighted average discount rate - finance leases 7.4 % 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, 2021: Amounts due in the year ended December 31, (in millions) Finance Leases Operating Leases 2022 $ 16.5 $ 280.6 2023 16.4 252.4 2024 15.7 243.0 2025 14.2 202.3 2026 13.8 166.0 Thereafter 25.6 903.9 Total minimum lease payments 102.2 2,048.2 Less: effect of discounting 20.5 927.7 Present value of future minimum lease payments 81.7 1,120.5 Less: current obligations under leases 11.1 155.5 Long-term lease obligations $ 70.6 $ 965.0 As of December 31, 2021, the Company has entered into certain leases that have not yet commenced. Such leases include a 15-year lease for water treatment equipment, with future lease payments estimated to total approximately $34.1 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
Lessee, Operating Leases	LEASES Lease Position as of December 31, 2021 and December 31, 2020 The table below presents the lease related assets and liabilities recorded on the Company’s Consolidated Balance Sheets as of December 31, 2021 and December 31, 2020: (in millions) Classification on the Balance Sheet December 31, 2021 December 31, 2020 Assets Operating lease assets - third party Lease right of use assets - third party $ 635.8 $ 836.3 Operating lease assets - affiliate Lease right of use assets - affiliate 485.4 571.0 Finance lease assets Lease right of use assets - third party 81.2 80.4 Total lease right of use assets $ 1,202.4 $ 1,487.7 Liabilities Current liabilities: Operating lease liabilities - third party Current operating lease liabilities - third party $ 64.8 $ 78.3 Operating lease liabilities - affiliate Current operating lease liabilities - affiliate 90.7 85.6 Finance lease liabilities - third party Accrued expenses 11.1 14.4 Noncurrent liabilities: Operating lease liabilities - third party Long-term operating lease liabilities - third party 570.3 755.9 Operating lease liabilities - affiliate Long-term operating lease liabilities - affiliate 394.7 485.4 Finance lease liabilities - third party Long-term financing lease liabilities - third party 70.6 68.3 Total lease liabilities $ 1,202.2 $ 1,487.9 Lease Costs The table below presents certain information related to costs for the Company’s leases for the year ended December 31, 2021 and December 31, 2020: Lease Costs (in millions) December 31, 2021 December 31, 2020 Components of total lease costs: Finance lease costs Amortization of right of use assets $ 16.1 $ 14.0 Interest on lease liabilities 4.6 4.3 Operating lease costs 299.1 291.2 Short-term lease costs 59.3 92.3 Variable lease costs 31.6 31.1 Total lease costs $ 410.7 $ 432.9 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, 2021. Other Information The table below presents supplemental cash flow information related to leases for the year ended December 31, 2021 and December 31, 2020 (in millions): Years Ended December 31, 2021 2020 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows for operating leases $ 297.9 $ 292.4 Operating cash flows for finance leases 4.6 4.3 Financing cash flows for finance leases 17.8 12.4 Supplemental non-cash amounts of lease liabilities arising from obtaining or remeasuring right-of-use assets (106.6) 702.0 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, 2021: Weighted average remaining lease term - operating leases 9.8 years Weighted average remaining lease term - finance leases 6.5 years Weighted average discount rate - operating leases 13.4 % Weighted average discount rate - finance leases 7.4 % 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, 2021: Amounts due in the year ended December 31, (in millions) Finance Leases Operating Leases 2022 $ 16.5 $ 280.6 2023 16.4 252.4 2024 15.7 243.0 2025 14.2 202.3 2026 13.8 166.0 Thereafter 25.6 903.9 Total minimum lease payments 102.2 2,048.2 Less: effect of discounting 20.5 927.7 Present value of future minimum lease payments 81.7 1,120.5 Less: current obligations under leases 11.1 155.5 Long-term lease obligations $ 70.6 $ 965.0 As of December 31, 2021, the Company has entered into certain leases that have not yet commenced. Such leases include a 15-year lease for water treatment equipment, with future lease payments estimated to total approximately $34.1 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, 2021
Equity [Abstract]
EQUITY STRUCTURE	EQUITY STRUCTURE PBF Holding has no common stock outstanding. As of December 31, 2021, 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, 2021
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) 2021 2020 2019 PBF Energy options $ 17.3 $ 16.1 $ 15.8 PBF Energy restricted shares 2.8 5.3 6.5 PBF Energy performance awards 10.2 7.9 8.2 $ 30.3 $ 29.3 $ 30.5 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, 2021 December 31, 2020 December 31, 2019 Expected life (in years) 6.00 6.08 6.25 Expected volatility 83.8 % 69.1 % 38.6 % Dividend yield 0.00 % 1.41 % 3.54 % Risk-free rate of return 1.37 % 0.81 % 2.16 % Exercise price $ 13.91 $ 13.58 $ 34.11 Weighted average fair value per option granted $ 9.84 $ 5.49 $ 9.43 The following table summarizes activity for PBF Energy options for 2021: Number of Weighted Weighted Stock-based awards, outstanding at January 1, 2021 13,790,777 $ 25.69 7.12 Granted 1,700,621 13.91 10.00 Exercised (52,400) 6.72 — Forfeited (389,239) 23.70 — Outstanding at December 31, 2021 15,049,759 $ 24.48 6.51 Exercisable and vested at December 31, 2021 9,397,483 $ 27.72 5.26 Expected to vest at December 31, 2021 15,049,759 $ 24.48 6.51 At December 31, 2021 the total intrinsic value of stock options outstanding and exercisable were $15.6 million and $5.0 million, respectively. The total intrinsic value of stock options exercised during the years ended December 31, 2021, 2020 and 2019 was $0.4 million, $0.0 million and $0.3 million, respectively. Unrecognized compensation expense related to PBF Energy options at December 31, 2021 was $36.7 million, which will be recognized from 2022 through 2024. 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 four 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, 2021 303,555 $ 22.32 Granted 81,840 16.13 Vested (229,462) 24.34 Forfeited (246) 24.18 Nonvested at December 31, 2021 155,687 $ 16.09 Unrecognized compensation expense related to PBF Energy Restricted Class A common stock at December 31, 2021 was $0.1 million, which will be recognized from 2022 through 2023. The following table reflects activity related to our restricted stock: December 31, 2021 December 31, 2020 December 31, 2019 Weighted-average grant-date fair value per share of restricted stock granted $ 16.13 $ 9.82 $ 28.20 Fair value of restricted stock vested (in millions) $ 3.1 $ 4.2 $ 11.6 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, 2021 December 31, 2020 December 31, 2019 Expected life (in years) 3.12 2.89 - 3.14 2.17 - 2.88 Expected volatility 83.78 % 39.88% - 82.63% 37.19% - 41.70% Dividend yield 0.00 % 0.00% - 4.28% 3.40% - 3.67% Risk-free rate of return 0.87 % 0.26% - 1.34% 1.66% - 2.51% Weighted average grant-date fair value per PSU $ 18.73 $ 10.77 $ 27.99 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, 2021 623,160 $ 15.62 Granted 301,965 18.73 Vested (179,600) 27.85 Nonvested at December 31, 2021 745,525 $ 13.93 In 2021 and 2020, PSU’s with a fair value of $1.8 million and $0.8 million, respectively, were vested. As of December 31, 2021, unrecognized compensation cost related to performance share unit awards was $8.2 million, which is expected to be recognized over a weighted average period of 2.63 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, 2021 16,071,745 Granted 11,782,926 Vested (7,676,658) Nonvested at December 31, 2021 20,178,013 In 2021 and 2020, Performance Units with a fair value of $5.2 million and $3.2 million, respectively, were vested. As of December 31, 2021, unrecognized compensation cost related to performance unit awards was $9.2 million, which is expected to be recognized over a weighted average period of 2.54 years.

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	12 Months Ended
	Dec. 31, 2021
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 $27.8 million, $32.7 million, and $27.5 million for the years ended December 31, 2021, 2020 and 2019, 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, 2021 and 2020 were as follows: Pension Plans Post-Retirement (in millions) 2021 2020 2021 2020 Change in benefit obligation: Benefit obligation at beginning of year $ 329.3 $ 271.2 $ 22.0 $ 17.5 Service cost 57.5 59.0 1.1 1.0 Interest cost 5.3 6.9 0.3 0.4 Plan amendments — — — 1.8 Benefit payments (31.2) (18.0) (1.2) (0.6) Actuarial (gain) loss (7.6) 10.2 (4.0) 1.9 Projected benefit obligation at end of year $ 353.3 $ 329.3 $ 18.2 $ 22.0 Change in plan assets: Fair value of plan assets at beginning of year $ 255.8 $ 197.4 $ — $ — Actual return on plan assets 27.7 28.6 — — Benefits paid (31.2) (18.0) (1.2) (0.6) Employer contributions 54.0 47.8 1.2 0.6 Fair value of plan assets at end of year $ 306.3 $ 255.8 $ — $ — Reconciliation of funded status: Fair value of plan assets at end of year $ 306.3 $ 255.8 $ — $ — Less benefit obligations at end of year 353.3 329.3 18.2 22.0 Funded status at end of year $ (47.0) $ (73.5) $ (18.2) $ (22.0) The accumulated benefit obligation for the defined benefit plans approximated $298.9 million and $281.5 million at December 31, 2021 and 2020, 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 2022 $ 24.8 $ 1.8 2023 18.1 1.7 2024 20.1 1.6 2025 23.7 1.5 2026 27.1 1.5 Years 2027-2031 168.6 6.8 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 $35.6 million to the Company’s Pension Plans during 2022. The components of net periodic benefit cost were as follows for the years ended December 31, 2021, 2020 and 2019: Pension Benefits Post-Retirement (in millions) 2021 2020 2019 2021 2020 2019 Components of net periodic benefit cost: Service cost $ 57.5 $ 59.0 $ 43.6 $ 1.1 $ 1.0 $ 1.0 Interest cost 5.3 6.9 8.3 0.3 0.4 0.7 Expected return on plan assets (14.2) (12.5) (9.6) — — — Amortization of prior service cost and actuarial loss 0.1 0.3 0.3 0.7 0.6 0.5 Net periodic benefit cost $ 48.7 $ 53.7 $ 42.6 $ 2.1 $ 2.0 $ 2.2 Lump sum payments made by the Supplemental Plan to employees retiring in 2021, 2020 and 2019 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, 2021, 2020, and 2019 were as follows: Pension Benefits Post-Retirement (in millions) 2021 2020 2019 2021 2020 2019 Prior service costs $ — $ — $ — $ — $ 1.8 $ — Net actuarial (gain) loss (21.1) (5.9) (10.7) (4.0) 1.9 (2.3) Amortization of losses and prior service cost (0.1) (0.3) (0.3) (0.7) (0.6) (0.5) Total changes in other comprehensive (income) loss $ (21.2) $ (6.2) $ (11.0) $ (4.7) $ 3.1 $ (2.8) The pre-tax amounts in accumulated other comprehensive income (loss) as of December 31, 2021 and 2020 that have not yet been recognized as components of net periodic costs were as follows: Pension Benefits Post-Retirement (in millions) 2021 2020 2021 2020 Prior service costs $ (0.5) $ (0.6) $ (4.3) $ (5.0) Net actuarial gain (loss) 12.7 (8.4) 7.8 3.9 Total $ 12.2 $ (9.0) $ 3.5 $ (1.1) The weighted average assumptions used to determine the benefit obligations as of December 31, 2021 and 2020 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2021 2020 2021 2020 2021 2020 Discount rate - benefit obligations 2.78 % 2.36 % 2.73 % 2.21 % 2.46 % 1.90 % Rate of compensation increase 4.26 % 4.28 % 4.50 % 4.50 % — — The weighted average assumptions used to determine the net periodic benefit costs for the years ended December 31, 2021, 2020 and 2019 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2021 2020 2019 2021 2020 2019 2021 2020 2019 Discount rates: Effective rate for service cost 2.40% 2.94% 4.24% 2.26% 2.79% 4.19% 2.35% 2.86% 4.21% Effective rate for interest cost 1.74% 2.50% 3.92% 1.53% 2.33% 3.83% 1.28% 2.21% 3.69% Effective rate for interest on service cost 1.92% 2.59% 4.00% 1.75% 2.42% 3.90% 2.11% 2.68% 4.09% Cash balance interest credit rate 1.57% 2.19% 3.34% 1.57% 2.19% 3.34% N/A N/A N/A Expected long-term rate of return on plan assets 5.25% 5.75% 6.00% N/A N/A N/A N/A N/A N/A Rate of compensation increase 4.28% 4.28% 4.55% 4.50% 4.50% 5.00% N/A N/A N/A The assumed health care cost trend rates as of December 31, 2021 and 2020 were as follows: Post-Retirement 2021 2020 Health care cost trend rate assumed for next year 5.2 % 5.4 % Rate to which the cost trend rate was assumed to decline (the ultimate trend rate) 4.0 % 4.5 % Year that the rate reaches the ultimate trend rate 2046 2038 The table below presents the fair values of the assets of the Company’s Qualified Plan as of December 31, 2021 and 2020 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) 2021 2020 Equities: Domestic equities $ 73.9 $ 64.4 Developed international equities 37.7 38.2 Global low volatility equities 24.1 22.5 Emerging market equities 24.8 20.7 Fixed-income 121.6 95.7 Real Estate 23.2 13.3 Cash and cash equivalents 1.0 1.0 Total $ 306.3 $ 255.8 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, 2021, 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, 2021
Revenues [Abstract]
REVENUES	REVENUES Revenue Recognition In accordance with FASB ASC Topic 606, Revenue from Contracts with Customer (“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) 2021 2020 2019 Gasoline and distillates $ 23,489.5 $ 12,799.4 $ 21,278.4 Feedstocks and other 1,310.1 935.5 806.9 Asphalt and blackoils 1,217.8 777.9 1,426.4 Chemicals 889.8 351.5 682.3 Lubricants 294.8 180.7 274.9 Total Revenues $ 27,202.0 $ 15,045.0 $ 24,468.9 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 $40.3 million and $45.1 million as of December 31, 2021 and December 31, 2020, 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, 2021
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, 2021 December 31, 2020 December 31, 2019 Current income tax expense (benefit) $ 0.5 $ (1.2) $ 0.5 Deferred income tax (benefit) expense (14.5) 7.3 (8.8) Total income tax (benefit) expense $ (14.0) $ 6.1 $ (8.3) A summary of the components of PBF Holding’s deferred tax assets and deferred tax liabilities consists of the following: (in millions) December 31, 2021 December 31, 2020 Deferred tax assets Net operating loss carry forwards $ 0.3 $ 0.1 Other 0.5 — Total deferred tax assets 0.8 0.1 Valuation allowance — — Total deferred tax assets, net 0.8 0.1 Deferred tax liabilities Property, plant and equipment 16.3 17.5 Inventory 8.7 21.3 Total deferred tax liabilities 25.0 38.8 Net deferred tax liability $ (24.2) $ (38.7)

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Dec. 31, 2021
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, 2021 and 2020. 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, 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 As of December 31, 2020 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 $ 402.3 $ — $ — $ 402.3 N/A $ 402.3 Commodity contracts 2.5 3.5 — 6.0 (6.0) — Derivatives included within inventory intermediation agreement obligations — 11.3 — 11.3 — 11.3 Liabilities: Commodity contracts 2.3 6.7 — 9.0 (6.0) 3.0 Catalyst obligations — 102.5 — 102.5 — 102.5 Contingent consideration obligation — — — — — — 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, 2021 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, 2021 and 2020, $20.7 million and $21.2 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) 2021 2020 Balance at beginning of period $ — $ — Additions — 77.3 Accretion on discounted liabilities — 2.0 Settlements — (1.5) Unrealized loss (gain) included in earnings 29.4 (77.8) Balance at end of period $ 29.4 $ — There were no transfers between levels during the years ended December 31, 2021 and 2020, respectively. Fair value of debt The table below summarizes the fair value and carrying value of debt as of December 31, 2021 and 2020. December 31, 2021 December 31, 2020 (in millions) Carrying Fair Carrying Fair 2025 Senior Secured Notes (a) $ 1,250.0 $ 1,192.7 $ 1,250.0 $ 1,232.9 2028 Senior Notes (a) 826.5 520.9 1,000.0 562.5 2025 Senior Notes (a) 669.5 475.9 725.0 475.3 Revolving Credit Facility (b) 900.0 900.0 900.0 900.0 PBF Rail Term Loan (b) — — 7.4 7.4 Catalyst financing arrangements (c) 58.4 58.4 102.5 102.5 3,704.4 3,147.9 3,984.9 3,280.6 Less - Current debt — — (7.4) (7.4) Unamortized premium 0.5 n/a 0.6 n/a Less - Unamortized deferred financing costs (31.6) n/a (45.3) n/a Long-term debt $ 3,673.3 $ 3,147.9 $ 3,932.8 $ 3,273.2 _______________ (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, 2021
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, 2021, there were 2,081,783 barrels of crude oil and feedstocks (no barrels at December 31, 2020) outstanding under these derivative instruments designated as fair value hedges. As of December 31, 2021, there were 2,070,550 barrels of intermediates and refined products (2,604,736 barrels at December 31, 2020) 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, 2021, there were 36,246,000 barrels of crude oil and 5,819,000 barrels of refined products (7,183,000 and 2,810,000, respectively, as of December 31, 2020), 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, 2021 and December 31, 2020 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, 2021: Derivatives included within the inventory intermediation agreement obligations Accrued expenses $ 19.7 December 31, 2020: Derivatives included within the inventory intermediation agreement obligations Accrued expenses $ 11.3 Derivatives not designated as hedging instruments: December 31, 2021: Commodity contracts Accounts receivable $ (12.0) December 31, 2020: Commodity contracts Accounts receivable $ (3.0) 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, 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 For the year ended December 31, 2019: Derivatives included within the inventory intermediation agreement obligations Cost of products and other $ (25.4) Derivatives not designated as hedging instruments: 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 For the year ended December 31, 2019: Commodity contracts Cost of products and other $ 36.5 Hedged items designated in fair value hedges: 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) For the year ended December 31, 2019: Crude oil, intermediate and refined product inventory Cost of products and other $ 25.4

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2021
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 year ended December 31, 2021 and December 31, 2020, only one customer, Shell plc (“Shell”), accounted for 10% or more of the Company’s revenues (approximately 15% and 13%, respectively). For the year ended December 31, 2019 no single customer amounted to greater than or equal to 10% of the Company’s revenues.
Revenue, Deferred Revenue and Accounts Receivable	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 17 - 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 “Renewable Fuel Standard”). 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).
Investments in Equity Method Investments	Investments in Equity Method Investments For equity investments that are not required to be consolidated under the variable or voting interest model, the Company evaluates the level of influence it is able to exercise over an entity’s operations to determine whether to use the equity method of accounting. The Company’s judgment regarding the level of control over an equity method investment includes considering key factors such as its ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Amounts recognized for equity method investments are included in equity method investments in the consolidated balance sheet and adjusted for the Company’s share of the net earnings and losses of the investee and cash distributions, which are included in the consolidated statements of operations and the consolidated statements of cash flows. Amounts recognized for earnings in excess of distributions of the Company’s equity method investments are included in the operating section of the consolidated statements of cash flows. The Company evaluates its equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. A loss is recorded in earnings in the current period to write down the carrying value of the investment to fair value if a decline in the value of an equity method investment is determined to be other than temporary.
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 0% 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 2016 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 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.
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 currently 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.
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 amendments in this ASU are effective for all entities at any time beginning on March 12, 2020 through December 31, 2022 and may be applied from the beginning of an interim period that includes the issuance date of the ASU. The Company does not expect that the adoption of this guidance will 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, 2021
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

ACQUISITIONS (Tables)

ACQUISITIONS (Tables)	12 Months Ended
	Dec. 31, 2021
Business Combination and Asset Acquisition [Abstract]
Business Combination, Consideration Transferred	The total purchase consideration and the fair values of the assets and liabilities at the acquisition date were as follows: (in millions) Purchase Price Gross purchase price $ 960.0 Working capital, including post close adjustments 216.1 Contingent consideration (a) 77.3 Total consideration $ 1,253.4 _______________________
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table summarizes the final amounts recognized for assets acquired and liabilities assumed as of the acquisition date: (in millions) Fair Value Allocation Inventories $ 224.1 Prepaid and other current assets 5.4 Property, plant and equipment 987.9 Operating lease right of use assets (a) 7.8 Financing lease right of use assets (a) 63.5 Deferred charges and other assets, net 63.7 Accrued expenses (1.4) Current operating lease liabilities (1.9) Current financing lease liabilities (b) (6.0) Long-term operating lease liabilities (5.9) Long-term financing lease liabilities (57.5) Other long-term liabilities - environmental obligation (26.3) Fair value of net assets acquired $ 1,253.4 _____________________________ (a) Operating and Financing lease right of use assets are recorded in Lease right of use assets - third party within the Consolidated Balance Sheets.
Business Acquisition, Pro Forma Information	Year Ended December 31, 2020 (Unaudited, in millions) Pro-forma revenues $ 15,408.8 Pro-forma net loss attributable to PBF Holding (1,888.5)

INVENTORIES (Tables)

INVENTORIES (Tables)	12 Months Ended
	Dec. 31, 2021
Inventory Disclosure [Abstract]
Schedule of Inventories	Inventories consisted of the following: 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 December 31, 2020 (in millions) Titled Inventory Inventory Intermediation Agreements Total Crude oil and feedstocks $ 1,018.9 $ — $ 1,018.9 Refined products and blendstocks 933.7 266.5 1,200.2 Warehouse stock and other 136.7 — 136.7 $ 2,089.3 $ 266.5 $ 2,355.8 Lower of cost or market adjustment (572.4) (97.2) (669.6) Total inventories $ 1,516.9 $ 169.3 $ 1,686.2

PROPERTY, PLANT AND EQUIPMENT_2

PROPERTY, PLANT AND EQUIPMENT, NET (Tables)	12 Months Ended
	Dec. 31, 2021
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, 2021 December 31, 2020 Land $ 418.8 $ 418.8 Processing units, pipelines and equipment 4,326.8 4,191.4 Buildings and leasehold improvements 107.3 106.2 Computers, furniture and fixtures 168.1 155.6 Construction in progress 328.1 195.4 5,349.1 5,067.4 Less - Accumulated depreciation (1,234.3) (1,044.3) Total property, plant and equipment, net $ 4,114.8 $ 4,023.1

DEFERRED CHARGES AND OTHER AS_2

DEFERRED CHARGES AND OTHER ASSETS, NET (Tables)	12 Months Ended
	Dec. 31, 2021
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, 2021 December 31, 2020 Deferred turnaround costs, net $ 537.0 $ 598.2 Catalyst, net (a) 166.8 155.2 Environmental credits 41.3 39.6 Linefill 27.4 27.4 Pension plan assets 20.7 21.2 Intangible assets, net 0.5 0.5 Other 20.1 20.6 Total deferred charges and other assets, net $ 813.8 $ 862.7 (a) Catalyst, net includes $113.0 million and $115.2 million of indefinite-lived precious metal catalysts (both owned or financed as part of existing catalyst financing arrangements) as of December 31, 2021 and December 31, 2020, respectively.
Intangible assets, net	Intangible assets, net primarily consists of permits and emission credits. Our net balance as of December 31, 2021 and December 31, 2020 is shown below: (in millions) December 31, 2021 December 31, 2020 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, 2021
Payables and Accruals [Abstract]
Schedule of accrued expenses	Accrued expenses consisted of the following: (in millions) December 31, 2021 December 31, 2020 Inventory-related accruals $ 959.9 $ 695.0 Renewable energy credit and emissions obligations (a) 953.9 528.1 Inventory intermediation agreements (b) 280.1 225.8 Excise and sales tax payable 112.3 119.7 Accrued transportation costs 91.0 72.1 Accrued utilities 73.0 58.6 Accrued capital expenditures 62.6 14.4 Accrued salaries and benefits 57.1 40.1 Accrued refinery maintenance and support costs 55.8 35.7 Accrued interest 32.8 40.2 Environmental liabilities 14.3 11.4 Current finance lease liabilities 11.1 14.4 Customer deposits 3.5 4.0 Other 20.9 22.3 Total accrued expenses $ 2,728.3 $ 1,881.8 (a) The Company is subject to obligations to purchase RINs required to comply with the Renewable Fuel Standard. The Company’s overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by 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, 2021, the Company had entered into $520.0 million of such forward purchase commitments with respect to its total accrued renewable energy and emissions obligations. Final settlement of the Company’s RINs obligation for annual compliance years 2020 through 2022 are subject to final rule making by EPA. Currently, the 2020 obligation is anticipated to require settlement in 2022 and the 2021 and 2022 obligations are anticipated to require settlement in 2023. 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 inventory intermediation agreements with J. Aron. As of December 31, 2021 and December 31, 2020, a liability is recognized for the inventory intermediation agreements and is recorded at market price for the J. Aron owned inventory held in the Company’s Storage Tanks, with any change in the market price being recorded in Cost of products and other.

CREDIT FACILITIES AND DEBT (Tab

CREDIT FACILITIES AND DEBT (Tables)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Summary of long-term debt outstanding	Long-term debt outstanding consisted of the following: (in millions) December 31, 2021 December 31, 2020 2025 Senior Secured Notes $ 1,250.0 $ 1,250.0 2028 Senior Notes 826.5 1,000.0 2025 Senior Notes 669.5 725.0 Revolving Credit Facility 900.0 900.0 PBF Rail Term Loan — 7.4 Catalyst financing arrangements 58.4 102.5 3,704.4 3,984.9 Less - Current debt — (7.4) Unamortized premium 0.5 0.6 Unamortized deferred financing costs (31.6) (45.3) Long-term debt $ 3,673.3 $ 3,932.8
Schedule of details of catalyst financing arrangements	Details of the catalyst financing arrangements at each of the Company’s refineries as of December 31, 2021 are included in the following table: Refinery Metal Annual interest rate Expiration date (1) Paulsboro Platinum 1.47 % December 2022 Delaware City Palladium 3.70 % September 2022 Toledo Platinum 5.05 % September 2022 Chalmette Platinum 5.10 % November 2022 Chalmette Platinum 1.80 % November 2022 Torrance Platinum 1.78 % July 2022 Martinez Palladium 3.70 % September 2022 __________________
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, 2022 $ 58.4 2023 900.0 2024 — 2025 1,919.5 2026 — Thereafter 826.5 Total debt outstanding $ 3,704.4

OTHER LONG-TERM LIABILITIES (Ta

OTHER LONG-TERM LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2021
Other Liabilities Disclosure [Abstract]
Schedule of other long-term liabilities	Other long-term liabilities consisted of the following: (in millions) December 31, 2021 December 31, 2020 Environmental liabilities $ 141.0 $ 140.5 Defined benefit pension plan liabilities 46.7 73.5 Contingent consideration 29.4 — Post-retirement medical plan liabilities 18.2 22.0 Early railcar return liability 6.0 13.9 Other 9.7 17.1 Total other long-term liabilities $ 251.0 $ 267.0

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2021
Commercial Agreements [Member]
Related Party Transaction [Line Items]
Schedule of related party transactions	These commercial agreements (as defined in the table below) with PBFX include: Agreements Initiation Date Initial Term Renewals (a) MVC Force Majeure Transportation and Terminaling Amended and Restated Rail Agreements (b) 5/8/2014 7 years, 8 months N/A 125,000 bpd PBF Holding or PBFX can declare Toledo Truck Unloading & Terminaling Services Agreement (c) 5/8/2014 7 years, 8 months 2 x 5 5,500 bpd Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility (c) 12/12/2014 10 years 2 x 5 4,400 bpd 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 (d) See note (d) 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 (e) 5/1/2016 Various (f) Evergreen 15,000 bpd (g) East Coast Terminals Tank Lease Agreements 5/1/2016 Various (f) Evergreen 350,000 barrels (h) Torrance Valley Pipeline Transportation Services Agreement- North Pipeline (c) 8/31/2016 10 years 2 x 5 50,000 bpd Torrance Valley Pipeline Transportation Services Agreement- South Pipeline (c) 8/31/2016 10 years 2 x 5 75,000 bpd (i) Torrance Valley Pipeline Transportation Services Agreement- Midway Storage Tank (c) 8/31/2016 10 years 2 x 5 55,000 barrels (h) Torrance Valley Pipeline Transportation Services Agreement- Emidio Storage Tank (c) 8/31/2016 10 years 2 x 5 900,000 barrels per month Torrance Valley Pipeline Transportation Services Agreement- Belridge Storage Tank (c) 8/31/2016 10 years 2 x 5 770,000 barrels per month Paulsboro Natural Gas Pipeline Services Agreement (c) 8/4/2017 15 years Evergreen 60,000 dekatherms per day Knoxville Terminals Agreement- Terminaling Services 4/16/2018 5 years Evergreen Various (j) Knoxville Terminals Agreement- Storage Services 4/16/2018 5 years Evergreen 115,334 barrels (h) Toledo Rail Loading Agreement (c) 7/31/2018 7 years, 5 months 2 x 5 Various (k) 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 (c) 7/31/2018 7 years, 5 months 2 x 5 5,000 bpd Delaware City Terminaling Services Agreement (l) 1/1/2022 4 years 2 x 5 95,000 bpd Storage Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility (c) 12/12/2014 10 years 2 x 5 3,849,271 barrels (h) PBF Holding or PBFX can declare Chalmette Storage Agreement (c) See note (m) 10 years 2 x 5 625,000 barrels (h) East Coast Storage Assets Terminal Storage Agreement (c) 1/1/2019 8 years Evergreen 2,953,725 barrels (h) ____________________ (a) PBF Holding has the option to extend the agreements for up to two additional five-year terms, as applicable. (b) The Amended and Restated Rail Agreements, as amended and effective as of January 1, 2018, include the Amended and Restated Delaware City Rail Terminaling Services Agreement and the Amended and Restated Delaware West Ladder Rack Terminaling Services Agreement, each between Delaware City Terminaling Company LLC (“DCTC”) and PBF Holding, with the service fees thereunder being adjusted, including the addition of an ancillary fee paid by PBF Holding on an actual cost basis. In determining payments due under the Amended and Restated Rail Agreements, excess volumes throughput under the agreements shall apply against required payments in respect to the minimum throughput commitments on a quarterly basis and, to the extent not previously applied, on an annual basis against the MVCs. Effective January 1, 2019, the existing Amended and Restated Rail Agreements were further amended for the inclusion of services through certain rail infrastructure at the PBFX East Coast storage facility. (c) These commercial agreements with PBFX are considered leases. (d) 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. (e) 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. (f) The East Coast Terminals related party agreements include varying initial term lengths, ranging from one (g) 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. (h) 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. (i) In connection with the TVPC Acquisition 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. (j) 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. (k) 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. (l) The Delaware City Terminaling Services Agreement between DCTC and PBF Holding commenced on January 1, 2022 subsequent to the expiration of the Amended and Restated Rail Agreements and includes additional services provided by PBFX as operator of other rail facilities owned by PBF Holding’s subsidiaries. (m) The Chalmette Storage Services Agreement was entered into on February 15, 2017 and commenced on November 1, 2017.
Contribution Agreements [Member]
Related Party Transaction [Line Items]
Schedule of related party transactions	The Contribution Agreement entered into during the year ended 2019 includes the following: Contribution Agreement Effective Date Assets Contributed Total Consideration Contribution Agreement XI 4/24/2019 Remaining 50% equity interest in TVPC (a) $200.0 million (a) On April 24, 2019, PBFX entered into a contribution agreement with PBF LLC, pursuant to which the Company contributed to PBF LLC, which in turn contributed to PBFX, all of the issued and outstanding limited liability company interests of TVP Holding Company LLC (“TVP Holding”) for total consideration of $200.0 million (the “TVPC Acquisition”). Prior to the TVPC Acquisition, TVP Holding (then a subsidiary of PBF Holding) owned a 50% equity interest in Torrance Valley Pipeline Company LLC (“TVPC”). Subsequent to the closing of the TVPC Acquisition on May 31, 2019, PBFX owns 100% of the equity interest in TVPC.
PBF Logistics LP [Member] | Commercial Agreements [Member]
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) 2021 2020 2019 Reimbursements under affiliate agreements: Services Agreement $ 8.7 $ 8.7 $ 8.6 Omnibus Agreement 7.3 7.6 7.7 Total expenses under affiliate agreements 304.1 289.4 300.9

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2021
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) 2022 $ 150.2 2023 125.2 2024 112.0 2025 108.3 2026 21.4 Thereafter 205.0 Total obligations $ 722.1

LEASES (Tables)

LEASES (Tables)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Assets and Liabilities, Lessee [Table Text Block]	The table below presents the lease related assets and liabilities recorded on the Company’s Consolidated Balance Sheets as of December 31, 2021 and December 31, 2020: (in millions) Classification on the Balance Sheet December 31, 2021 December 31, 2020 Assets Operating lease assets - third party Lease right of use assets - third party $ 635.8 $ 836.3 Operating lease assets - affiliate Lease right of use assets - affiliate 485.4 571.0 Finance lease assets Lease right of use assets - third party 81.2 80.4 Total lease right of use assets $ 1,202.4 $ 1,487.7 Liabilities Current liabilities: Operating lease liabilities - third party Current operating lease liabilities - third party $ 64.8 $ 78.3 Operating lease liabilities - affiliate Current operating lease liabilities - affiliate 90.7 85.6 Finance lease liabilities - third party Accrued expenses 11.1 14.4 Noncurrent liabilities: Operating lease liabilities - third party Long-term operating lease liabilities - third party 570.3 755.9 Operating lease liabilities - affiliate Long-term operating lease liabilities - affiliate 394.7 485.4 Finance lease liabilities - third party Long-term financing lease liabilities - third party 70.6 68.3 Total lease liabilities $ 1,202.2 $ 1,487.9
Lease, Cost [Table Text Block]	The table below presents certain information related to costs for the Company’s leases for the year ended December 31, 2021 and December 31, 2020: Lease Costs (in millions) December 31, 2021 December 31, 2020 Components of total lease costs: Finance lease costs Amortization of right of use assets $ 16.1 $ 14.0 Interest on lease liabilities 4.6 4.3 Operating lease costs 299.1 291.2 Short-term lease costs 59.3 92.3 Variable lease costs 31.6 31.1 Total lease costs $ 410.7 $ 432.9
Cash Flow, Lessee [Table Text Block]	The table below presents supplemental cash flow information related to leases for the year ended December 31, 2021 and December 31, 2020 (in millions): Years Ended December 31, 2021 2020 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows for operating leases $ 297.9 $ 292.4 Operating cash flows for finance leases 4.6 4.3 Financing cash flows for finance leases 17.8 12.4 Supplemental non-cash amounts of lease liabilities arising from obtaining or remeasuring right-of-use assets (106.6) 702.0 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, 2021: Weighted average remaining lease term - operating leases 9.8 years Weighted average remaining lease term - finance leases 6.5 years Weighted average discount rate - operating leases 13.4 % Weighted average discount rate - finance leases 7.4 %
Lessee, Liability, Maturity [Table Text Block]	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, 2021: Amounts due in the year ended December 31, (in millions) Finance Leases Operating Leases 2022 $ 16.5 $ 280.6 2023 16.4 252.4 2024 15.7 243.0 2025 14.2 202.3 2026 13.8 166.0 Thereafter 25.6 903.9 Total minimum lease payments 102.2 2,048.2 Less: effect of discounting 20.5 927.7 Present value of future minimum lease payments 81.7 1,120.5 Less: current obligations under leases 11.1 155.5 Long-term lease obligations $ 70.6 $ 965.0
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, 2021: Amounts due in the year ended December 31, (in millions) Finance Leases Operating Leases 2022 $ 16.5 $ 280.6 2023 16.4 252.4 2024 15.7 243.0 2025 14.2 202.3 2026 13.8 166.0 Thereafter 25.6 903.9 Total minimum lease payments 102.2 2,048.2 Less: effect of discounting 20.5 927.7 Present value of future minimum lease payments 81.7 1,120.5 Less: current obligations under leases 11.1 155.5 Long-term lease obligations $ 70.6 $ 965.0

STOCK-BASED COMPENSATION (Table

STOCK-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2021
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) 2021 2020 2019 PBF Energy options $ 17.3 $ 16.1 $ 15.8 PBF Energy restricted shares 2.8 5.3 6.5 PBF Energy performance awards 10.2 7.9 8.2 $ 30.3 $ 29.3 $ 30.5
Weighted average assumptions	December 31, 2021 December 31, 2020 December 31, 2019 Expected life (in years) 6.00 6.08 6.25 Expected volatility 83.8 % 69.1 % 38.6 % Dividend yield 0.00 % 1.41 % 3.54 % Risk-free rate of return 1.37 % 0.81 % 2.16 % Exercise price $ 13.91 $ 13.58 $ 34.11 Weighted average fair value per option granted $ 9.84 $ 5.49 $ 9.43
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, 2021 December 31, 2020 December 31, 2019 Expected life (in years) 3.12 2.89 - 3.14 2.17 - 2.88 Expected volatility 83.78 % 39.88% - 82.63% 37.19% - 41.70% Dividend yield 0.00 % 0.00% - 4.28% 3.40% - 3.67% Risk-free rate of return 0.87 % 0.26% - 1.34% 1.66% - 2.51% Weighted average grant-date fair value per PSU $ 18.73 $ 10.77 $ 27.99
Employee Stock Option [Member]
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 2021: Number of Weighted Weighted Stock-based awards, outstanding at January 1, 2021 13,790,777 $ 25.69 7.12 Granted 1,700,621 13.91 10.00 Exercised (52,400) 6.72 — Forfeited (389,239) 23.70 — Outstanding at December 31, 2021 15,049,759 $ 24.48 6.51 Exercisable and vested at December 31, 2021 9,397,483 $ 27.72 5.26 Expected to vest at December 31, 2021 15,049,759 $ 24.48 6.51
Restricted Stock [Member]
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, 2021 303,555 $ 22.32 Granted 81,840 16.13 Vested (229,462) 24.34 Forfeited (246) 24.18 Nonvested at December 31, 2021 155,687 $ 16.09 Unrecognized compensation expense related to PBF Energy Restricted Class A common stock at December 31, 2021 was $0.1 million, which will be recognized from 2022 through 2023. The following table reflects activity related to our restricted stock: December 31, 2021 December 31, 2020 December 31, 2019 Weighted-average grant-date fair value per share of restricted stock granted $ 16.13 $ 9.82 $ 28.20 Fair value of restricted stock vested (in millions) $ 3.1 $ 4.2 $ 11.6
Performance share units [Member]
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, 2021 623,160 $ 15.62 Granted 301,965 18.73 Vested (179,600) 27.85 Nonvested at December 31, 2021 745,525 $ 13.93
Performance Units [Member]
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, 2021 16,071,745 Granted 11,782,926 Vested (7,676,658) Nonvested at December 31, 2021 20,178,013

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	12 Months Ended
	Dec. 31, 2021
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, 2021 and 2020 were as follows: Pension Plans Post-Retirement (in millions) 2021 2020 2021 2020 Change in benefit obligation: Benefit obligation at beginning of year $ 329.3 $ 271.2 $ 22.0 $ 17.5 Service cost 57.5 59.0 1.1 1.0 Interest cost 5.3 6.9 0.3 0.4 Plan amendments — — — 1.8 Benefit payments (31.2) (18.0) (1.2) (0.6) Actuarial (gain) loss (7.6) 10.2 (4.0) 1.9 Projected benefit obligation at end of year $ 353.3 $ 329.3 $ 18.2 $ 22.0 Change in plan assets: Fair value of plan assets at beginning of year $ 255.8 $ 197.4 $ — $ — Actual return on plan assets 27.7 28.6 — — Benefits paid (31.2) (18.0) (1.2) (0.6) Employer contributions 54.0 47.8 1.2 0.6 Fair value of plan assets at end of year $ 306.3 $ 255.8 $ — $ — Reconciliation of funded status: Fair value of plan assets at end of year $ 306.3 $ 255.8 $ — $ — Less benefit obligations at end of year 353.3 329.3 18.2 22.0 Funded status at end of year $ (47.0) $ (73.5) $ (18.2) $ (22.0)
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 2022 $ 24.8 $ 1.8 2023 18.1 1.7 2024 20.1 1.6 2025 23.7 1.5 2026 27.1 1.5 Years 2027-2031 168.6 6.8
Schedule of net periodic benefit cost	The components of net periodic benefit cost were as follows for the years ended December 31, 2021, 2020 and 2019: Pension Benefits Post-Retirement (in millions) 2021 2020 2019 2021 2020 2019 Components of net periodic benefit cost: Service cost $ 57.5 $ 59.0 $ 43.6 $ 1.1 $ 1.0 $ 1.0 Interest cost 5.3 6.9 8.3 0.3 0.4 0.7 Expected return on plan assets (14.2) (12.5) (9.6) — — — Amortization of prior service cost and actuarial loss 0.1 0.3 0.3 0.7 0.6 0.5 Net periodic benefit cost $ 48.7 $ 53.7 $ 42.6 $ 2.1 $ 2.0 $ 2.2
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, 2021, 2020, and 2019 were as follows: Pension Benefits Post-Retirement (in millions) 2021 2020 2019 2021 2020 2019 Prior service costs $ — $ — $ — $ — $ 1.8 $ — Net actuarial (gain) loss (21.1) (5.9) (10.7) (4.0) 1.9 (2.3) Amortization of losses and prior service cost (0.1) (0.3) (0.3) (0.7) (0.6) (0.5) Total changes in other comprehensive (income) loss $ (21.2) $ (6.2) $ (11.0) $ (4.7) $ 3.1 $ (2.8)
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, 2021 and 2020 that have not yet been recognized as components of net periodic costs were as follows: Pension Benefits Post-Retirement (in millions) 2021 2020 2021 2020 Prior service costs $ (0.5) $ (0.6) $ (4.3) $ (5.0) Net actuarial gain (loss) 12.7 (8.4) 7.8 3.9 Total $ 12.2 $ (9.0) $ 3.5 $ (1.1)
Schedule of assumptions used	The weighted average assumptions used to determine the benefit obligations as of December 31, 2021 and 2020 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2021 2020 2021 2020 2021 2020 Discount rate - benefit obligations 2.78 % 2.36 % 2.73 % 2.21 % 2.46 % 1.90 % Rate of compensation increase 4.26 % 4.28 % 4.50 % 4.50 % — — The weighted average assumptions used to determine the net periodic benefit costs for the years ended December 31, 2021, 2020 and 2019 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2021 2020 2019 2021 2020 2019 2021 2020 2019 Discount rates: Effective rate for service cost 2.40% 2.94% 4.24% 2.26% 2.79% 4.19% 2.35% 2.86% 4.21% Effective rate for interest cost 1.74% 2.50% 3.92% 1.53% 2.33% 3.83% 1.28% 2.21% 3.69% Effective rate for interest on service cost 1.92% 2.59% 4.00% 1.75% 2.42% 3.90% 2.11% 2.68% 4.09% Cash balance interest credit rate 1.57% 2.19% 3.34% 1.57% 2.19% 3.34% N/A N/A N/A Expected long-term rate of return on plan assets 5.25% 5.75% 6.00% N/A N/A N/A N/A N/A N/A Rate of compensation increase 4.28% 4.28% 4.55% 4.50% 4.50% 5.00% 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, 2021 and 2020 were as follows: Post-Retirement 2021 2020 Health care cost trend rate assumed for next year 5.2 % 5.4 % Rate to which the cost trend rate was assumed to decline (the ultimate trend rate) 4.0 % 4.5 % Year that the rate reaches the ultimate trend rate 2046 2038
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, 2021 and 2020 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) 2021 2020 Equities: Domestic equities $ 73.9 $ 64.4 Developed international equities 37.7 38.2 Global low volatility equities 24.1 22.5 Emerging market equities 24.8 20.7 Fixed-income 121.6 95.7 Real Estate 23.2 13.3 Cash and cash equivalents 1.0 1.0 Total $ 306.3 $ 255.8

REVENUES (Tables)

REVENUES (Tables)	12 Months Ended
	Dec. 31, 2021
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) 2021 2020 2019 Gasoline and distillates $ 23,489.5 $ 12,799.4 $ 21,278.4 Feedstocks and other 1,310.1 935.5 806.9 Asphalt and blackoils 1,217.8 777.9 1,426.4 Chemicals 889.8 351.5 682.3 Lubricants 294.8 180.7 274.9 Total Revenues $ 27,202.0 $ 15,045.0 $ 24,468.9

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2021
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, 2021 December 31, 2020 December 31, 2019 Current income tax expense (benefit) $ 0.5 $ (1.2) $ 0.5 Deferred income tax (benefit) expense (14.5) 7.3 (8.8) Total income tax (benefit) expense $ (14.0) $ 6.1 $ (8.3)
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	A summary of the components of PBF Holding’s deferred tax assets and deferred tax liabilities consists of the following: (in millions) December 31, 2021 December 31, 2020 Deferred tax assets Net operating loss carry forwards $ 0.3 $ 0.1 Other 0.5 — Total deferred tax assets 0.8 0.1 Valuation allowance — — Total deferred tax assets, net 0.8 0.1 Deferred tax liabilities Property, plant and equipment 16.3 17.5 Inventory 8.7 21.3 Total deferred tax liabilities 25.0 38.8 Net deferred tax liability $ (24.2) $ (38.7)

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2021
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, 2021 and 2020. 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, 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 As of December 31, 2020 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 $ 402.3 $ — $ — $ 402.3 N/A $ 402.3 Commodity contracts 2.5 3.5 — 6.0 (6.0) — Derivatives included within inventory intermediation agreement obligations — 11.3 — 11.3 — 11.3 Liabilities: Commodity contracts 2.3 6.7 — 9.0 (6.0) 3.0 Catalyst obligations — 102.5 — 102.5 — 102.5 Contingent consideration obligation — — — — — —
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) 2021 2020 Balance at beginning of period $ — $ — Additions — 77.3 Accretion on discounted liabilities — 2.0 Settlements — (1.5) Unrealized loss (gain) included in earnings 29.4 (77.8) Balance at end of period $ 29.4 $ —
Schedule of Fair value of Debt	The table below summarizes the fair value and carrying value of debt as of December 31, 2021 and 2020. December 31, 2021 December 31, 2020 (in millions) Carrying Fair Carrying Fair 2025 Senior Secured Notes (a) $ 1,250.0 $ 1,192.7 $ 1,250.0 $ 1,232.9 2028 Senior Notes (a) 826.5 520.9 1,000.0 562.5 2025 Senior Notes (a) 669.5 475.9 725.0 475.3 Revolving Credit Facility (b) 900.0 900.0 900.0 900.0 PBF Rail Term Loan (b) — — 7.4 7.4 Catalyst financing arrangements (c) 58.4 58.4 102.5 102.5 3,704.4 3,147.9 3,984.9 3,280.6 Less - Current debt — — (7.4) (7.4) Unamortized premium 0.5 n/a 0.6 n/a Less - Unamortized deferred financing costs (31.6) n/a (45.3) n/a Long-term debt $ 3,673.3 $ 3,147.9 $ 3,932.8 $ 3,273.2 _______________ (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, 2021
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, 2021 and December 31, 2020 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, 2021: Derivatives included within the inventory intermediation agreement obligations Accrued expenses $ 19.7 December 31, 2020: Derivatives included within the inventory intermediation agreement obligations Accrued expenses $ 11.3 Derivatives not designated as hedging instruments: December 31, 2021: Commodity contracts Accounts receivable $ (12.0) December 31, 2020: Commodity contracts Accounts receivable $ (3.0)
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, 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 For the year ended December 31, 2019: Derivatives included within the inventory intermediation agreement obligations Cost of products and other $ (25.4) Derivatives not designated as hedging instruments: 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 For the year ended December 31, 2019: Commodity contracts Cost of products and other $ 36.5 Hedged items designated in fair value hedges: 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) For the year ended December 31, 2019: Crude oil, intermediate and refined product inventory Cost of products and other $ 25.4

DESCRIPTION OF THE BUSINESS A_2

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION (Details) - segment	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Description of Business [Line Items]
Percentage of ownership in PBF LLC	100.00%
Number of Reportable Segments	1
PBF Energy [Member] | Class A Common Stock [Member]
Description of Business [Line Items]
Percentage of ownership in PBF LLC	99.20%	99.20%

SUMMARY OF SIGNIFICANT ACCOUN_4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Concentration of Credit Risk) (Details) - Customer Concentration Risk [Member] - numberOfCustomers	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenues [Member]
Concentration Risk [Line Items]
Number of Customers to Account for More than 10%	1	1	0
Concentration Risk, Benchmark Description	10	10	10
Revenues [Member] | Royal Dutch Shell
Concentration Risk [Line Items]
Concentration risk percentage	15.00%	13.00%
Accounts Receivables [Member]
Concentration Risk [Line Items]
Number of Customers to Account for More than 10%	1	1
Concentration Risk, Benchmark Description	10	10
Accounts Receivables [Member] | Royal Dutch Shell
Concentration Risk [Line Items]
Concentration risk percentage	26.00%	17.00%

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Leases) (Details)	Dec. 31, 2021
Minimum [Member]
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term	1 year
Maximum [Member]
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, 2021
Process Units and Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Process Units and Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Pipeline and Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Pipeline and Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Buildings [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Computers, furniture and fixtures | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	3 years
Computers, furniture and fixtures | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	7 years
Leasehold Improvements [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	20 years
Railcars [Member]
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, 2021
Minimum [Member]
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 [Member]
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 [Member]	Oct. 31, 2020number_period	Dec. 31, 2021renewal
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Requisite Service Period	3 years	3 years
Share-Based Compensation Arrangement By Share-based Payment Award, Award Measurement, Number Of Periods | number_period	4
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Distribution Percentage Based On Performance Measurements, Number Of Periods | renewal		4
Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Distribution Percentage Based On Performance Measurements		0.00%
Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Distribution Percentage Based On Performance Measurements		200.00%

SUMMARY OF SIGNIFICANT ACCOUN_9

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Income Taxes) (Details) - 12 months ended Dec. 31, 2021	subsidiary	state
Accounting Policies [Abstract]
Number of subsidiaries acquired	2	2

ACQUISITIONS (Additional Inform

ACQUISITIONS (Additional Information) (Details) - USD ($)	Feb. 01, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jan. 24, 2020
Business Acquisition [Line Items]
Acquisition costs		$ 0	$ 11,100,000	$ 0
2028 Senior Notes [Member]
Business Acquisition [Line Items]
Long-term Debt					$ 1,000,000,000
Debt fixed interest rate					6.00%
Martinez Acquisition
Business Acquisition [Line Items]
Consideration transferred	$ 1,253,400,000
Working capital	$ 216,100,000

ACQUISITIONS (Purchase Price) (

ACQUISITIONS (Purchase Price) (Details) - USD ($) $ in Millions		Feb. 01, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Business Acquisition [Line Items]
Gross purchase price			$ 0	$ 1,176.2	$ 0
Martinez Acquisition
Business Acquisition [Line Items]
Gross purchase price		$ 960
Working capital		216.1
Contingent consideration	[1]	77.3
Total consideration		$ 1,253.4
Term of Agreement		4 years
[1]	The Martinez Acquisition included an obligation for the Company to make post-closing earn-out payments to the Seller based on certain earnings thresholds of the Martinez refinery (as set forth in the Sale and Purchase Agreement), for a period of up to four years following the acquisition closing date (the “Martinez Contingent Consideration”). The Company recorded the Martinez Contingent Consideration based on its estimated fair value of $77.3 million at the acquisition date, which was recorded within “Other long-term liabilities” within the Consolidated Balance Sheets. Subsequent changes in the fair value of the Martinez Contingent Consideration are recorded in the Consolidated Statements of Operations.

ACQUISITIONS (Assets and Liabil

ACQUISITIONS (Assets and Liabilities Acquired) (Details) - Martinez Acquisition $ in Millions	Feb. 01, 2020USD ($)
Business Acquisition [Line Items]
Inventories	$ 224.1
Prepaid and other current assets	5.4
Property, plant and equipment	987.9
Operating lease right of use assets	7.8	[1]
Financing lease right of use assets	63.5	[1]
Deferred charges and other assets, net	63.7
Accrued expenses	(1.4)
Current operating lease liabilities	(1.9)
Current financing lease liabilities	(6)	[2]
Long-term operating lease liabilities	(5.9)
Long-term financing lease liabilities	(57.5)
Other long-term liabilities - environmental obligation	(26.3)
Fair value of net assets acquired	$ 1,253.4
[1]	Operating and Financing lease right of use assets are recorded in Lease right of use assets - third party within the Consolidated Balance Sheets.
[2]	Current financing lease liabilities are recorded in Accrued expenses within the Consolidated Balance Sheets.

ACQUISITIONS (Pro Forma Informa

ACQUISITIONS (Pro Forma Information) (Details) - Martinez Acquisition $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)
Business Acquisition [Line Items]
Pro-forma revenues	$ 15,408.8
Pro-forma net loss attributable to PBF Holding	$ (1,888.5)

Credit Losses (Details)

Credit Losses (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Credit Loss [Abstract]
Allowance for doubtful accounts	$ 0	$ 0

INVENTORIES (Details)

INVENTORIES (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Inventory [Line Items]
Crude oil and feedstocks	$ 1,104,900,000	$ 1,018,900,000
Refined products and blendstocks	1,258,400,000	1,200,200,000
Warehouse stock and other	141,800,000	136,700,000
Inventory, Gross	2,505,100,000	2,355,800,000
Lower of cost or market adjustment	0	669,600,000	$ 401,600,000
Total inventories	2,505,100,000	1,686,200,000
Income from operations	404,000,000	(1,611,400,000)	$ 498,500,000
Inventory, LIFO Reserve, Effect on Income, Net	0	83,000,000
Titled Inventory [Member]
Inventory [Line Items]
Crude oil and feedstocks	953,500,000	1,018,900,000
Refined products and blendstocks	964,600,000	933,700,000
Warehouse stock and other	141,800,000	136,700,000
Inventory, Gross	2,059,900,000	2,089,300,000
Lower of cost or market adjustment	0	572,400,000
Total inventories	2,059,900,000	1,516,900,000
Inventory Supply and Offtake Arrangements [Member]
Inventory [Line Items]
Crude oil and feedstocks	151,400,000	0
Refined products and blendstocks	293,800,000	266,500,000
Warehouse stock and other	0	0
Inventory, Gross	445,200,000	266,500,000
Lower of cost or market adjustment	0	97,200,000
Total inventories	445,200,000	169,300,000
Adjustment [Member]
Inventory [Line Items]
Income from operations	$ 669,600,000	$ (268,000,000)

PROPERTY, PLANT AND EQUIPMENT_3

PROPERTY, PLANT AND EQUIPMENT, NET (Details) $ in Millions	Apr. 17, 2020USD ($)hydrogenPlants	Dec. 31, 2020USD ($)	Sep. 30, 2019USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		$ 5,067.4		$ 5,349.1	$ 5,067.4
Less - Accumulated depreciation		(1,044.3)		(1,234.3)	(1,044.3)
Property, plant and equipment, net		4,023.1		4,114.8	4,023.1
Depreciation				192.3	179.4	$ 140.7
Impairment expense				0	91.8	0
Number of Hydrogen Plants Sold | hydrogenPlants	5
Proceeds from sale of assets	$ 530			0	543.1	36.3
Gain (Loss) on Disposition of Property Plant Equipment				0.2	477.8	29.9
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property				0.2	477.8	$ 29.9
Air Products and Chemical, Inc.
Property, Plant and Equipment [Line Items]
Proceeds from sale of assets	$ 530
Gain (Loss) on Disposition of Property Plant Equipment					471.1
Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		418.8		418.8	418.8
Process units, pipelines and equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		4,191.4		4,326.8	4,191.4
Building and leasehold improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		106.2		107.3	106.2
Computers furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		155.6		168.1	155.6
Construction in progress [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		195.4		328.1	195.4
Capitalized interest				$ 8.9	11.9
Construction in progress [Member] | East Coast Refining | Idled Processing Units
Property, Plant and Equipment [Line Items]
Impairment expense					11.9
Construction in progress [Member] | East Coast Refining | Capital Projects
Property, Plant and Equipment [Line Items]
Impairment expense					$ 79.9
Torrance Refinery [Member]
Property, Plant and Equipment [Line Items]
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property		$ 8.1	$ 33.1

DEFERRED CHARGES AND OTHER AS_3

DEFERRED CHARGES AND OTHER ASSETS, NET (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Deferred turnaround costs, net		$ 537,000	$ 598,200
Catalyst, net (a)	[1]	166,800	155,200
Environmental credits		41,300	39,600
Linefill		27,400	27,400
Pension plan assets		20,700	21,200
Intangible assets, net		500	500
Other		20,100	20,600
Total deferred charges and other assets, net		813,800	862,700
Amortization expense		220,600	315,700	$ 256,800
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 [Member]
Catalyst, net (a)		$ 113,000	$ 115,200
[1]	Catalyst, net includes $113.0 million and $115.2 million of indefinite-lived precious metal catalysts (both owned or financed as part of existing catalyst financing arrangements) as of December 31, 2021 and December 31, 2020, respectively.

ACCRUED EXPENSES (Details)

ACCRUED EXPENSES (Details) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Accrued Expenses:
Inventory-related accruals		$ 959.9	$ 695
Renewable energy credit and emissions obligations (a)	[1]	953.9	528.1
Inventory intermediation agreements (b)	[2]	280.1	225.8
Excise and sales tax payable		112.3	119.7
Accrued transportation costs		91	72.1
Accrued utilities		73	58.6
Accrued capital expenditures		62.6	14.4
Accrued salaries and benefits		57.1	40.1
Accrued refinery maintenance and support costs		55.8	35.7
Accrued interest		32.8	40.2
Environmental liabilities		14.3	11.4
Current finance lease liabilities		11.1	14.4
Customer deposits		3.5	4
Other		20.9	22.3
Total accrued expenses		$ 2,728.3	$ 1,881.8
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]		Total accrued expenses	Total accrued expenses
Forward Purchase Commitments for Renewable Energy Credit Obligations		$ 520
[1]	The Company is subject to obligations to purchase RINs required to comply with the Renewable Fuel Standard. The Company’s overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by 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, 2021, the Company had entered into $520.0 million of such forward purchase commitments with respect to its total accrued renewable energy and emissions obligations. Final settlement of the Company’s RINs obligation for annual compliance years 2020 through 2022 are subject to final rule making by EPA. Currently, the 2020 obligation is anticipated to require settlement in 2022 and the 2021 and 2022 obligations are anticipated to require settlement in 2023. 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 inventory intermediation agreements with J. Aron. As of December 31, 2021 and December 31, 2020, a liability is recognized for the inventory intermediation agreements and is recorded at market price for the J. Aron owned inventory held in the Company’s Storage Tanks, with any change in the market price being recorded in Cost of products and other.

CREDIT FACILITIES AND DEBT (Det

CREDIT FACILITIES AND DEBT (Details) - USD ($) $ in Millions

Dec. 21, 2020

May 13, 2020

Jan. 24, 2020

May 02, 2018

May 30, 2017

Dec. 22, 2016

Oct. 31, 2012

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

May 07, 2020

May 06, 2020

Feb. 18, 2020

Feb. 09, 2012

Debt Instrument [Line Items]

Uncommitted Receivables Purchase Facility, Maximum Borrowing

$ 300

Gain (loss) on extinguishment of debt

$ 79.9

$ (22.2)

$ 0

Minimum [Member]

Debt Instrument [Line Items]

Debt instrument term

1 year

Maximum [Member]

Debt Instrument [Line Items]

Debt instrument term

8 years

Revolving Loan [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

$ 900

900

Catalyst Financing Arrangement [Member]

Debt Instrument [Line Items]

Annual catalyst financing fees

2

2.7

Line of Credit [Member] | Revolving Loan [Member]

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 3,400

Line of Credit Facility, Available Increase in Borrowing Capacity

$ 3,500

Maximum borrowing capacity, as a percentage of aggregate borrowing capacity

10.00%

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

20.00%

10.00%

Long-term Line of Credit

900

900

Letters of Credit Outstanding, Amount

380.1

184.4

Line of Credit [Member] | Revolving Loan [Member] | Maximum [Member]

Debt Instrument [Line Items]

Line of Credit Facility, Commitment Fee Percentage

0.25%

Line of Credit [Member] | Revolving Loan [Member] | Base Rate [Member] | Minimum [Member]

Debt Instrument [Line Items]

Basis spread on variable rate

0.25%

Line of Credit [Member] | Revolving Loan [Member] | Base Rate [Member] | Maximum [Member]

Debt Instrument [Line Items]

Basis spread on variable rate

1.00%

Line of Credit [Member] | Revolving Loan [Member] | LIBOR [Member] | Minimum [Member]

Debt Instrument [Line Items]

Basis spread on variable rate

1.25%

Line of Credit [Member] | Revolving Loan [Member] | LIBOR [Member] | Maximum [Member]

Debt Instrument [Line Items]

Basis spread on variable rate

2.00%

Line of Credit [Member] | Revolving Loan [Member] | Company Credit Rating [Member] | Minimum [Member]

Debt Instrument [Line Items]

Basis spread on variable rate

1.00%

Line of Credit [Member] | Revolving Loan [Member] | Company Credit Rating [Member] | Maximum [Member]

Debt Instrument [Line Items]

Basis spread on variable rate

1.75%

2025 Senior Secured Notes

Debt Instrument [Line Items]

Long-term Debt

1,250

1,250

Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed

35.00%

Redemption price as a percentage

109.25%

2025 Senior Secured Notes | Regulatory Debt Facility

Debt Instrument [Line Items]

Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed

35.00%

Redemption price as a percentage

104.625%

2028 Senior Notes [Member]

Debt Instrument [Line Items]

Long-term Debt

826.5

1,000

Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed

35.00%

Redemption price as a percentage

106.00%

PBF Rail Logistics Company LLC [Member] | PBF Rail Term Loan [Member]

Debt Instrument [Line Items]

Long-term Debt

$ 35

0

7.4

Debt instrument term

5 years

2020 Senior Secured Notes [Member]

Debt Instrument [Line Items]

Debt fixed interest rate

8.25%

2023 Senior Notes [Member]

Debt Instrument [Line Items]

Debt fixed interest rate

7.00%

Repayments of Long-term Debt

$ 0

517.5

0

2025 Senior Notes [Member]

Debt Instrument [Line Items]

Long-term Debt

$ 725

Debt fixed interest rate

7.25%

Proceeds from Debt, Net of Issuance Costs

$ 711.6

Redemption price as a percentage

100.00%

Extinguishment of Debt, Amount

$ 55.5

Repayments of Long-term Debt

37.5

0

0

Gain (loss) on extinguishment of debt

17.5

2028 Senior Notes [Member]

Debt Instrument [Line Items]

Long-term Debt

$ 1,000

Debt fixed interest rate

6.00%

Proceeds from Debt, Net of Issuance Costs

$ 987

Extinguishment of Debt, Amount

173.5

Repayments of Long-term Debt

109.3

$ 0

$ 0

Gain (loss) on extinguishment of debt

$ 62.4

Paulsboro Catalyst [Member] | Catalyst Financing Arrangement [Member]

Debt Instrument [Line Items]

Debt fixed interest rate

[1]

1.47%

Toledo Catalyst [Member] | Catalyst Financing Arrangement [Member]

Debt Instrument [Line Items]

Debt fixed interest rate

[1]

5.05%

Torrance Catalyst [Member] | Catalyst Financing Arrangement [Member]

Debt Instrument [Line Items]

Debt fixed interest rate

[1]

1.78%

Initial 2025 Senior Secured Notes

Debt Instrument [Line Items]

Long-term Debt

$ 1,000

Debt fixed interest rate

9.25%

Proceeds from Debt, Net of Issuance Costs

$ 982.9

Additional 2025 Senior Secured Notes

Debt Instrument [Line Items]

Long-term Debt

$ 250

Debt fixed interest rate

9.25%

Proceeds from Debt, Net of Issuance Costs

$ 245.7

Debt Instrument, Issuance Percentage Of Face Amount

100.25%

[1]

These catalyst financing arrangements are included in Long-term debt as of December 31, 2021 as the Company has the ability and intent to finance this debt through availability under other credit facilities if the catalyst financing arrangements are not renewed at maturity.

CREDIT FACILITIES AND DEBT (Sum

CREDIT FACILITIES AND DEBT (Summary of Long-Term Debt) (Details) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020	Dec. 22, 2016
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 3,704.4	$ 3,984.9
Less—Current debt		0	(7.4)
Unamortized Debt Issuance Expense		(31.6)	(45.3)
Long-term Debt, Excluding Current Maturities		3,673.3	3,932.8
Debt Instrument, Unamortized Premium		0.5	0.6
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Long-term Line of Credit		900	900
2025 Senior Secured Notes
Debt Instrument [Line Items]
Long-term Debt		1,250	1,250
2028 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt		826.5	1,000
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt		669.5	725
PBF Rail Term Loan [Member] | PBF Rail Logistics Company LLC [Member]
Debt Instrument [Line Items]
Long-term Debt		0	7.4	$ 35
Catalyst Obligation [Member]
Debt Instrument [Line Items]
Long-term Debt		$ 58.4	$ 102.5
Catalyst Financing Arrangement [Member] | Paulsboro Catalyst [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	[1]	1.47%
Catalyst Financing Arrangement [Member] | Delaware City Catalyst [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	[1]	3.70%
Catalyst Financing Arrangement [Member] | Toledo Catalyst [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	[1]	5.05%
Catalyst Financing Arrangement [Member] | Chalmette Catalyst - Entered 2021 [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	[1]	5.10%
Catalyst Financing Arrangement [Member] | Chalmette Catalyst - Entered 2019 [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	[1]	1.80%
Catalyst Financing Arrangement [Member] | Torrance Catalyst [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	[1]	1.78%
Catalyst Financing Arrangement [Member] | Martinez Catalyst [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	[1]	3.70%
[1]	These catalyst financing arrangements are included in Long-term debt as of December 31, 2021 as the Company has the ability and intent to finance this debt through availability under other credit facilities if the catalyst financing arrangements are not renewed at maturity.

CREDIT FACILITIES AND DEBT (Deb

CREDIT FACILITIES AND DEBT (Debt Maturities) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Long-term Debt, Fiscal Year Maturity [Abstract]
2022	$ 58.4
2023	900
2024	0
2025	1,919.5
2026	0
Thereafter	826.5
Long-term Debt	$ 3,704.4	$ 3,984.9

OTHER LONG-TERM LIABILITIES (De

OTHER LONG-TERM LIABILITIES (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Other Long-Term Liabilities [Abstract]
Environmental liabilities	$ 141	$ 140.5
Defined benefit pension plan liabilities	46.7	73.5
Contingent consideration	29.4	0
Post-retirement medical plan liabilities	18.2	22
Early railcar return liability	6	13.9
Other	9.7	17.1
Other long-term liabilities	$ 251	$ 267

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Series B Units [Member] | Guarantor, Affiliated Entity [Member]
Related Party Transaction [Line Items]
Distribution To Unitholders	$ 0	$ 0

RELATED PARTY TRANSACTIONS (Con

RELATED PARTY TRANSACTIONS (Contribution Agreements) (Details) - USD ($) $ in Millions		May 31, 2019	May 30, 2019	Apr. 24, 2019
Torrance Valley Pipeline Company LLC [Member] | TVP Holding [Member]
Related Party Transaction [Line Items]
Percentage of ownership in subsidiaries	[1]		50.00%
Torrance Valley Pipeline Company LLC [Member] | PBF Logistics LP [Member]
Related Party Transaction [Line Items]
Percentage of ownership in subsidiaries		100.00%
PBF Logistics LP [Member] | Torrance Valley Pipeline Company LLC [Member]
Related Party Transaction [Line Items]
Related Party, Distribution of Property				$ 200
[1]	On April 24, 2019, PBFX entered into a contribution agreement with PBF LLC, pursuant to which the Company contributed to PBF LLC, which in turn contributed to PBFX, all of the issued and outstanding limited liability company interests of TVP Holding Company LLC (“TVP Holding”) for total consideration of $200.0 million (the “TVPC Acquisition”). Prior to the TVPC Acquisition, TVP Holding (then a subsidiary of PBF Holding) owned a 50% equity interest in Torrance Valley Pipeline Company LLC (“TVPC”). Subsequent to the closing of the TVPC Acquisition on May 31, 2019, PBFX owns 100% of the equity interest in TVPC.

RELATED PARTY TRANSACTIONS (Com

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

Jan. 01, 2022bbl / drenewal

May 31, 2019bbl / d

Jan. 01, 2019bbl

Jul. 31, 2018Railcars_per_daybbl / drenewal

Apr. 16, 2018USD ($)bbl

Nov. 01, 2017bblrenewal

Aug. 04, 2017dekatherm_per_day

Nov. 01, 2016

Aug. 31, 2016bbl / drenewalbbl

May 01, 2016bbl / d

May 15, 2015bbl / drenewal

Dec. 12, 2014bbl / dbblrenewal

May 08, 2014bbl / drenewal

Jan. 24, 2013bbl

Dec. 31, 2021renewal

May 30, 2019bbl / d

Related Party Transaction [Line Items]

Number of Contract Renewals

2

Term of Renewal

5 years

Amended and Restated Rail Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

[1]

7 years 8 months

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

[1]

125,000

Toledo Truck Unloading & Terminaling Services Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

[2]

7 years 8 months

Number of Contract Renewals

2

Term of Renewal

5 years

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

[2]

5,500

Toledo Storage Facility Storage and Terminaling Services Agreement [Member] | Toledo Terminaling Facility [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

[2]

10 years

Number of Contract Renewals

[2]

2

Term of Renewal

[2]

5 years

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

[2]

4,400

Toledo Storage Facility Storage and Terminaling Services Agreement [Member] | Toledo Storage Facility [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

[2]

10 years

Number of Contract Renewals

[2]

2

Term of Renewal

[2]

5 years

Oil And Gas Plant, Maximum Storage Capacity | bbl

[2],[3]

3,849,271

Delaware Pipeline Services Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

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 [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

[4]

2 years 5 months

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

Related Party Transaction [Line Items]

Term of Agreement

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 [Member] | LPGs [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

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 [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

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

[5],[6],[7]

15,000

East Coast Terminals Tank Lease Agreements [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Maximum Storage Capacity | bbl

[3],[7]

350,000

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

Related Party Transaction [Line Items]

Term of Agreement

[2]

10 years

Number of Contract Renewals

[2]

2

Term of Renewal

[2]

5 years

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

[2]

50,000

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

Related Party Transaction [Line Items]

Term of Agreement

[2]

10 years

Number of Contract Renewals

[2]

2

Term of Renewal

[2]

5 years

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

75,000

75,000

[2],[8]

70,000

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

Related Party Transaction [Line Items]

Term of Agreement

[2]

10 years

Number of Contract Renewals

[2]

2

Term of Renewal

[2]

5 years

Oil And Gas Plant, Maximum Storage Capacity | bbl

[2],[3]

55,000

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

Related Party Transaction [Line Items]

Term of Agreement

[2]

10 years

Number of Contract Renewals

[2]

2

Term of Renewal

[2]

5 years

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

[2]

900,000

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

Related Party Transaction [Line Items]

Term of Agreement

[2]

10 years

Number of Contract Renewals

[2]

2

Term of Renewal

[2]

5 years

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

[2]

770,000

Paulsboro Natural Gas Pipeline Services Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

[2]

15 years

Oil And Gas Plant, Maximum Storage Capacity | dekatherm_per_day

[2]

60,000

Knoxville Terminals Agreement [Member] | Terminaling Service [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

5 years

Knoxville Terminals Agreement [Member] | Terminaling Service [Member] | PBF Logistics LP [Member] | Agreement Period One [Member]

Related Party Transaction [Line Items]

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

0.9

Knoxville Terminals Agreement [Member] | Terminaling Service [Member] | PBF Logistics LP [Member] | Agreement Period Two [Member]

Related Party Transaction [Line Items]

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

1.8

Knoxville Terminals Agreement [Member] | Terminaling Service [Member] | PBF Logistics LP [Member] | Agreement Period Three [Member]

Related Party Transaction [Line Items]

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

2.7

Knoxville Terminals Agreement [Member] | Storage Services | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

5 years

Oil And Gas Plant, Maximum Storage Capacity | bbl

[3]

115,334

Toledo Rail Loading Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

[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 [Member] | Product [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

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

30

Toledo Rail Loading Agreement [Member] | Premium Product [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

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

11.5

Chalmette Terminal Throughput Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

1 year

Chalmette Rail Unloading Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

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 [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

[2]

7 years 5 months

Number of Contract Renewals

[2]

2

Term of Renewal

[2]

5 years

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

[2]

5,000

Delaware City Terminaling Services Agreement [Member] | PBF Logistics LP [Member] | Subsequent Event [Member]

Related Party Transaction [Line Items]

Term of Agreement

4 years

Delaware City Terminaling Services Agreement [Member] | PBF Logistics LP [Member] | Scenario, Forecast [Member]

Related Party Transaction [Line Items]

Number of Contract Renewals

2

Term of Renewal

5 years

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

95,000

Chalmette Storage Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

[2]

10 years

Number of Contract Renewals

[2]

2

Term of Renewal

[2]

5 years

Oil And Gas Plant, Maximum Storage Capacity | bbl

[2],[3]

625,000

East Coast Storage Assets Terminal Storage Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Term of Agreement

[2]

8 years

Oil And Gas Plant, Maximum Storage Capacity | bbl

[2],[3]

2,953,725

East Coast Terminals commercial agreements [Member] | PBF Logistics LP [Member] | Minimum [Member]

Related Party Transaction [Line Items]

Term of Agreement

1 year

East Coast Terminals commercial agreements [Member] | PBF Logistics LP [Member] | Maximum [Member]

Related Party Transaction [Line Items]

Term of Agreement

5 years

[1]

The Amended and Restated Rail Agreements, as amended and effective as of January 1, 2018, include the Amended and Restated Delaware City Rail Terminaling Services Agreement and the Amended and Restated Delaware West Ladder Rack Terminaling Services Agreement, each between Delaware City Terminaling Company LLC (“DCTC”) and PBF Holding, with the service fees thereunder being adjusted, including the addition of an ancillary fee paid by PBF Holding on an actual cost basis. In determining payments due under the Amended and Restated Rail Agreements, excess volumes throughput under the agreements shall apply against required payments in respect to the minimum throughput commitments on a quarterly basis and, to the extent not previously applied, on an annual basis against the MVCs. Effective January 1, 2019, the existing Amended and Restated Rail Agreements were further amended for the inclusion of services through certain rail infrastructure at the PBFX East Coast storage facility.

[2]

These commercial agreements with PBFX are considered leases.

[3]

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.

[4]

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.

[5]

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.

[6]

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.

[7]

The East Coast Terminals related party agreements include varying initial term lengths, ranging from one

[8]

In connection with the TVPC Acquisition 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.

[9]

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.

RELATED PARTY TRANSACTIONS (Omn

RELATED PARTY TRANSACTIONS (Omnibus and Services Agreements) (Details) - USD ($) $ in Millions	Jan. 01, 2020	Dec. 31, 2021
Related Party Transaction [Line Items]
Related Party Transaction, Annual Fee Increase	$ 8.3
PBF Logistics LP [Member] | Fifth Amended and Restated Omnibus Agreement [Member]
Related Party Transaction [Line Items]
Term of Agreement		10 years
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party		$ 7.3
PBF Logistics LP [Member] | Services Agreement [Member]
Related Party Transaction [Line Items]
Related Party Transaction, 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) - PBF Logistics LP [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
General and Administrative Expense [Member] | Services Agreement [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction	$ 8.7	$ 8.7	$ 8.6
General and Administrative Expense [Member] | Omnibus Agreement [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction	7.3	7.6	7.7
Cost of Sales [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction	$ 304.1	$ 289.4	$ 300.9

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES (Details) $ in Millions	Feb. 01, 2020USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)
Environmental Matters
Environmental liabilities		$ 155.3	$ 151.9
Environmental liabilities, Lont-Term		$ 141	140.5
Tax Receivable Agreement [Abstract]
Percent of tax benefit received from increases in tax basis paid to stockholders		85.00%
Percentage of ownership in PBF LLC		100.00%
Payable to Related Parties, Tax Receivable Agreement		$ 48.3
Martinez Acquistion
Contingent Consideration
Term of Agreement	4 years
Working capital, including post close adjustments	$ 77.3
Business Combination, Contingent Consideration, Liability		$ 29.4	$ 0
PBF Energy [Member] | Class A Common Stock [Member]
Tax Receivable Agreement [Abstract]
Percentage of ownership in PBF LLC		99.20%	99.20%
Environmental Issue [Member] | Torrance Refinery [Member]
Environmental Matters
Environmental liabilities		$ 118.5	$ 113.7
Accrual For Environmental Loss Contingencies, Expected Future Payments Over Next Five Years		$ 49.2
Executive [Member] | Minimum [Member]
Employment Agreements
Potential lump sum payment as a multiple of base salary		1.50
Executive [Member] | Maximum [Member]
Employment Agreements
Potential lump sum payment as a multiple of base salary		2.99

COMMITMENTS AND CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES (Future Minimum Rental Payments) (Details) $ in Millions	Dec. 31, 2021USD ($)
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2022	$ 150.2
2023	125.2
2024	112
2025	108.3
2026	21.4
Thereafter	205
Total future obligation payments due	$ 722.1

LEASES (Details)

LEASES (Details) $ in Millions	Apr. 17, 2020USD ($)hydrogenPlants	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Aug. 01, 2020USD ($)
Lessee, Lease, Description [Line Items]
Number of Hydrogen Plants Sold | hydrogenPlants	5
Proceeds from sale of assets	$ 530	$ 0	$ 543.1	$ 36.3
Gain (Loss) on Disposition of Property Plant Equipment		0.2	477.8	$ 29.9
Operating Lease, Liability		1,120.5
Net gains (losses) on sale-leaseback transactions		$ 0
Lessee, Lease Not Yet Commenced, Term Of Contract		15 years
Lessee, Leases Not Yet Commenced, Liability		$ 34.1
Operating lease costs		$ 299.1	291.2
Air Products and Chemical, Inc.
Lessee, Lease, Description [Line Items]
Proceeds from sale of assets	$ 530
Gain (Loss) 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 [Member]
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term		1 year
Maximum [Member]
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 [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Right-of-Use Asset		$ 485.4	571
Operating lease costs		$ 129.1	$ 129.1
Lease with Affiliate [Member] | Minimum [Member]
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term		7 years
Lease with Affiliate [Member] | Maximum [Member]
Lessee, Lease, Description [Line Items]
Non-cancelable operating lease term		15 years

LEASES (Lease Assets and Liabil

LEASES (Lease Assets and Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Lease right of use assets	Lease right of use assets
Finance lease assets	$ 81.2	$ 80.4
Lease right of use assets	1,202.4	1,487.7
Current operating lease liabilities	155.5
Current finance lease liabilities	11.1	14.4
Long-term lease obligations	965
Long-term finance lease liabilities	70.6	68.3
Lease Liability	$ 1,202.2	$ 1,487.9
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Accrued expenses	Accrued expenses
Third Party Lease [Member]
Operating Lease, Right-of-Use Asset	$ 635.8	$ 836.3
Lease right of use assets	717	916.7
Current operating lease liabilities	64.8	78.3
Long-term lease obligations	570.3	755.9
Long-term finance lease liabilities	70.6	68.3
Lease with Affiliate [Member]
Operating Lease, Right-of-Use Asset	485.4	571
Lease right of use assets	485.4	571
Current operating lease liabilities	90.7	85.6
Long-term lease obligations	$ 394.7	$ 485.4

LEASES (Lease Cost) (Details)

LEASES (Lease Cost) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Finance lease costs, Amortization of lease right of use assets	$ 16.1	$ 14
Finance lease costs, Interest on lease liabilities	4.6	4.3
Operating lease costs	299.1	291.2
Short-term lease costs	59.3	92.3
Variable lease costs	31.6	31.1
Total lease costs	$ 410.7	$ 432.9

LEASES (Supplemental Cash Flow

LEASES (Supplemental Cash Flow and Other Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Leases - Supplemental Cash Flow and Other Information [Abstract]
Operating cash flows for operating leases	$ 297.9	$ 292.4
Operating cash flows for finance leases	4.6	4.3
Financing cash flows for finance leases	17.8	12.4
Supplemental non-cash amounts of lease liabilities arising from obtaining or remeasuring right-of-use assets	$ (106.6)	$ 702
Weighted average remaining lease term - operating leases	9 years 9 months 18 days
Weighted average remaining lease term - finance leases	6 years 6 months
Weighted average discount rate - operating leases	13.40%
Weighted average discount rate - finance leases	7.40%

LEASES (Maturity of Lease Liabi

LEASES (Maturity of Lease Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Finance Lease Liabilities, Payments, Due [Abstract]
2022	$ 16.5
2023	16.4
2024	15.7
2025	14.2
2026	13.8
Thereafter	25.6
Total minimum lease payments	102.2
Less: effect of discounting	20.5
Present value of future minimum lease payments	81.7
Less: current obligations under leases	11.1	$ 14.4
Long-term lease obligations	70.6	$ 68.3
Operating Lease Liabilities, Payments Due [Abstract]
2022	280.6
2023	252.4
2024	243
2025	202.3
2026	166
Thereafter	903.9
Total minimum lease payments	2,048.2
Less: effect of discounting	927.7
Present value of future minimum lease payments	1,120.5
Less: current obligations under leases	155.5
Long-term lease obligations	$ 965

EQUITY STRUCTURE (Additional In

EQUITY STRUCTURE (Additional Information) (Details)	12 Months Ended
	Dec. 31, 2021USD ($)voteshares	Dec. 31, 2021USD ($)shares	Dec. 31, 2021USD ($)subsidiaryshares	Dec. 31, 2021USD ($)stateshares	Dec. 31, 2020USD ($)
Class of Stock [Line Items]
Shares outstanding	0	0	0	0
Percentage of ownership in PBF LLC	100.00%	100.00%	100.00%	100.00%
Number of subsidiaries acquired			2	2
Net Income (Loss) Attributable to Noncontrolling Interest | $		$ 2,300,000			$ 300,000
Collins Pipeline Company And T&M Terminal Company [Member]
Class of Stock [Line Items]
Noncontrolling Interest, ownership Percentage by Parent	80.00%	80.00%	80.00%	80.00%
PBF Energy [Member] | Class B Common Stock [Member]
Class of Stock [Line Items]
Number of votes per share | vote	1
PBF Finance Corporation [Member]
Class of Stock [Line Items]
Shares outstanding	100	100	100	100
PBF LLC [Member] | Series B Units [Member]
Class of Stock [Line Items]
Equity unit, stated value per share | $	$ 0	$ 0	$ 0	$ 0
Number of units authorized	1,000,000	1,000,000	1,000,000	1,000,000

STOCK-BASED COMPENSATION (Share

STOCK-BASED COMPENSATION (Share-Based Compensation Expense) (Details) - General and Administrative Expense [Member] - PBF Energy [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	$ 30.3	$ 29.3	$ 30.5
Employee Stock Option [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	17.3	16.1	15.8
Restricted Stock [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	2.8	5.3	6.5
Performance Shares [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	$ 10.2	$ 7.9	$ 8.2

STOCK-BASED COMPENSATION (Weigh

STOCK-BASED COMPENSATION (Weighted Average Assumptions) (Details) - PBF Energy [Member] - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life (in years)	6 years	6 years 29 days	6 years 3 months
Expected volatility	83.80%	69.10%	38.60%
Dividend yield	0.00%	1.41%	3.54%
Risk-free rate of return	1.37%	0.81%	2.16%
Exercise price (in dollars per share)	$ 13.91	$ 13.58	$ 34.11
Weighted average fair value per unit (in dollars per share)	9.84	5.49	9.43
Granted (in dollars per share)	$ 13.91
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life (in years)	3 years 1 month 13 days
Expected volatility	83.78%
Dividend yield	0.00%
Risk-free rate of return	0.87%
Granted (in dollars per share)	$ 18.73	$ 10.77	$ 27.99
Performance Share Units | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life (in years)		2 years 10 months 20 days	2 years 2 months 1 day
Expected volatility		39.88%	37.19%
Dividend yield		0.00%	3.40%
Risk-free rate of return		0.26%	1.66%
Performance Share Units | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life (in years)		3 years 1 month 20 days	2 years 10 months 17 days
Expected volatility		82.63%	41.70%
Dividend yield		4.28%	3.67%
Risk-free rate of return		1.34%	2.51%

STOCK-BASED COMPENSATION (Sha_2

STOCK-BASED COMPENSATION (Share-Based Compensation Activity) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Weighted Average Remaining Contractual Life
Total estimated fair value, vested in period	$ 3.1	$ 4.2	$ 11.6
Employee Stock Option [Member] | PBF Energy [Member]
Options & Restricted Stock
Options, beginning balance (in shares)	13,790,777
Granted (in shares)	1,700,621
Exercised/Vested (in shares)	(52,400)
Forfeited (in shares)	(389,239)
Options, ending balance (in shares)	15,049,759	13,790,777
Options exercisable and vested (in shares)	9,397,483
Options expected to vest (in shares)	15,049,759
Weighted Average Exercise Price
Weighted average exercise price (in dollars per share)	$ 24.48	$ 25.69
Granted (in dollars per share)	13.91
Exercised (in dollars per share)	6.72
Forfeited (in dollars per share)	23.70
Weighted average exercise price, exercisable and vested (in dollars per share)	27.72
Weighted average exercise price, expected to vest (in dollars per share)	$ 24.48
Weighted Average Remaining Contractual Life
Weighted average remaining contractual term, outstanding (in years)	6 years 6 months 3 days	7 years 1 month 13 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)	6 years 6 months 3 days
Restricted Stock [Member] | PBF Energy [Member]
Options & Restricted Stock
Options, beginning balance (in shares)	303,555
Granted (in shares)	81,840
Exercised/Vested (in shares)	(229,462)
Forfeited (in shares)	(246)
Options, ending balance (in shares)	155,687	303,555
Weighted Average Exercise Price
Weighted average exercise price (in dollars per share)	$ 16.09	$ 22.32
Granted (in dollars per share)	16.13	$ 9.82	$ 28.20
Exercised (in dollars per share)	24.34
Forfeited (in dollars per share)	$ 24.18
Performance Share Units | PBF Energy [Member]
Options & Restricted Stock
Options, beginning balance (in shares)	623,160
Granted (in shares)	301,965
Options, ending balance (in shares)	745,525	623,160
Weighted Average Exercise Price
Weighted average exercise price (in dollars per share)	$ 13.93	$ 15.62
Granted (in dollars per share)	18.73	$ 10.77	$ 27.99
Exercised (in dollars per share)	$ 27.85
Weighted Average Remaining Contractual Life
Total estimated fair value, vested in period	$ 1.8	$ 0.8

STOCK-BASED COMPENSATION (Summa

STOCK-BASED COMPENSATION (Summary of Unit Activity) (Details) - PBF Energy [Member] - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Performance Units [Member]
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	20,178,013	16,071,745
Granted (in shares)	11,782,926
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested, Number of Shares (in shares	(7,676,658)
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	745,525	623,160
Granted (in shares)	301,965
Exercised (in dollars per share)	$ 27.85
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested, Number of Shares (in shares	(179,600)
Granted (in dollars per share)	$ 18.73	$ 10.77	$ 27.99
Weighted average exercise price (in dollars per share)	$ 13.93	$ 15.62

STOCK-BASED COMPENSATION (Addit

STOCK-BASED COMPENSATION (Additional Information) (Details)	Oct. 31, 2020number_period	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2021USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total estimated fair value, vested in period		$ 3,100,000	$ 4,200,000	$ 11,600,000
Employee Stock Option [Member] | PBF Energy [Member]
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		$ 15,600,000			$ 15,600,000
Total intrinsic value of stock options exercisable		5,000,000			5,000,000
Total intrinsic value of stock options exercised during period		400,000	0	$ 300,000
Unrecognized compensation expense		$ 36,700,000			36,700,000
Restricted Stock [Member] | PBF Energy [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period		4 years
Unrecognized compensation expense		$ 100,000			$ 100,000
Performance Share Units And Performance Unit Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Requisite Service Period	3 years	3 years
Share-Based Compensation Arrangement By Share-based Payment Award, Award Measurement, Number Of Periods | number_period	4
Performance Share Units And Performance Unit Awards [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Distribution Percentage Based On Performance Measurements		0.00%
Performance Share Units And Performance Unit Awards [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Distribution Percentage Based On Performance Measurements		200.00%
Performance Share Units And Performance Unit Awards [Member] | PBF Energy [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Requisite Service Period					3 years
Share-Based Compensation Arrangement By Share-based Payment Award, Award Measurement, Number Of Periods | number_period	4
Performance Share Units And Performance Unit Awards [Member] | PBF Energy [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Distribution Percentage Based On Performance Measurements		0.00%
Performance Share Units And Performance Unit Awards [Member] | PBF Energy [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Distribution Percentage Based On Performance Measurements		200.00%
Performance share units [Member] | PBF Energy [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense		$ 8,200,000			$ 8,200,000
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition		2 years 7 months 17 days
Performance Units [Member] | PBF Energy [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation expense		$ 9,200,000			9,200,000
Total estimated fair value, vested in period		$ 5,200,000	$ 3,200,000
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition		2 years 6 months 14 days
Share-based compensation, Performance Unit, Payout, At Target		$ 1			1
Performance Units [Member] | PBF Energy [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, Performance Unit, Payout, At Target		$ 2			$ 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, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Benefits [Member]
Change in benefit obligation:
Benefit obligation at beginning of year	$ 329.3	$ 271.2
Service cost	57.5	59	$ 43.6
Interest cost	5.3	6.9	8.3
Plan amendments	0	0
Benefit payments	(31.2)	(18)
Actuarial (gain) loss	(7.6)	10.2
Projected benefit obligation at end of year	353.3	329.3	271.2
Change in plan assets:
Fair value of plan assets at beginning of year	255.8	197.4
Actual return on plan assets	27.7	28.6
Benefits paid	(31.2)	(18)
Employer contributions	54	47.8
Fair value of plan assets at end of year	306.3	255.8	197.4
Reconciliation of funded status:
Fair value of plan assets at end of year	306.3	255.8	197.4
Less benefit obligations at end of year	353.3	329.3	271.2
Funded status at end of year	(47)	(73.5)
Post Retirement Medical Plan [Member]
Change in benefit obligation:
Benefit obligation at beginning of year	22	17.5
Service cost	1.1	1	1
Interest cost	0.3	0.4	0.7
Plan amendments	0	1.8
Benefit payments	(1.2)	(0.6)
Actuarial (gain) loss	(4)	1.9
Projected benefit obligation at end of year	18.2	22	17.5
Change in plan assets:
Fair value of plan assets at beginning of year	0	0
Actual return on plan assets	0	0
Benefits paid	(1.2)	(0.6)
Employer contributions	1.2	0.6
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	18.2	22	$ 17.5
Funded status at end of year	$ (18.2)	$ (22)

EMPLOYEE BENEFIT PLANS (Expecte

EMPLOYEE BENEFIT PLANS (Expected Benefit Payments) (Details) $ in Millions	Dec. 31, 2021USD ($)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
2022	$ 24.8
2023	18.1
2024	20.1
2025	23.7
2026	27.1
Years 2027-2031	168.6
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
2022	1.8
2023	1.7
2024	1.6
2025	1.5
2026	1.5
Years 2027-2031	$ 6.8

EMPLOYEE BENEFIT PLANS (Net Per

EMPLOYEE BENEFIT PLANS (Net Periodic Benefit Cost) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 57.5	$ 59	$ 43.6
Interest cost	5.3	6.9	8.3
Expected return on plan assets	(14.2)	(12.5)	(9.6)
Amortization of prior service cost and actuarial loss	0.1	0.3	0.3
Net periodic benefit cost	48.7	53.7	42.6
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	1.1	1	1
Interest cost	0.3	0.4	0.7
Expected return on plan assets	0	0	0
Amortization of prior service cost and actuarial loss	0.7	0.6	0.5
Net periodic benefit cost	$ 2.1	$ 2	$ 2.2

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, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service costs	$ 0	$ 0	$ 0
Net actuarial (gain) loss	(21.1)	(5.9)	(10.7)
Amortization of losses and prior service cost	(0.1)	(0.3)	(0.3)
Total changes in other comprehensive (income) loss	(21.2)	(6.2)	(11)
Prior service costs	(0.5)	(0.6)
Net actuarial gain (loss)	12.7	(8.4)
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax	12.2	(9)
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service costs	0	1.8	0
Net actuarial (gain) loss	(4)	1.9	(2.3)
Amortization of losses and prior service cost	(0.7)	(0.6)	(0.5)
Total changes in other comprehensive (income) loss	(4.7)	3.1	$ (2.8)
Prior service costs	(4.3)	(5)
Net actuarial gain (loss)	7.8	3.9
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax	$ 3.5	$ (1.1)

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, 2021	Dec. 31, 2020
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service costs	$ (0.5)	$ (0.6)
Net actuarial gain (loss)	12.7	(8.4)
Total	12.2	(9)
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service costs	(4.3)	(5)
Net actuarial gain (loss)	7.8	3.9
Total	$ 3.5	$ (1.1)

EMPLOYEE BENEFIT PLANS (Assumpt

EMPLOYEE BENEFIT PLANS (Assumptions Used) (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Benefits [Member]
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate	2.78%	2.36%
Rate of compensation increase	4.26%	4.28%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Expected long-term rate of return on plan assets	5.25%	5.75%	6.00%
Rate of compensation increase	4.28%	4.28%	4.55%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Weighted-Average Interest Crediting Rate	1.57%	2.19%	3.34%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate, Service Cost	2.40%	2.94%	4.24%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate, Interest Cost	1.74%	2.50%	3.92%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate, Interest On Service Cost	1.92%	2.59%	4.00%
Supplemental Employee Retirement Plan [Member]
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate	2.73%	2.21%
Rate of compensation increase	4.50%	4.50%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Rate of compensation increase	4.50%	4.50%	5.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Weighted-Average Interest Crediting Rate	1.57%	2.19%	3.34%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate, Service Cost	2.26%	2.79%	4.19%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate, Interest Cost	1.53%	2.33%	3.83%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate, Interest On Service Cost	1.75%	2.42%	3.90%
Post Retirement Medical Plan [Member]
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate	2.46%	1.90%
Rate of compensation increase	0.00%	0.00%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate, Service Cost	2.35%	2.86%	4.21%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate, Interest Cost	1.28%	2.21%	3.69%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate, Interest On Service Cost	2.11%	2.68%	4.09%

EMPLOYEE BENEFIT PLANS (Assumed

EMPLOYEE BENEFIT PLANS (Assumed Health Care Cost Trend Rates) (Details) - Post Retirement Medical Plan [Member]	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	5.20%	5.40%
Rate to which the cost trend rate was assumed to decline (the ultimate trend rate)	4.00%	4.50%
Year that the rate reached the ultimate trend rate	2046	2038

EMPLOYEE BENEFIT PLANS (Fair Va

EMPLOYEE BENEFIT PLANS (Fair Value of Assets of the Company's Qualified Plan) (Details) - Pension Benefits [Member] - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	$ 306.3	$ 255.8	$ 197.4
Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	306.3	255.8
Level 1 [Member] | Domestic Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	73.9	64.4
Level 1 [Member] | Developed International Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	37.7	38.2
Level 1 [Member] | Emerging Market Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	24.8	20.7
Level 1 [Member] | Global Low Volatility Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	24.1	22.5
Level 1 [Member] | Fixed-Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	121.6	95.7
Level 1 [Member] | Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	23.2	13.3
Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	$ 1	$ 1

EMPLOYEE BENEFIT PLANS (Additio

EMPLOYEE BENEFIT PLANS (Additional Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Maximum age to receive health care coverage	65 years
Accumulated benefit obligation	$ 298.9	$ 281.5
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Required service period for employee participation	30 days
Basic contributions as a percentage of annual salary	50.00%
Company matching contribution, percent of match	200.00%
Company matching contribution, percent of employees' annual pay	3.00%
Contribution to the qualified defined contribution plans	$ 27.8	$ 32.7	$ 27.5
Estimated future contributions in 2019	$ 35.6
Pension Benefits [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	54.00%
Pension Benefits [Member] | Fixed Income Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	40.00%
Pension Benefits [Member] | Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	6.00%

REVENUES (Details)

REVENUES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Product Information [Line Items]
Revenues	$ 27,202	$ 15,045	$ 24,468.9
Deferred revenue	40.3	45.1
Gasoline and Distillates [Member]
Product Information [Line Items]
Revenues	23,489.5	12,799.4	21,278.4
Feedstocks and other [Member]
Product Information [Line Items]
Revenues	1,310.1	935.5	806.9
Asphalt and blackoils [Member]
Product Information [Line Items]
Revenues	1,217.8	777.9	1,426.4
Chemicals [Member]
Product Information [Line Items]
Revenues	889.8	351.5	682.3
Lubricants [Member]
Product Information [Line Items]
Revenues	$ 294.8	$ 180.7	$ 274.9

INCOME TAXES (Narrative) (Detai

INCOME TAXES (Narrative) (Details) - 12 months ended Dec. 31, 2021	subsidiary	state
Class of Stock [Line Items]
Number of subsidiaries acquired	2	2

INCOME TAXES (Components of Inc

INCOME TAXES (Components of Income Tax (Benefit) Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Current income tax expense (benefit)	$ 0.5	$ (1.2)	$ 0.5
Deferred income tax (benefit) expense	(14.5)	7.3	(8.8)
Total income tax (benefit) expense	$ (14)	$ 6.1	$ (8.3)

INCOME TAXES (Components of Def

INCOME TAXES (Components of Deferred Tax Assets and Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Deferred tax assets
Net operating loss carry forwards	$ 0.3	$ 0.1
Other	0.5	0
Total deferred tax assets	0.8	0.1
Valuation allowance	0	0
Total deferred tax assets, net	0.8	0.1
Deferred tax liabilities
Property, plant and equipment	16.3	17.5
Inventory	8.7	21.3
Total deferred tax liabilities	25	38.8
Net deferred tax liability	$ (24.2)	$ (38.7)

FAIR VALUE MEASUREMENTS (Measur

FAIR VALUE MEASUREMENTS (Measured on Recurring Basis) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Plan [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Plan Assets, Amount	$ 306.3	$ 255.8	$ 197.4
Level 1 [Member] | Pension Plan [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Plan Assets, Amount	306.3	255.8
Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Plan Assets, Amount		21.2
Commodity contract [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	83.5	9
Derivative, Collateral, Right to Reclaim Cash	(71.5)	(6)
Derivative Liability	12	3
Commodity contract [Member] | Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	79.7	2.3
Commodity contract [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	3.8	6.7
Commodity contract [Member] | Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	0	0
Catalyst Obligation [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	58.4	102.5
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability	58.4	102.5
Catalyst Obligation [Member] | Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0
Catalyst Obligation [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	58.4	102.5
Catalyst Obligation [Member] | Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
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 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	953.9
Derivative, Collateral, Right to Reclaim Cash	0
Renewable Energy Credit and Emissions Obligation | Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0
Renewable Energy Credit and Emissions Obligation | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	953.9
Renewable Energy Credit and Emissions Obligation | Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0
Contingent Consideration | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	29.4	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Contingent Consideration | Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0
Contingent Consideration | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0
Contingent Consideration | Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	29.4	0
Money market funds [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	260.9	402.3
Money market funds [Member] | Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	260.9	402.3
Money market funds [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
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 [Member] | Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Commodity contract [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	71.5	6
Derivative, Collateral, Obligation to Return Cash	(71.5)	(6)
Derivative Asset	0	0
Commodity contract [Member] | Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	71.5	2.5
Commodity contract [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	0	3.5
Commodity contract [Member] | Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	0	0
Inventory Intermediation Agreement Obligation [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	19.7	11.3
Derivative, Collateral, Obligation to Return Cash	0	0
Derivative Asset	19.7	11.3
Inventory Intermediation Agreement Obligation [Member] | Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	0	0
Inventory Intermediation Agreement Obligation [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	19.7	11.3
Inventory Intermediation Agreement Obligation [Member] | Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
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 [Member] | Pension Plan [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Plan Assets, Amount	$ 20.7

FAIR VALUE MEASUREMENTS (Fair V

FAIR VALUE MEASUREMENTS (Fair Value and Carrying Value of Debt) (Details) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020	Dec. 22, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Gross		$ 3,704.4	$ 3,984.9
Less - Current debt		0	(7.4)
Unamortized Debt Issuance Expense		(31.6)	(45.3)
Long-term debt		3,673.3	3,932.8
Long-term Debt, Fair Value		3,147.9	3,280.6
Less - Current maturities, Fair value		0	(7.4)
Long-term debt, Fair value		3,147.9	3,273.2
Debt Instrument, Unamortized Premium		0.5	0.6
Revolving Credit Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Line of Credit		900	900
Lines of Credit, Fair Value Disclosure	[1]	900	900
2025 Senior Secured Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		1,250	1,250
Long-term Debt, Fair Value	[2]	1,192.7	1,232.9
2028 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		826.5	1,000
Long-term Debt, Fair Value	[2]	520.9	562.5
2025 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		669.5	725
Long-term Debt, Fair Value	[2]	475.9	475.3
Catalyst Obligation [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		58.4	102.5
Long-term Debt, Fair Value	[3]	58.4	102.5
PBF Rail Logistics Company LLC [Member] | PBF Rail Term Loan [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		0	7.4	$ 35
Long-term Debt, Fair Value	[1]	$ 0	$ 7.4
[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.

FAIR VALUE MEASUREMENTS (Change

FAIR VALUE MEASUREMENTS (Change in Fair Value at Level 3) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
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	0	0
Purchases	0	77,300,000
Settlements	0	1,500,000
Unrealized gain (loss) included in earnings	29,400,000	(77,800,000)
Balance at end of period	29,400,000	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Accretion	$ 0	$ 2,000,000

DERIVATIVES (Narrative) (Detail

DERIVATIVES (Narrative) (Details)	12 Months Ended
	Dec. 31, 2021USD ($)bbl	Dec. 31, 2020USD ($)bbl	Dec. 31, 2019USD ($)
Derivative [Line Items]
Gain (loss) on fair value hedge ineffectiveness | $	$ 0	$ 0	$ 0
Crude Oil and Feedstock Inventory [Member] | Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	2,081,783	0
Intermediates and Refined Products Inventory [Member] | Fair Value Hedging [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	2,070,550	2,604,736
Crude Oil Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	36,246,000	7,183,000
Refined Product Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	5,819,000	2,810,000

DERIVATIVES (Fair Value of Deri

DERIVATIVES (Fair Value of Derivative Instruments) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Designated as Hedging Instrument [Member] | Inventory Intermediation Agreement Obligation [Member] | Accrued Expenses [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	$ 19.7	$ 11.3
Not Designated as Hedging Instrument [Member] | Commodity contract [Member] | Accounts Receivable [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	$ (12)	$ (3)

DERIVATIVES (Gain (Loss) Recogn

DERIVATIVES (Gain (Loss) Recognized in Income) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on fair value hedge ineffectiveness	$ 0	$ 0	$ 0
Designated as Hedging Instrument [Member] | Cost of Sales [Member] | Inventory Intermediation Agreement Obligation [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	8,400,000	12,600,000	(25,400,000)
Designated as Hedging Instrument [Member] | Cost of Sales [Member] | Intermediates and Refined Products Inventory [Member] | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	(8,400,000)	(12,600,000)	25,400,000
Not Designated as Hedging Instrument [Member] | Cost of Sales [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	$ (83,400,000)	$ 44,400,000	$ 36,500,000