PBF Holding 10-Q 12 Nov 15 2015 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information Document - shares	9 Months Ended
	Sep. 30, 2015	Nov. 05, 2015
Entity Information [Line Items]
Entity Registrant Name	PBF HOLDING CO LLC
Entity Central Index Key	1,566,011
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2015
Document Fiscal Period Focus	Q3
Document Fiscal Year Focus	2,015
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Current Reporting Status	Yes
Entity Common Stock, Shares Outstanding		0
PBF Finance Corporation [Member]
Entity Information [Line Items]
Entity Registrant Name	PBF FINANCE CORPORATION
Entity Central Index Key	1,566,097
Entity Common Stock, Shares Outstanding		100

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014	Sep. 30, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$ 369,421	$ 218,403	$ 360,347	$ 76,970
Accounts receivable	395,624	551,269
Accounts receivable - affiliate	3,299	3,223
Inventories	1,101,182	1,102,261
Prepaid expense and other current assets	55,152	32,157
Total current assets	1,924,678	1,907,313
Property, plant and equipment, net	1,814,507	1,806,060
Deferred charges and other assets, net	301,931	330,517
Total assets	4,041,116	4,043,890
Current liabilities:
Accounts payable	212,434	335,182
Accounts payable - affiliate	24,272	11,630
Accrued expenses	1,049,237	1,129,970
Deferred revenue	4,174	1,227
Total current liabilities	1,290,117	1,478,009
Delaware Economic Development Authority loan	8,000	8,000
Long-term debt	764,422	742,349
Intercompany notes payable	152,037	122,264
Other long-term liabilities	63,081	62,752
Total liabilities	$ 2,277,657	$ 2,413,374
Commitments and contingencies (Note 8)
Equity:
Member's equity	$ 1,131,992	$ 1,144,100
Retained earnings	657,028	513,292
Accumulated other comprehensive loss	(25,561)	(26,876)
Total equity	1,763,459	1,630,516
Total liabilities and equity	$ 4,041,116	$ 4,043,890

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues	$ 3,217,640	$ 5,260,003	$ 9,763,440	$ 15,308,155
Costs and expenses:
Cost of sales, excluding depreciation	2,858,409	4,685,652	8,414,423	13,776,574
Operating expenses, excluding depreciation	200,014	200,858	625,542	679,538
General and administrative expenses	47,802	34,786	116,115	103,505
(Gain) loss on sale of assets	(142)	18	(1,133)	(162)
Depreciation and amortization expense	46,484	67,686	139,757	135,417
Total cost and expenses	3,152,567	4,989,000	9,294,704	14,694,872
Income from operations	65,073	271,003	468,736	613,283
Other income (expenses)
Change in fair value of catalyst leases	4,994	5,543	8,982	1,204
Interest expense, net	(21,888)	(24,031)	(65,915)	(75,704)
Net income	$ 48,179	$ 252,515	$ 411,803	$ 538,783

Condensed Consolidated Stateme4

Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Net income	$ 48,179	$ 252,515	$ 411,803	$ 538,783
Other comprehensive income:
Unrealized gain (loss) on available for sale securities	119	(160)	115	(75)
Net gain on pension and other postretirement benefits	400	242	1,200	691
Total other comprehensive income	519	82	1,315	616
Comprehensive income	$ 48,698	$ 252,597	$ 413,118	$ 539,399

Condensed Consolidated Stateme5

Condensed Consolidated Statement of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Net income	$ 411,803	$ 538,783
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization	145,975	140,863
Stock-based compensation	6,329	4,725
Change in fair value of catalyst lease obligations	(8,982)	(1,204)
Change in non-cash lower of cost or market adjustment	81,147	0
Non-cash change in inventory repurchase obligations	53,370	(31,602)
Pension and other post retirement benefit costs	19,340	16,462
Gain on disposition of property, plant and equipment	(1,133)	(162)
Changes in current assets and current liabilities:
Accounts receivable	155,645	(101,752)
Due to/from affiliates	12,566	3,998
Inventories	(110,830)	(378,538)
Prepaid expense and other current assets	(22,995)	25,612
Accounts payable	(122,748)	(76,008)
Accrued expenses	(342,781)	268,649
Deferred revenue	2,947	(6,017)
Other assets and liabilities	(21,884)	(15,740)
Net cash provided by operations	257,769	388,069
Cash flows from investing activities:
Expenditures for property, plant and equipment	(287,931)	(253,454)
Expenditures for deferred turnaround costs	(39,725)	(58,423)
Expenditures for other assets	(7,275)	(13,446)
Proceeds from sale of assets	168,270	74,343
Net cash used in investing activities	(166,661)	(250,980)
Cash flows from financing activities:
Proceeds from members' capital contributions	0	328,664
Proceeds from intercompany notes payable	29,773	90,761
Proceeds from Rail Facility revolver borrowings	102,075	35,925
Repayments of Rail Facility revolver borrowings	(71,938)	0
Distributions to members	0	(283,680)
Proceeds from revolver borrowings	0	395,000
Repayments of revolver borrowings	0	(410,000)
Deferred financing costs and other	0	(10,382)
Net cash provided by financing activities	59,910	146,288
Net increase in cash and cash equivalents	151,018	283,377
Cash and equivalents, beginning of period	218,403	76,970
Cash and equivalents, end of period	369,421	360,347
Non-cash activities:
Conversion of Delaware Economic Development Authority loan to grant	0	4,000
Accrued distributions	268,066	0
Accrued construction in progress and unpaid fixed assets	4,670	65,193
Conversion of Delaware Economic Development Authority loan to grant	$ 15,975	$ 70,185

DESCRIPTION OF THE BUSINESS AND

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION	9 Months Ended
	Sep. 30, 2015
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"), a Delaware limited liability 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 94.4% of the outstanding economic interest in, PBF LLC as of September 30, 2015 . PBF Finance Corporation ("PBF Finance") is a wholly-owned subsidiary of PBF Holding. Delaware City Refining Company LLC ("Delaware City Refining" or "DCR"), PBF Power Marketing LLC, PBF Energy Limited, Paulsboro Refining Company LLC, Paulsboro Natural Gas Pipeline Company LLC and Toledo Refining Company LLC are PBF Holding’s principal operating subsidiaries and are all wholly-owned subsidiaries of PBF Holding. Collectively, PBF Holding and its consolidated subsidiaries are referred to hereinafter as the "Company". On May 14, 2014, PBF Logistics LP ("PBFX"), a Delaware master limited partnership, completed its initial public offering (the "PBFX Offering") of 15,812,500 common units. The initial assets distributed by PBF Holding to PBF LLC, which were then contributed to PBFX, consisted of the Delaware City Rail Unloading Terminal (“DCR Rail Terminal”), which was part of PBF Holding’s Delaware City, Delaware refinery, and the Toledo Truck Unloading Terminal (“Toledo Truck Terminal”), which was part of PBF Holding’s Toledo, Ohio refinery. On September 30, 2014, PBF Holding distributed to PBF LLC all of the equity interests of Delaware City Terminaling Company II LLC ("DCT II"), which assets consisted solely of the Delaware City heavy crude unloading rack (the "DCR West Rack"). PBF LLC then contributed to PBFX all of the equity interests of DCT II. On December 11, 2014, PBF Holding distributed to PBF LLC all of the issued and outstanding limited liability company interests of Toledo Terminaling Company LLC ("Toledo Terminaling"), whose assets consist of a tank farm and related facilities located at PBF Energy's Toledo refinery, including a propane storage and loading facility (the "Toledo Storage Facility"). PBF LLC then contributed to PBFX all of the issued and outstanding limited liability company interests of Toledo Terminaling. On May 14, 2015, PBF Holding distributed to PBF LLC all of the issued and outstanding limited liability company interests of Delaware Pipeline Company LLC ("DPC") and Delaware City Logistics Company LLC ("DCLC"), whose assets consist of a products pipeline, truck rack and related facilities located at our Delaware City refinery (collectively the "Delaware City Products Pipeline and Truck Rack"). PBF LLC then contributed to PBFX all of the issued and outstanding limited liability company interests of the Delaware City Products Pipeline and Truck Rack. Refer to Note 7 "Related Party Transactions" of our Notes to Condensed Consolidated Financial Statements for further information on agreements entered into with PBFX. Substantially all of the Company’s operations are in the United States. The Company’s three 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. To generate earnings and cash flows from operations, the Company is primarily dependent upon processing crude oil and selling refined petroleum products at margins sufficient to cover fixed and variable costs and other expenses. Crude oil and refined petroleum products are commodities; and factors largely out of the Company’s control can cause prices to vary over time. The potential margin volatility can have a material effect on the Company’s financial position, earnings and cash flow. Basis of Presentation The unaudited condensed consolidated financial information furnished herein reflects all adjustments (consisting of normal recurring accruals) which are, in the opinion of management, considered necessary for a fair presentation of the financial position and the results of operations and cash flows of the Company for the periods presented. All intercompany accounts and transactions have been eliminated in consolidation. These unaudited condensed consolidated financial statements of the Company have been prepared in accordance with U.S. generally accepted accounting principles ("GAAP") for interim financial information. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. These interim condensed consolidated financial statements should be read in conjunction with the financial statements included in the Annual Report on Form 10-K for the year ended December 31, 2014 of PBF Holding Company LLC and PBF Finance Corporation. The results of operations for the three and nine months ended September 30, 2015 are not necessarily indicative of the results to be expected for the full year. Recent Accounting Pronouncements In April 2015, the FASB issued ASU No. 2015-03, "Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs" ("ASU 2015-03"), which requires debt issuance costs related to a recognized debt liability to be presented on the balance sheet as a direct deduction from the debt liability rather than as an asset. The standard is effective for interim and annual periods beginning after December 15, 2015 and early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In August 2015, the FASB issued ASU No. 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date” (“ASU 2015-14”), which defers the effective date of ASU 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”) for all entities by one year. The guidance in ASU 2014-09 will replace most existing revenue recognition guidance in GAAP when it becomes effective. Under ASU 2015-14, this guidance becomes effective for interim and annual periods beginning after December 15, 2017 and permits the use of either the retrospective or cumulative effect transition method. Under ASU 2015-14, early adoption is permitted only as of annual reporting periods beginning after December 15, 2016, including interim reporting periods within that reporting period. The Company continues to evaluate the impact of this new standard on its consolidated financial statements and related disclosures. In September 2015, the FASB issued ASU No. 2015-16, "Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments" ("ASU 2015-16"), which requires (i) that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined, (ii) that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date, (iii)that an entity present separately on the face of the income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. Under ASU 2015-16, this guidance becomes effective for annual periods beginning after December 15, 2016 and interim periods within annual periods beginning after December 15, 2017 with prospective application with early adoption permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.

INVENTORIES

INVENTORIES	9 Months Ended
	Sep. 30, 2015
Inventory Disclosure [Abstract]
INVENTORIES	INVENTORIES Inventories consisted of the following: September 30, 2015 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 954,744 $ 21,288 $ 976,032 Refined products and blendstocks 545,279 310,238 855,517 Warehouse stock and other 40,890 — 40,890 $ 1,540,913 $ 331,526 $ 1,872,439 Lower of cost or market reserve (662,638 ) (108,619 ) (771,257 ) Total inventories $ 878,275 $ 222,907 $ 1,101,182 December 31, 2014 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 918,756 $ 61,122 $ 979,878 Refined products and blendstocks 520,308 255,459 775,767 Warehouse stock and other 36,726 — 36,726 $ 1,475,790 $ 316,581 $ 1,792,371 Lower of cost or market reserve (609,774 ) (80,336 ) (690,110 ) Total inventories $ 866,016 $ 236,245 $ 1,102,261 Inventory under inventory supply and intermediation arrangements includes certain crude oil stored at the Company’s Delaware City refinery's storage facilities that the Company will purchase as it is consumed in connection with its crude supply agreement; and intermediates and light finished products sold to counterparties in connection with the intermediation agreements and stored in the Paulsboro and Delaware City refineries' storage facilities. Due to the lower crude oil and refined product pricing environment at the end of 2014 and into the third quarter of 2015, the Company recorded adjustments to value its inventories to the lower of cost or market. During the three months ended September 30, 2015 , the Company recorded an adjustment to value its inventories to the lower of cost or market which decreased both operating income and net income by $208,313 reflecting the net change in the lower of cost or market inventory reserve from $562,944 at June 30, 2015 to $771,257 at September 30, 2015 . During the nine months ended September 30, 2015 , the Company recorded an adjustment to value its inventories to the lower of cost or market which decreased both operating income and net income by $81,147 reflecting the net change in the lower of cost or market inventory reserve from $690,110 at December 31, 2014 to $771,257 at September 30, 2015 .

DEFERRED CHARGES AND OTHER ASSE

DEFERRED CHARGES AND OTHER ASSETS, NET	9 Months Ended
	Sep. 30, 2015
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: September 30, December 31, Deferred turnaround costs, net $ 183,618 $ 204,987 Catalyst, net 71,516 77,322 Deferred financing costs, net 25,006 30,128 Linefill 10,230 10,230 Restricted cash 1,500 1,521 Intangible assets, net 231 357 Other 9,830 5,972 Total deferred charges and other assets, net $ 301,931 $ 330,517

ACCRUED EXPENSES

ACCRUED EXPENSES	9 Months Ended
	Sep. 30, 2015
Payables and Accruals [Abstract]
ACCRUED EXPENSES	ACCRUED EXPENSES Accrued expenses consisted of the following: September 30, December 31, Inventory-related accruals $ 407,678 $ 588,297 Accrued distributions 268,066 — Inventory supply and intermediation arrangements 212,930 253,549 Accrued transportation costs 49,548 59,959 Accrued salaries and benefits 37,766 55,993 Excise and sales tax payable 20,430 40,444 Accrued utilities 9,633 22,337 Customer deposits 8,910 24,659 Accrued interest 6,601 22,946 Accrued construction in progress 4,634 31,452 Other 23,041 30,334 Total accrued expenses $ 1,049,237 $ 1,129,970 The Company has the obligation to repurchase certain intermediates and finished products that are held in the Company’s refinery storage tanks at the Delaware City and Paulsboro refineries in accordance with the Inventory Intermediation Agreements with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. ("J. Aron"). A liability is recognized for the Inventory supply and intermediation arrangements and is recorded at market price for the J. Aron owned inventory held in the Company's storage tanks under the Inventory Intermediation Agreements, with any change in the market price being recorded in cost of sales. The Company has the obligation to purchase and sell feedstocks under a supply agreement with Statoil Marketing and Trading (US) Inc. ("Statoil") for its Delaware City refinery (the “Crude Supply Agreement”). Statoil purchases the refinery's production of certain feedstocks or purchases feedstocks from third parties on the refinery's behalf. Legal title to the feedstocks is held by Statoil and the feedstocks are held in the refinery's storage tanks until they are needed for further use in the refining process. At that time, the products are drawn out of the storage tanks and purchased by the refinery. These purchases and sales are settled monthly at the daily market prices related to those 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 refinery to Statoil. Inventory remains at cost and the net cash receipts result in a liability. The Company is subject to obligations to purchase Renewable Identification Numbers ("RINs") required to comply with the Renewable Fuels Standard. The Company's overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by the Environmental Protection Agency ("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 expense and other current assets when the amount of RINs earned and purchased is greater than the RINs liability. Accrued distributions represent unpaid distributions to PBF LLC related to tax distributions and non-tax distributions made by PBF LLC to its members.

INCOME TAXES

INCOME TAXES	9 Months Ended
	Sep. 30, 2015
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 no benefit or provision for federal or state income tax in the PBF Holding financial statements.

INTERCOMPANY NOTE PAYABLE

INTERCOMPANY NOTE PAYABLE	9 Months Ended
	Sep. 30, 2015
INTERCOMPANY NOTE PAYABLE [Abstract]
INTERCOMPANY NOTE PAYABLE	INTERCOMPANY NOTES PAYABLE As of September 30, 2015 , PBF Holding had outstanding notes payable with PBF Energy and PBF LLC for an aggregate principal amount of $152,037 ( $122,264 as of December 31, 2014). The notes have an interest rate of 2.5% and a five year term but may be prepaid in whole or in part at any time, at the option of PBF Holding, without penalty or premium.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 2015
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONS 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, storage and pipeline services agreements with PBFX under which PBFX provides commercial transportation, terminaling, storage and pipeline services to the Company. These agreements with PBFX include: Delaware City Rail Terminaling Services Agreement PBF Holding entered into a rail terminaling services agreement with PBFX to obtain terminaling services at the DCR Rail Terminal (the “DCR Terminaling Agreement”). Under the DCR Terminaling Agreement, PBF Holding is obligated to throughput aggregate volumes of crude oil of at least 85,000 barrels per day (“bpd”) for each quarter (in each case, calculated on a quarterly average basis) for a terminaling service fee of $2.03 per barrel, which will decrease to $0.50 per barrel to the extent volumes exceed the minimum throughput commitment. PBF Holding also pays PBFX for providing related ancillary services at the terminal that are specified in the agreement. For the three and nine months ended September 30, 2015 , PBF Holding paid PBFX fees of $15,890 and $47,153 respectively, related to the DCR Terminaling Agreement. For the three and nine months ended September 30, 2014 , PBF Holding paid PBFX fees of $13,800 and $21,000 , respectively, related to the DCR Terminaling Agreement. Toledo Truck Unloading & Terminaling Agreement PBF Holding entered into a truck unloading and terminaling services agreement with PBFX to obtain terminaling services at the Toledo Truck Terminal (as amended the “Toledo Terminaling Agreement”). Under the Toledo Terminaling Agreement, PBF Holding is obligated to throughput aggregate volumes of crude oil of at least 5,500 bpd (calculated on a quarterly average basis) for a terminaling service fee of $1.016 per barrel. PBF Holding also pays PBFX for providing related ancillary services at the terminal which are specified in the Toledo Terminaling Agreement. For the three and nine months ended September 30, 2015 , PBF Holding paid PBFX fees of $1,766 and $3,608 , respectively, related to the Toledo Terminaling Agreement. For the three and nine months ended September 30, 2014 , PBF Holding paid PBFX fees of $944 and $1,526 , respectively, related to the Toledo Terminaling Agreement. Delaware City West Ladder Rack Terminaling Services Agreement PBF Holding entered into a rail terminaling services agreement with PBFX to obtain terminaling services at the DCR West Rack (the “West Ladder Rack Terminaling Agreement”). Under the West Ladder Rack Terminaling Agreement, PBF Holding is obligated to throughput aggregate volumes of crude oil of at least 40,000 bpd for a terminaling service fee equal to $2.20 per barrel for all volumes of crude oil throughput up to the minimum throughput commitment, and $1.50 per barrel for all volumes of crude oil throughput in excess of the minimum throughput commitment, in any contract quarter. PBF Holding also pays PBFX for providing related ancillary services at the terminal which are specified in the West Ladder Rack Terminaling Agreement. For the three and nine months ended September 30, 2015 , PBF Holding paid PBFX fees of $8,096 and $24,024 , respectively, related to the West Ladder Rack Terminaling Agreement. For the three and nine months ended September 30, 2014 , PBF Holding paid PBFX no fees related to the West Ladder Rack Terminaling Agreement. Toledo Storage Facility Storage and Terminaling Services Agreement PBF Holding entered into a storage and terminaling services agreement with PBFX (the “Toledo Storage Facility Storage and Terminaling Agreement”). Under the Toledo Storage Facility Storage and Terminaling Agreement, PBFX provides PBF Holding with storage and throughput services in return for storage and throughput fees. The storage services require PBFX to accept, redeliver and store all products tendered by PBF Holding in the tanks and load products at the storage facility on behalf of PBF Holding up to the effective operating capacity of each tank, the loading capacity of the propane rack and the overall capacity of the Toledo Storage Facility. PBF Holding pays a fee of $0.50 per barrel of shell capacity dedicated to PBF Holding under the Toledo Storage Facility Storage and Terminaling Agreement. The minimum throughput commitment for the propane storage and loading facility is 4,400 bpd for a fee equal to $2.52 per barrel of product loaded up to the minimum throughput commitment and in excess of the minimum throughput commitment. If PBF Holding does not throughput the aggregate amounts equal to the minimum throughput commitment described above, PBF Holding will be required to pay a shortfall payment equal to the shortfall volume multiplied by the fee of $2.52 per barrel. For the three and nine months ended September 30, 2015 , PBF Holding paid PBFX fees of $6,355 and $19,113 , respectively, related to the Toledo Storage Facility Storage and Terminaling Agreement. For the three and nine months ended September 30, 2014 , PBF Holding paid PBFX no fees related to the Toledo Storage Facility Storage and Terminaling Agreement. Delaware City Pipeline Services Agreement PBF Holding entered into a pipeline services agreement with PBFX (the “Delaware City Pipeline Services Agreement”). Under the Delaware City Pipeline Services Agreement, PBFX provides PBF Holding with pipeline throughput services in return for throughput fees. The Delaware City Pipeline Services Agreement has an initial term of approximately ten years, under which PBFX provides pipeline services to PBF Holding on the Delaware Products Pipeline. The minimum throughput commitment for the pipeline facility is 50,000 bpd for a fee equal to $0.5266 per barrel of product throughputted up to the minimum throughput commitment and in excess of the minimum throughput commitment. If PBF Holding does not throughput the aggregate amounts equal to the minimum throughput commitment described above, PBF Holding will be required to pay a shortfall payment equal to the shortfall volume multiplied by the fee. Effective July 2015, the throughput fee was raised to $0.5507 per barrel, due to an increase in the Federal Energy Regulatory Commission ("FERC") tariff. For the three and nine months ended September 30, 2015 , PBF Holding paid PBFX fees of $2,533 and $3,795 , respectively, related to the Delaware City Pipeline Services Agreement. For the three and nine months ended September 30, 2014 , PBF Holding paid PBFX no fees related to the Delaware City Pipeline Services Agreement. Delaware City Truck Loading Agreement PBF Holding entered into a truck unloading agreement with PBFX (the “Delaware City Truck Loading Agreement”). Under the Delaware City Truck Loading Agreement, PBFX provides PBF Holding with truck loading services in return for fees. The Delaware City Truck Loading Agreement has an initial term of approximately ten years, under which PBFX provides loading services to PBF Holding at the Delaware City Terminal. The minimum throughput commitment for the truck rack is approximately 30,000 bpd for refined clean products with a fee equal to approximately $0.462 per barrel and approximately 5,000 bpd for LPGs with a fee equal to approximately $2.52 per barrel of product loaded up to the minimum throughput commitment and for volumes in excess of the minimum throughput commitment. For the three and nine months ended September 30, 2015 , PBF Holding paid PBFX fees of $2,442 and $3,720 , respectively, related to the Delaware City Truck Loading Agreement. For the three and nine months ended September 30, 2014 , PBF Holding paid PBFX no fees related to the Delaware City Truck Loading Agreement. Third Amended and Restated Omnibus Agreement PBF Holding entered into an omnibus agreement (as amended from time to time the "Omnibus Agreement") with PBFX, PBF GP, and PBF LLC 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. The Omnibus Agreement was amended on May 15, 2015 to include the Delaware City Products Pipeline and Truck Rack. Pursuant to the amended Omnibus Agreement, the annual administrative fee was increased to $2,350 per year from $2,225 per year. For the three and nine months ended September 30, 2015 , PBF Holding received fees from PBFX of $1,471 and $3,860 , respectively, related to the Omnibus Agreement. For the three and nine months ended September 30, 2014 , PBF Holding received fees from PBFX of $800 and $1,222 , respectively, related to the Omnibus Agreement. Third Amended and Restated Operation and Management Services and Secondment Agreement PBF Holding and certain of its subsidiaries entered into an operation and management services and secondment agreement (as amended from time to time the “Services Agreement”) with PBFX, pursuant to which PBF Holding and its subsidiaries provide PBFX with the personnel necessary for PBFX to perform its obligations under its 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. The operation and management services and secondment agreement was amended on May 15, 2015 to include the Delaware City Products Pipeline and Truck Rack. For the three and nine months ended September 30, 2015 , PBF Holding received fees from PBFX of $1,122 and $3,333 , respectively, related to the Services Agreement. For the three and nine months ended September 30, 2014 , PBF Holding received fees from PBFX of $125 and $191 , respectively, related to the Services Agreement.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES Environmental Matters The Company’s refineries 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, 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. In connection with the Paulsboro refinery acquisition, the Company assumed certain environmental remediation obligations. The environmental liability of $10,714 recorded as of September 30, 2015 ( $10,476 as of December 31, 2014 ) represents the present value of expected future costs discounted at a rate of 8.0% . The current portion of the environmental liability is recorded in Accrued expenses and the non-current portion is recorded in Other long-term liabilities. As of September 30, 2015 and December 31, 2014 , this liability is self-guaranteed by the Company. In connection with the acquisition of the Delaware City assets, Valero Energy Corporation ("Valero") remains responsible for certain pre-acquisition environmental obligations up to $20,000 and the predecessor to Valero in ownership of the refinery retains other historical obligations. In connection with the acquisition of the Delaware City assets and the Paulsboro refinery, the Company and Valero purchased ten year, $75,000 environmental insurance policies to insure against unknown environmental liabilities at each site. In connection with the Toledo refinery acquisition, Sunoco, Inc. (R&M) ("Sunoco") remains responsible for environmental remediation for conditions that existed on the closing date for twenty years from March 1, 2011, subject to certain limitations. In 2010, New York State adopted a Low-Sulfur Heating Oil mandate that, beginning July 1, 2012, requires all heating oil sold in New York State to contain no more than 15 parts per million ("PPM") sulfur. Since July 1, 2012, other states in the Northeast market began requiring heating oil sold in their state to contain no more than 15 PPM sulfur. Currently, six Northeastern states require heating oil with 15 PPM or less sulfur. By July 1, 2016, two more states are expected to adopt this requirement and by July 1, 2018 most of the remaining Northeastern states (except for Pennsylvania and New Hampshire) will require heating oil with 15 PPM or less sulfur. All of the heating oil the Company currently produces meets these specifications. The mandate and other requirements do not currently have a material impact on the Company's financial position, results of operations or cash flows. The EPA issued the final Tier 3 Gasoline standards on March 3, 2014 under the Clean Air Act. This final rule establishes more stringent vehicle emission standards and further reduces the sulfur content of gasoline starting in January of 2017. The new standard is set at 10 PPM sulfur in gasoline on an annual average basis starting January 1, 2017, with a credit trading program to provide compliance flexibility. The EPA responded to industry comments on the proposed rule and maintained the per gallon sulfur cap on gasoline at the existing 80 PPM cap. The standards set by the new rule are not expected to have a material impact on the Company’s financial position, results of operations or cash flows. The EPA was required to release the final annual standards for the Reformulated Fuels Standard ("RFS") for 2014 no later than Nov 29, 2013 and for 2015 no later than Nov 29, 2014. The EPA did not meet these requirements but did release proposed standards for 2014. The EPA did not finalize this proposal in 2014. However, in May 2015, the EPA re-proposed annual standards for RFS 2 for 2014, and proposed new standards for 2015 and 2016 and biomass-based diesel volumes for 2017. The EPA is proposing volume requirements in the annual standards which, while below the volumes originally set by Congress, would increase renewable fuel use in the U.S. above historical levels and provide for steady growth over time. The EPA is also proposing to increase the required volume of biomass-based diesel in 2015, 2016, and 2017 while maintaining the opportunity for growth in other advanced biofuels. The EPA has solicited comments on the proposed annual standards and held public hearings on June 25, 2015. Final action on this proposal is expected by November 30, 2015. If they are issued, the final standards may have a material impact on the Company's cost of compliance with RFS 2. On September 12, 2012, the EPA issued final amendments to the New Source Performance Standards ("NSPS") for petroleum refineries, including standards for emissions of nitrogen oxides from process heaters and work practice standards and monitoring requirements for flares. The Company has evaluated the impact of the regulation and amended standards on its refinery operations and currently does not expect the cost to comply to be material. In addition, the EPA published a Final Rule to the Clean Water Act ("CWA") 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 (BTA) as soon as possible, but state agencies have the discretion to establish implementation time lines. The Company continues to evaluate the impact of this regulation, and at this time does not anticipate it having a material impact on the Company’s financial position, results of operations or cash flows. The Delaware City Rail Terminal and DCR West Rack are collocated with the Delaware City refinery, and are located in Delaware's coastal zone where certain activities are regulated under the Delaware Coastal Zone act. On June 14, 2013, two administrative appeals were filed by the Sierra Club and Delaware Audubon (collectively the "Appellants") regarding an air permit Delaware City Refining obtained to allow loading of crude oil onto barges. The appeals allege that both the loading of crude oil onto barges and the operation of the Delaware City Rail Terminal violate Delaware’s Coastal Zone Act. The first appeal is Number 2013-1 before the State Coastal Zone Industrial Control Board (the “CZ Board”), and the second appeal is before the Environmental Appeals Board (the "EAB") and appeals Secretary’s Order No. 2013-A-0020. The CZ Board held a hearing on the first appeal on July 16, 2013, and ruled in favor of Delaware City Refining and the State of Delaware and dismissed the Appellants’ appeal for lack of standing. The Appellants appealed that decision to the Delaware Superior Court, New Castle County, Case No. N13A-09-001 ALR, and Delaware City Refining and the State of Delaware filed cross-appeals. A hearing on the second appeal before the EAB, case no. 2013-06, was held on January 13, 2014, and the EAB ruled in favor of Delaware City Refining and the State and dismissed the appeal for lack of jurisdiction. The Appellants also filed a Notice of Appeal with the Superior Court appealing the EAB’s decision. On March 31, 2015 the Superior Court affirmed the decisions by both the CZ Board and the EAB stating they both lacked jurisdiction to rule on the Appellants' appeal. The Appellants appealed to the Delaware Supreme Court, and, on November 5, 2015, the Delaware Supreme Court affirmed the Superior Court decision. The Company is also currently subject to certain other existing environmental claims and proceedings. The Company believes that there is only a remote possibility 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. PBF LLC Limited Liability Company Agreement The holders of limited liability company interests in PBF LLC, including PBF Energy, generally have to include for purposes of calculating their U.S. federal, state and local income taxes their share of any taxable income of PBF LLC, regardless of whether such holders receive cash distributions from PBF LLC. PBF Energy ultimately may not receive cash distributions from PBF LLC equal to its share of such taxable income or even equal to the actual tax due with respect to that income. For example, PBF LLC is required to include in taxable income PBF LLC’s allocable share of PBFX’s taxable income and gains (such share to be determined pursuant to the partnership agreement of PBFX), regardless of the amount of cash distributions received by PBF LLC from PBFX, and such taxable income and gains will flow-through to PBF Energy to the extent of its allocable share of the taxable income of PBF LLC. As a result, at certain times, the amount of cash otherwise ultimately available to PBF Energy on account of its indirect interest in PBFX may not be sufficient for PBF Energy to pay the amount of taxes it will owe on account of its indirect interests in PBFX. Taxable income of PBF LLC generally is allocated to the holders of PBF LLC units (including PBF Energy) pro-rata in accordance with their respective share of the net profits and net losses of PBF LLC. In general, PBF LLC is required to make periodic tax distributions to the members of PBF LLC, including PBF Energy, pro-rata in accordance with their respective percentage interests for such period (as determined under the amended and restated limited liability company agreement of PBF LLC), subject to available cash and applicable law and contractual restrictions (including pursuant to our debt instruments) and based on certain assumptions. Generally, these tax distributions are required to be in an amount equal to our estimate of the taxable income of PBF LLC for the year multiplied by an assumed tax rate equal to the highest effective marginal combined U.S. federal, state and local income tax rate prescribed for an individual or corporate resident in New York, New York (taking into account the nondeductibility of certain expenses). If, with respect to any given calendar year, the aggregate periodic tax distributions were less than the actual taxable income of PBF LLC multiplied by the assumed tax rate, PBF LLC is required to make a “true up” tax distribution, no later than March 15 of the following year, equal to such difference, subject to the available cash and borrowings of PBF LLC. PBF LLC obtains funding to pay its tax distributions by causing PBF Holding to distribute cash to PBF LLC and from distributions it receives from PBFX. 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 Unit holders (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's 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 the Company. 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 94.4% interest in PBF LLC as of September 30, 2015 ( 89.9% as of December 31, 2014). PBF LLC obtains funding to pay its tax distributions by causing PBF Holding to distribute cash to PBF LLC and from distributions it receives from PBFX.

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	9 Months Ended
	Sep. 30, 2015
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]
EMPLOYEE BENEFIT PLANS	EMPLOYEE BENEFIT PLANS The components of net periodic benefit cost related to the Company’s defined benefit plans consisted of the following: Three Months Ended Nine Months Ended Pension Benefits 2015 2014 2015 2014 Components of net periodic benefit cost: Service cost $ 5,790 $ 5,134 $ 17,369 $ 14,276 Interest cost 710 616 2,126 1,787 Expected return on plan assets (830 ) (546 ) (2,489 ) (1,609 ) Amortization of prior service costs 13 13 39 26 Amortization of loss 311 277 933 757 Net periodic benefit cost $ 5,994 $ 5,494 $ 17,978 $ 15,237 Three Months Ended Nine Months Ended Post Retirement Medical Plan 2015 2014 2015 2014 Components of net periodic benefit cost: Service cost $ 243 $ 269 $ 731 $ 747 Interest cost 134 125 403 353 Amortization of prior service costs 76 52 228 107 Amortization of loss (gain) — — — (4 ) Net periodic benefit cost $ 453 $ 446 $ 1,362 $ 1,203

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended
	Sep. 30, 2015
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 September 30, 2015 and December 31, 2014 . We have 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. We have 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. We have no derivative contracts that are subject to master netting arrangements that are reflected gross on the balance sheet. As of September 30, 2015 Fair Value Hierarchy Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Level 1 Level 2 Level 3 Assets: Money market funds $ 342,414 $ — $ — $ 342,414 N/A $ 342,414 Non-qualified pension plan assets 9,441 — — 9,441 N/A 9,441 Commodity contracts 148,907 10,710 838 160,455 (137,670 ) 22,785 Derivatives included with intermediation agreement obligations — 44,684 — 44,684 — 44,684 Derivatives included with inventory supply arrangement obligations — 1,031 — 1,031 — 1,031 Liabilities: Commodity contracts 134,702 1,945 1,023 137,670 (137,670 ) — Catalyst lease obligations — 27,577 — 27,577 — 27,577 As of December 31, 2014 Fair Value Hierarchy Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Level 1 Level 2 Level 3 Assets: Money market funds $ 5,575 $ — $ — $ 5,575 N/A $ 5,575 Non-qualified pension plan assets 5,494 — — 5,494 N/A 5,494 Commodity contracts 415,023 12,093 1,715 428,831 (397,676 ) 31,155 Derivatives included with inventory intermediation agreement obligations — 94,834 — 94,834 — 94,834 Derivatives included with inventory supply arrangement obligation — 4,251 — 4,251 — 4,251 Liabilities: Commodity contracts 390,144 7,338 194 397,676 (397,676 ) — Catalyst lease obligations — 36,559 — 36,559 — 36,559 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. • Non-qualified pension plan assets categorized in Level 1 of the fair value hierarchy are measured at fair value using a market approach based on published net asset values of mutual funds and included within Deferred charges and other assets, net. • 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 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 were derived using broker quotes, prices from other third party sources and other available market based data. • The derivatives included with inventory supply arrangement obligations, derivatives included with inventory intermediation agreement obligations and the catalyst lease 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. The table below summarizes the changes in fair value measurements categorized in Level 3 of the fair value hierarchy: Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Balance at beginning of period $ 1,905 $ 2,689 $ 1,521 $ (23,365 ) Purchases — — — — Settlements (1,238 ) (9,020 ) (12,549 ) (5,353 ) Unrealized gain included in earnings (852 ) 19,377 10,843 41,764 Transfers into Level 3 — — — — Transfers out of Level 3 — — — — Balance at end of period $ (185 ) $ 13,046 $ (185 ) $ 13,046 There were no transfers between levels during the three and nine months ended September 30, 2015 and 2014, respectively. Fair value of debt The table below summarizes the fair value and carrying value of debt as of September 30, 2015 and December 31, 2014. September 30, 2015 December 31, 2014 Carrying value Fair value Carrying value Fair value Senior Secured Notes (a) $ 669,354 $ 680,548 $ 668,520 $ 675,580 Revolving Loan (b) — — — — Rail Facility (b) 67,491 67,491 37,270 37,270 Catalyst leases (c) 27,577 27,577 36,559 36,559 764,422 775,616 742,349 749,409 Less - Current maturities — — — — Long-term debt $ 764,422 $ 775,616 $ 742,349 $ 749,409 (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 Senior Secured 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 leases 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 lease repurchase obligations as the Company's liability is directly impacted by the change in fair value of the underlying catalyst.

DERIVATIVES

DERIVATIVES	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVES	DERIVATIVES The Company uses derivative instruments to mitigate certain exposures to commodity price risk. The Company’s crude supply agreement contains purchase obligations for certain volumes of crude oil and other feedstocks. In addition, the Company entered into Inventory Intermediation Agreements commencing in July 2013 that contain purchase obligations for certain volumes of intermediates and refined products. The purchase obligations related to crude oil, feedstocks, 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 and refined products. The level of activity for these derivatives is based on the level of operating inventories. As of September 30, 2015 , there were 238,306 barrels of crude oil and feedstocks ( 662,579 barrels at December 31, 2014 ) outstanding under these derivative instruments designated as fair value hedges and no barrels ( no barrels at December 31, 2014 ) outstanding under these derivative instruments not designated as hedges. As of September 30, 2015 , there were 3,130,766 barrels of intermediates and refined products ( 3,106,325 barrels at December 31, 2014 ) outstanding under these derivative instruments designated as fair value hedges and no barrels ( no barrels at December 31, 2014 ) outstanding under these derivative instruments not designated as 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 September 30, 2015 , there were 45,651,000 barrels of crude oil and 2,277,000 barrels of refined products ( 47,339,000 and 1,970,871 , respectively, as of December 31, 2014 ), outstanding under short and long term commodity derivative contracts not designated as hedges representing the notional value of the contracts. The following tables provide information about the fair values of these derivative instruments as of September 30, 2015 and December 31, 2014 and the line items in the consolidated balance sheet in which the fair values are reflected. Description Balance Sheet Location Fair Value Asset/(Liability) Derivatives designated as hedging instruments: September 30, 2015: Derivatives included with inventory supply arrangement obligations Accrued expenses $ 1,031 Derivatives included with the intermediation agreement obligations Accrued expenses $ 44,684 December 31, 2014: Derivatives included with inventory supply arrangement obligations Accrued expenses $ 4,251 Derivatives included with the intermediation agreement obligations Accrued expenses $ 94,834 Derivatives not designated as hedging instruments: September 30, 2015: Commodity contracts Accounts receivable $ 22,785 December 31, 2014: Commodity contracts Accounts receivable $ 31,155 The following tables provide information about the gain or loss recognized in income on these derivative instruments and the line items in the consolidated financial statements in which such gains and losses are reflected. Description Location of Gain or (Loss) Recognized in Income on Derivatives Gain or (Loss) Recognized in Income on Derivatives Derivatives designated as hedging instruments: For the three months ended September 30, 2015: Derivatives included with inventory supply arrangement obligations Cost of sales $ 1,409 Derivatives included with the intermediation agreement obligations Cost of sales $ 34,424 For the three months ended September 30, 2014: Derivatives included with inventory supply arrangement obligations Cost of sales $ 2,729 Derivatives included with the intermediation agreement obligations Cost of sales $ 20,900 For the nine months ended September 30, 2015: Derivatives included with inventory supply arrangement obligations Cost of sales $ (3,220 ) Derivatives included with the intermediation agreement obligations Cost of sales $ (50,150 ) For the nine months ended September 30, 2014: Derivatives included with inventory supply arrangement obligations Cost of sales $ 1,660 Derivatives included with the intermediation agreement obligations Cost of sales $ 29,942 Derivatives not designated as hedging instruments: For the three months ended September 30, 2015: Commodity contracts Cost of sales $ 31,017 For the three months ended September 30, 2014: Commodity contracts Cost of sales $ 70,624 For the nine months ended September 30, 2015: Commodity contracts Cost of sales $ (14,080 ) For the nine months ended September 30, 2014: Commodity contracts Cost of sales $ 101,902 Hedged items designated in fair value hedges: For the three months ended September 30, 2015: Crude oil and feedstock inventory Cost of sales $ (1,409 ) Intermediate and refined product inventory Cost of sales $ (34,424 ) For the three months ended September 30, 2014: Crude oil and feedstock inventory Cost of sales $ (2,729 ) Intermediate and refined product inventory Cost of sales $ (20,900 ) For the nine months ended September 30, 2015: Crude oil and feedstock inventory Cost of sales $ 3,220 Intermediate and refined product inventory Cost of sales $ 50,150 For the nine months ended September 30, 2014: Crude oil and feedstock inventory Cost of sales $ (1,660 ) Intermediate and refined product inventory Cost of sales $ (29,942 ) The Company had no ineffectiveness related to the Company's fair value hedges for the three and nine months ended September 30, 2015 and 2014 .

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	9 Months Ended
	Sep. 30, 2015
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS Distributions On October 29, 2015, PBF Energy, PBF Holding's indirect parent, declared a dividend of $0.30 per share on its outstanding Class A common stock. The dividend is payable on November 24, 2015 to PBF Energy Class A common stockholders of record at the close of business on November 9, 2015. PBF Holding intends to make a distribution of approximately $30,752 to PBF LLC, which in turn will make pro-rata distributions to its members, including PBF Energy. PBF Energy will then use this distribution to fund the dividend payments to the shareholders of PBF Energy. Chalmette Acquisition On November 1, 2015, the Company acquired from ExxonMobil Oil Corporation, Mobil Pipe Line Company and PDV Chalmette, L.L.C. (collectively, the "Chalmette Sellers"), the ownership interests of Chalmette Refining, L.L.C. (“Chalmette Refining”), which owns the Chalmette refinery and related logistics assets (collectively, the "Chalmette Acquisition"). The Chalmette refinery, located outside of New Orleans, Louisiana, is a dual-train coking refinery and is capable of processing both light and heavy crude oil. Subsequent to the closing of the Chalmette Acquisition, Chalmette Refining is a wholly-owned subsidiary of PBF Holding. Chalmette Refining owns 100% of the MOEM Pipeline, providing access to the Empire Terminal, as well as the CAM Connection Pipeline, providing access to the Louisiana Offshore Oil Port facility through a third party pipeline. Chalmette Refining also owns 80% of each of the Collins Pipeline Company and T&M Terminal Company, both located in Collins, Mississippi, which provide a clean products outlet for the refinery to the Plantation and Colonial Pipelines. Also included in the acquisition are a marine terminal capable of importing waterborne feedstocks and loading or unloading finished products; a clean products truck rack which provides access to local markets; and a crude and product storage facility. The aggregate purchase price for the Chalmette Acquisition was $322,000 in cash, plus estimated inventory and working capital of $233,083 , which is subject to final valuation within ninety days of closing. The transaction was financed through a combination of cash on hand and borrowings under the Company’s existing revolving credit line. A determination of the acquisition-date fair values of the assets acquired and the liabilities assumed and the working capital at closing calculation is pending the completion of an independent appraisal and other evaluations. The Chalmette Acquisition provides the Company with a broader more diversified asset base and increases the number of operating refineries from three to four and the Company's combined crude oil throughput capacity. The acquisition also provides the Company with a presence in the attractive Petroleum Administration for Defense Districts ("PADD") 3 market. October 2015 Equity Offering On October 13, 2015, PBF Energy, PBF Holding's indirect parent, completed a public offering of an aggregate of 11,500,000 shares of PBF Energy Class A common stock, including 1,500,000 shares of PBF Energy Class A common stock that was sold pursuant to the exercise of an over-allotment option, for net proceeds of $344,000 , after deducting underwriting discounts and commissions and other offering expenses (the "October 2015 Equity Offering"). In connection with the October 2015 Equity Offering, $345,000 was contributed to PBF LLC, PBF Holding's parent, which in turn contributed such proceeds to PBF Holding.

CONDENSED CONSOLIDATING FINANCI

CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS	9 Months Ended
	Sep. 30, 2015
Condensed Financial Information of Subsidiary Disclosure [Abstract]
CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS	CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING PBF Services Company, Delaware City Refining, PBF Power Marketing LLC, Paulsboro Refining Company LLC, Paulsboro Natural Gas Pipeline Company LLC and Toledo Refining Company LLC are 100% owned subsidiaries of PBF Holding and serve as guarantors of the obligations under the Senior Secured Notes. These guarantees are full and unconditional and joint and several. For purposes of the following footnote, PBF Holding is referred to as “Issuer.” The indenture dated February 9, 2012, among PBF Holding, PBF Finance, the guarantors party thereto and Wilmington Trust, National Association, governs subsidiaries designated as “Guarantor Subsidiaries.” PBF Rail Logistics Company LLC, PBF Transportation Company LLC and PBF Energy Limited are consolidated subsidiaries of the Company that are not guarantors of the Senior Secured Notes. The Senior Secured Notes were co-issued by PBF Finance. For purposes of the following footnote, PBF Finance is referred to as “Co-Issuer.” The Co-Issuer has no independent assets or operations. The following supplemental combining and condensed consolidating financial information reflects the Issuer’s separate accounts, the combined accounts of the Guarantor Subsidiaries and Non-Guarantor Subsidiaries, the combining and consolidating adjustments and eliminations and the Issuer’s consolidated accounts for the dates and periods indicated. For purposes of the following combining and consolidating information, the Issuer’s Investment in its subsidiaries is accounted for under the equity method of accounting. . CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) September 30, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 361,037 $ 3 $ 10,231 $ (1,850 ) $ 369,421 Accounts receivable 369,071 18,649 7,904 — 395,624 Accounts receivable - affiliate 802 2,497 — — 3,299 Inventories 547,225 376,182 177,775 — 1,101,182 Prepaid expense and other current assets 44,940 10,212 — — 55,152 Due from related parties 19,279,650 20,178,357 2,867,690 (42,325,697 ) — Total current assets 20,602,725 20,585,900 3,063,600 (42,327,547 ) 1,924,678 Property, plant and equipment, net 21,630 1,692,834 100,043 — 1,814,507 Investment in subsidiaries 1,757,810 — — (1,757,810 ) — Deferred charges and other assets, net 33,906 265,963 2,062 — 301,931 Total assets $ 22,416,071 $ 22,544,697 $ 3,165,705 $ (44,085,357 ) $ 4,041,116 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 121,933 $ 92,332 $ 19 $ (1,850 ) $ 212,434 Accounts payable - affiliate 24,272 — — — 24,272 Accrued expenses 536,121 430,464 82,652 — 1,049,237 Deferred revenue 4,174 — — — 4,174 Due to related parties 19,118,950 20,342,238 2,864,509 (42,325,697 ) — Total current liabilities 19,805,450 20,865,034 2,947,180 (42,327,547 ) 1,290,117 Delaware Economic Development Authority loan — 8,000 — — 8,000 Long-term debt 669,354 27,577 67,491 — 764,422 Intercompany notes payable 152,037 — — — 152,037 Other long-term liabilities 25,771 37,310 — — 63,081 Total liabilities 20,652,612 20,937,921 3,014,671 (42,327,547 ) 2,277,657 Commitments and contingencies Equity: Member's equity 1,131,992 736,016 39,346 (775,362 ) 1,131,992 Retained earnings (accumulated deficit) 657,028 879,148 111,688 (990,836 ) 657,028 Accumulated other comprehensive (loss) income (25,561 ) (8,388 ) — 8,388 (25,561 ) Total equity 1,763,459 1,606,776 151,034 (1,757,810 ) 1,763,459 Total liabilities and equity $ 22,416,071 $ 22,544,697 $ 3,165,705 $ (44,085,357 ) $ 4,041,116 13. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) December 31, 2014 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 185,381 $ 704 $ 34,334 $ (2,016 ) $ 218,403 Accounts receivable 518,498 26,238 6,533 — 551,269 Accounts receivable - affiliate 529 2,694 — — 3,223 Inventories 510,947 435,924 155,390 — 1,102,261 Prepaid expense and other current assets 26,964 5,193 — — 32,157 Due from related parties 16,189,384 18,805,509 1,607,878 (36,602,771 ) — Total current assets 17,431,703 19,276,262 1,804,135 (36,604,787 ) 1,907,313 Property, plant and equipment, net 68,218 1,683,294 54,548 — 1,806,060 Investment in subsidiaries 2,569,636 — — (2,569,636 ) — Deferred charges and other assets, net 34,840 293,098 2,579 — 330,517 Total assets $ 20,104,397 $ 21,252,654 $ 1,861,262 $ (39,174,423 ) $ 4,043,890 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 235,791 $ 92,984 $ 8,423 $ (2,016 ) $ 335,182 Accounts Payable - affiliate 11,600 30 — — 11,630 Accrued expenses 487,783 450,856 191,331 — 1,129,970 Deferred revenue 1,227 — — — 1,227 Due to related parties 16,924,490 18,151,095 1,527,186 (36,602,771 ) — Total current liabilities 17,660,891 18,694,965 1,726,940 (36,604,787 ) 1,478,009 Delaware Economic Development Authority loan — 8,000 — — 8,000 Long-term debt 668,520 36,559 37,270 — 742,349 Intercompany notes payable 122,264 — — — 122,264 Other long-term liabilities 22,206 40,546 — — 62,752 Total liabilities 18,473,881 18,780,070 1,764,210 (36,604,787 ) 2,413,374 Commitments and contingencies Equity: Member's equity 1,144,100 749,278 44,346 (793,624 ) 1,144,100 Retained earnings (accumulated deficit) 513,292 1,731,694 52,706 (1,784,400 ) 513,292 Accumulated other comprehensive (loss) income (26,876 ) (8,388 ) — 8,388 (26,876 ) Total equity 1,630,516 2,472,584 97,052 (2,569,636 ) 1,630,516 Total liabilities and equity $ 20,104,397 $ 21,252,654 $ 1,861,262 $ (39,174,423 ) $ 4,043,890 13. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF CASH FLOW (UNAUDITED) Nine Months Ended September 30, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 411,803 $ (852,587 ) $ 58,981 $ 793,606 $ 411,803 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 13,085 130,513 2,377 — 145,975 Stock-based compensation — 6,329 — — 6,329 Change in fair value of catalyst lease obligations — (8,982 ) — — (8,982 ) Change in non-cash lower of cost or market inventory adjustment (2,091 ) 83,238 — — 81,147 Non-cash change in inventory repurchase obligations — 53,370 — — 53,370 Pension and other post retirement benefit costs 5,769 13,571 — — 19,340 Gain on disposition of property, plant and equipment (251 ) (232 ) (650 ) — (1,133 ) Equity in earnings of subsidiaries 793,606 — — (793,606 ) — Changes in current assets and current liabilities: Accounts receivable 149,427 7,589 (1,371 ) — 155,645 Due to/from affiliates (729,595 ) 818,461 (76,300 ) — 12,566 Inventories (34,187 ) (54,258 ) (22,385 ) — (110,830 ) Prepaid expenses and other current assets (17,976 ) (5,019 ) — — (22,995 ) Accounts payable (113,856 ) (654 ) (8,404 ) 166 (122,748 ) Accrued expenses (206,906 ) (27,197 ) (108,678 ) — (342,781 ) Deferred revenue 2,947 — — — 2,947 Other assets and liabilities (3,430 ) (18,276 ) (178 ) — (21,884 ) Net cash provided by (used in) operating activities 268,345 145,866 (156,608 ) 166 257,769 Cash flows from investing activities: Expenditures for property, plant and equipment (188,364 ) (99,567 ) — — (287,931 ) Expenditures for deferred turnaround costs — (39,725 ) — — (39,725 ) Expenditures for other assets — (7,275 ) — — (7,275 ) Investment in subsidiaries 5,000 — — (5,000 ) — Proceeds from sale of assets 60,902 — 107,368 — 168,270 Net cash (used in) provided by investing activities (122,462 ) (146,567 ) 107,368 (5,000 ) (166,661 ) Cash flows from financing activities: Proceeds from members' capital contributions — — 5,000 (5,000 ) — Distribution to Parent — — (10,000 ) 10,000 — Proceeds from intercompany notes payable 29,773 — — — 29,773 Proceeds from Rail Facility revolver borrowings — — 102,075 — 102,075 Repayments of Rail Facility revolver borrowings — — (71,938 ) — (71,938 ) Net cash provided by financing activities 29,773 — 25,137 5,000 59,910 Net increase (decrease) in cash and cash equivalents 175,656 (701 ) (24,103 ) 166 151,018 Cash and equivalents, beginning of period 185,381 704 34,334 (2,016 ) 218,403 Cash and equivalents, end of period $ 361,037 $ 3 $ 10,231 $ (1,850 ) $ 369,421 13. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF CASH FLOW (UNAUDITED) Nine Months Ended September 30, 2014 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 538,783 $ (818,711 ) $ 7,287 $ 811,424 $ 538,783 Adjustments to reconcile net income to net cash from operating activities: Depreciation and amortization 15,123 125,053 687 — 140,863 Stock-based compensation — 4,725 — — 4,725 Change in fair value of catalyst lease obligations — (1,204 ) — — (1,204 ) Non-cash change in inventory repurchase obligations — (31,602 ) — — (31,602 ) Pension and other post retirement benefit costs 4,607 11,855 — — 16,462 (Gain) loss on disposition of property, plant and equipment (186 ) 24 — — (162 ) Equity in earnings of subsidiaries 811,424 — — (811,424 ) — Changes in current assets and current liabilities: Accounts receivable (69,105 ) (776 ) (31,871 ) — (101,752 ) Due to/from affiliates (890,671 ) 947,290 (52,621 ) — 3,998 Inventories (322,231 ) 24,320 (80,627 ) — (378,538 ) Prepaid expenses and other current assets 25,583 29 — — 25,612 Accounts payable (76,856 ) (20,905 ) 24,171 (2,418 ) (76,008 ) Accrued expenses 133,070 (2,376 ) 137,955 — 268,649 Deferred revenue (6,017 ) — — — (6,017 ) Other assets and liabilities (1,851 ) (13,889 ) — — (15,740 ) Net cash provided by (used in) operating activities 161,673 223,833 4,981 (2,418 ) 388,069 Cash flows from investing activities: Expenditures for property, plant and equipment (44,993 ) (152,755 ) (55,706 ) — (253,454 ) Expenditures for refinery turnarounds costs — (58,423 ) — — (58,423 ) Expenditures for other assets — (13,446 ) — — (13,446 ) Investment in subsidiaries (22,990 ) — — 22,990 — Proceeds from sale of assets 74,343 — — — 74,343 Net cash provided by (used in) investing activities 6,360 (224,624 ) (55,706 ) 22,990 (250,980 ) Cash flows from financing activities: Proceeds from members' capital contributions 328,664 — 22,990 (22,990 ) 328,664 Distributions to members (283,680 ) — — — (283,680 ) Proceeds from intercompany notes payable 90,761 — — — 90,761 Proceeds from Rail Facility revolver borrowings — — 35,925 — 35,925 Proceeds from revolver borrowings 395,000 — — — 395,000 Repayments of revolver borrowings (410,000 ) — — — (410,000 ) Deferred financing costs and other (7,164 ) — (3,218 ) — (10,382 ) Net cash provided by (used in) financing activities 113,581 — 55,697 (22,990 ) 146,288 Net increase (decrease) in cash and cash equivalents 281,614 (791 ) 4,972 (2,418 ) 283,377 Cash and equivalents, beginning of period 76,179 791 — — 76,970 Cash and equivalents, end of period $ 357,793 $ — $ 4,972 $ (2,418 ) $ 360,347

DESCRIPTION OF THE BUSINESS A19

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION (Policies)	9 Months Ended
	Sep. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
New Accounting Pronouncements	Recent Accounting Pronouncements In April 2015, the FASB issued ASU No. 2015-03, "Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs" ("ASU 2015-03"), which requires debt issuance costs related to a recognized debt liability to be presented on the balance sheet as a direct deduction from the debt liability rather than as an asset. The standard is effective for interim and annual periods beginning after December 15, 2015 and early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In August 2015, the FASB issued ASU No. 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date” (“ASU 2015-14”), which defers the effective date of ASU 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”) for all entities by one year. The guidance in ASU 2014-09 will replace most existing revenue recognition guidance in GAAP when it becomes effective. Under ASU 2015-14, this guidance becomes effective for interim and annual periods beginning after December 15, 2017 and permits the use of either the retrospective or cumulative effect transition method. Under ASU 2015-14, early adoption is permitted only as of annual reporting periods beginning after December 15, 2016, including interim reporting periods within that reporting period. The Company continues to evaluate the impact of this new standard on its consolidated financial statements and related disclosures. In September 2015, the FASB issued ASU No. 2015-16, "Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments" ("ASU 2015-16"), which requires (i) that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined, (ii) that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date, (iii)that an entity present separately on the face of the income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. Under ASU 2015-16, this guidance becomes effective for annual periods beginning after December 15, 2016 and interim periods within annual periods beginning after December 15, 2017 with prospective application with early adoption permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.

INVENTORIES (Tables)

INVENTORIES (Tables)	9 Months Ended
	Sep. 30, 2015
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventories consisted of the following: September 30, 2015 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 954,744 $ 21,288 $ 976,032 Refined products and blendstocks 545,279 310,238 855,517 Warehouse stock and other 40,890 — 40,890 $ 1,540,913 $ 331,526 $ 1,872,439 Lower of cost or market reserve (662,638 ) (108,619 ) (771,257 ) Total inventories $ 878,275 $ 222,907 $ 1,101,182 December 31, 2014 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 918,756 $ 61,122 $ 979,878 Refined products and blendstocks 520,308 255,459 775,767 Warehouse stock and other 36,726 — 36,726 $ 1,475,790 $ 316,581 $ 1,792,371 Lower of cost or market reserve (609,774 ) (80,336 ) (690,110 ) Total inventories $ 866,016 $ 236,245 $ 1,102,261

DEFERRED CHARGES AND OTHER AS21

DEFERRED CHARGES AND OTHER ASSETS, NET (Tables)	9 Months Ended
	Sep. 30, 2015
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: September 30, December 31, Deferred turnaround costs, net $ 183,618 $ 204,987 Catalyst, net 71,516 77,322 Deferred financing costs, net 25,006 30,128 Linefill 10,230 10,230 Restricted cash 1,500 1,521 Intangible assets, net 231 357 Other 9,830 5,972 Total deferred charges and other assets, net $ 301,931 $ 330,517

ACCRUED EXPENSES (Tables)

ACCRUED EXPENSES (Tables)	9 Months Ended
	Sep. 30, 2015
Payables and Accruals [Abstract]
Schedule of accrued expenses	Accrued expenses consisted of the following: September 30, December 31, Inventory-related accruals $ 407,678 $ 588,297 Accrued distributions 268,066 — Inventory supply and intermediation arrangements 212,930 253,549 Accrued transportation costs 49,548 59,959 Accrued salaries and benefits 37,766 55,993 Excise and sales tax payable 20,430 40,444 Accrued utilities 9,633 22,337 Customer deposits 8,910 24,659 Accrued interest 6,601 22,946 Accrued construction in progress 4,634 31,452 Other 23,041 30,334 Total accrued expenses $ 1,049,237 $ 1,129,970

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	9 Months Ended
	Sep. 30, 2015
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]
Schedule of net periodic benefit cost	The components of net periodic benefit cost related to the Company’s defined benefit plans consisted of the following: Three Months Ended Nine Months Ended Pension Benefits 2015 2014 2015 2014 Components of net periodic benefit cost: Service cost $ 5,790 $ 5,134 $ 17,369 $ 14,276 Interest cost 710 616 2,126 1,787 Expected return on plan assets (830 ) (546 ) (2,489 ) (1,609 ) Amortization of prior service costs 13 13 39 26 Amortization of loss 311 277 933 757 Net periodic benefit cost $ 5,994 $ 5,494 $ 17,978 $ 15,237 Three Months Ended Nine Months Ended Post Retirement Medical Plan 2015 2014 2015 2014 Components of net periodic benefit cost: Service cost $ 243 $ 269 $ 731 $ 747 Interest cost 134 125 403 353 Amortization of prior service costs 76 52 228 107 Amortization of loss (gain) — — — (4 ) Net periodic benefit cost $ 453 $ 446 $ 1,362 $ 1,203

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Sep. 30, 2015
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 September 30, 2015 and December 31, 2014 . We have 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. We have 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. We have no derivative contracts that are subject to master netting arrangements that are reflected gross on the balance sheet. As of September 30, 2015 Fair Value Hierarchy Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Level 1 Level 2 Level 3 Assets: Money market funds $ 342,414 $ — $ — $ 342,414 N/A $ 342,414 Non-qualified pension plan assets 9,441 — — 9,441 N/A 9,441 Commodity contracts 148,907 10,710 838 160,455 (137,670 ) 22,785 Derivatives included with intermediation agreement obligations — 44,684 — 44,684 — 44,684 Derivatives included with inventory supply arrangement obligations — 1,031 — 1,031 — 1,031 Liabilities: Commodity contracts 134,702 1,945 1,023 137,670 (137,670 ) — Catalyst lease obligations — 27,577 — 27,577 — 27,577 As of December 31, 2014 Fair Value Hierarchy Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Level 1 Level 2 Level 3 Assets: Money market funds $ 5,575 $ — $ — $ 5,575 N/A $ 5,575 Non-qualified pension plan assets 5,494 — — 5,494 N/A 5,494 Commodity contracts 415,023 12,093 1,715 428,831 (397,676 ) 31,155 Derivatives included with inventory intermediation agreement obligations — 94,834 — 94,834 — 94,834 Derivatives included with inventory supply arrangement obligation — 4,251 — 4,251 — 4,251 Liabilities: Commodity contracts 390,144 7,338 194 397,676 (397,676 ) — Catalyst lease obligations — 36,559 — 36,559 — 36,559
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: Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Balance at beginning of period $ 1,905 $ 2,689 $ 1,521 $ (23,365 ) Purchases — — — — Settlements (1,238 ) (9,020 ) (12,549 ) (5,353 ) Unrealized gain included in earnings (852 ) 19,377 10,843 41,764 Transfers into Level 3 — — — — Transfers out of Level 3 — — — — Balance at end of period $ (185 ) $ 13,046 $ (185 ) $ 13,046
Schedule of Fair value of Debt	The table below summarizes the fair value and carrying value of debt as of September 30, 2015 and December 31, 2014. September 30, 2015 December 31, 2014 Carrying value Fair value Carrying value Fair value Senior Secured Notes (a) $ 669,354 $ 680,548 $ 668,520 $ 675,580 Revolving Loan (b) — — — — Rail Facility (b) 67,491 67,491 37,270 37,270 Catalyst leases (c) 27,577 27,577 36,559 36,559 764,422 775,616 742,349 749,409 Less - Current maturities — — — — Long-term debt $ 764,422 $ 775,616 $ 742,349 $ 749,409 (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 Senior Secured 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 leases 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 lease repurchase obligations as the Company's liability is directly impacted by the change in fair value of the underlying catalyst.

DERIVATIVES (Tables)

DERIVATIVES (Tables)	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Fair Value of Derivative Instruments	The following tables provide information about the fair values of these derivative instruments as of September 30, 2015 and December 31, 2014 and the line items in the consolidated balance sheet in which the fair values are reflected. Description Balance Sheet Location Fair Value Asset/(Liability) Derivatives designated as hedging instruments: September 30, 2015: Derivatives included with inventory supply arrangement obligations Accrued expenses $ 1,031 Derivatives included with the intermediation agreement obligations Accrued expenses $ 44,684 December 31, 2014: Derivatives included with inventory supply arrangement obligations Accrued expenses $ 4,251 Derivatives included with the intermediation agreement obligations Accrued expenses $ 94,834 Derivatives not designated as hedging instruments: September 30, 2015: Commodity contracts Accounts receivable $ 22,785 December 31, 2014: Commodity contracts Accounts receivable $ 31,155
Schedule of Derivative Instruments, Gain (Loss) Recognized in Income	The following tables provide information about the gain or loss recognized in income on these derivative instruments and the line items in the consolidated financial statements in which such gains and losses are reflected. Description Location of Gain or (Loss) Recognized in Income on Derivatives Gain or (Loss) Recognized in Income on Derivatives Derivatives designated as hedging instruments: For the three months ended September 30, 2015: Derivatives included with inventory supply arrangement obligations Cost of sales $ 1,409 Derivatives included with the intermediation agreement obligations Cost of sales $ 34,424 For the three months ended September 30, 2014: Derivatives included with inventory supply arrangement obligations Cost of sales $ 2,729 Derivatives included with the intermediation agreement obligations Cost of sales $ 20,900 For the nine months ended September 30, 2015: Derivatives included with inventory supply arrangement obligations Cost of sales $ (3,220 ) Derivatives included with the intermediation agreement obligations Cost of sales $ (50,150 ) For the nine months ended September 30, 2014: Derivatives included with inventory supply arrangement obligations Cost of sales $ 1,660 Derivatives included with the intermediation agreement obligations Cost of sales $ 29,942 Derivatives not designated as hedging instruments: For the three months ended September 30, 2015: Commodity contracts Cost of sales $ 31,017 For the three months ended September 30, 2014: Commodity contracts Cost of sales $ 70,624 For the nine months ended September 30, 2015: Commodity contracts Cost of sales $ (14,080 ) For the nine months ended September 30, 2014: Commodity contracts Cost of sales $ 101,902 Hedged items designated in fair value hedges: For the three months ended September 30, 2015: Crude oil and feedstock inventory Cost of sales $ (1,409 ) Intermediate and refined product inventory Cost of sales $ (34,424 ) For the three months ended September 30, 2014: Crude oil and feedstock inventory Cost of sales $ (2,729 ) Intermediate and refined product inventory Cost of sales $ (20,900 ) For the nine months ended September 30, 2015: Crude oil and feedstock inventory Cost of sales $ 3,220 Intermediate and refined product inventory Cost of sales $ 50,150 For the nine months ended September 30, 2014: Crude oil and feedstock inventory Cost of sales $ (1,660 ) Intermediate and refined product inventory Cost of sales $ (29,942 )

CONDENSED CONSOLIDATING FINAN26

CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Tables)	9 Months Ended
	Sep. 30, 2015
Condensed Financial Information of Subsidiary Disclosure [Abstract]
Condensed Consolidating Balance Sheet	CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) September 30, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 361,037 $ 3 $ 10,231 $ (1,850 ) $ 369,421 Accounts receivable 369,071 18,649 7,904 — 395,624 Accounts receivable - affiliate 802 2,497 — — 3,299 Inventories 547,225 376,182 177,775 — 1,101,182 Prepaid expense and other current assets 44,940 10,212 — — 55,152 Due from related parties 19,279,650 20,178,357 2,867,690 (42,325,697 ) — Total current assets 20,602,725 20,585,900 3,063,600 (42,327,547 ) 1,924,678 Property, plant and equipment, net 21,630 1,692,834 100,043 — 1,814,507 Investment in subsidiaries 1,757,810 — — (1,757,810 ) — Deferred charges and other assets, net 33,906 265,963 2,062 — 301,931 Total assets $ 22,416,071 $ 22,544,697 $ 3,165,705 $ (44,085,357 ) $ 4,041,116 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 121,933 $ 92,332 $ 19 $ (1,850 ) $ 212,434 Accounts payable - affiliate 24,272 — — — 24,272 Accrued expenses 536,121 430,464 82,652 — 1,049,237 Deferred revenue 4,174 — — — 4,174 Due to related parties 19,118,950 20,342,238 2,864,509 (42,325,697 ) — Total current liabilities 19,805,450 20,865,034 2,947,180 (42,327,547 ) 1,290,117 Delaware Economic Development Authority loan — 8,000 — — 8,000 Long-term debt 669,354 27,577 67,491 — 764,422 Intercompany notes payable 152,037 — — — 152,037 Other long-term liabilities 25,771 37,310 — — 63,081 Total liabilities 20,652,612 20,937,921 3,014,671 (42,327,547 ) 2,277,657 Commitments and contingencies Equity: Member's equity 1,131,992 736,016 39,346 (775,362 ) 1,131,992 Retained earnings (accumulated deficit) 657,028 879,148 111,688 (990,836 ) 657,028 Accumulated other comprehensive (loss) income (25,561 ) (8,388 ) — 8,388 (25,561 ) Total equity 1,763,459 1,606,776 151,034 (1,757,810 ) 1,763,459 Total liabilities and equity $ 22,416,071 $ 22,544,697 $ 3,165,705 $ (44,085,357 ) $ 4,041,116 13. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) December 31, 2014 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 185,381 $ 704 $ 34,334 $ (2,016 ) $ 218,403 Accounts receivable 518,498 26,238 6,533 — 551,269 Accounts receivable - affiliate 529 2,694 — — 3,223 Inventories 510,947 435,924 155,390 — 1,102,261 Prepaid expense and other current assets 26,964 5,193 — — 32,157 Due from related parties 16,189,384 18,805,509 1,607,878 (36,602,771 ) — Total current assets 17,431,703 19,276,262 1,804,135 (36,604,787 ) 1,907,313 Property, plant and equipment, net 68,218 1,683,294 54,548 — 1,806,060 Investment in subsidiaries 2,569,636 — — (2,569,636 ) — Deferred charges and other assets, net 34,840 293,098 2,579 — 330,517 Total assets $ 20,104,397 $ 21,252,654 $ 1,861,262 $ (39,174,423 ) $ 4,043,890 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 235,791 $ 92,984 $ 8,423 $ (2,016 ) $ 335,182 Accounts Payable - affiliate 11,600 30 — — 11,630 Accrued expenses 487,783 450,856 191,331 — 1,129,970 Deferred revenue 1,227 — — — 1,227 Due to related parties 16,924,490 18,151,095 1,527,186 (36,602,771 ) — Total current liabilities 17,660,891 18,694,965 1,726,940 (36,604,787 ) 1,478,009 Delaware Economic Development Authority loan — 8,000 — — 8,000 Long-term debt 668,520 36,559 37,270 — 742,349 Intercompany notes payable 122,264 — — — 122,264 Other long-term liabilities 22,206 40,546 — — 62,752 Total liabilities 18,473,881 18,780,070 1,764,210 (36,604,787 ) 2,413,374 Commitments and contingencies Equity: Member's equity 1,144,100 749,278 44,346 (793,624 ) 1,144,100 Retained earnings (accumulated deficit) 513,292 1,731,694 52,706 (1,784,400 ) 513,292 Accumulated other comprehensive (loss) income (26,876 ) (8,388 ) — 8,388 (26,876 ) Total equity 1,630,516 2,472,584 97,052 (2,569,636 ) 1,630,516 Total liabilities and equity $ 20,104,397 $ 21,252,654 $ 1,861,262 $ (39,174,423 ) $ 4,043,890
Condensed Consolidating Statement of Cash Flow	CONDENSED CONSOLIDATING STATEMENT OF CASH FLOW (UNAUDITED) Nine Months Ended September 30, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 411,803 $ (852,587 ) $ 58,981 $ 793,606 $ 411,803 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 13,085 130,513 2,377 — 145,975 Stock-based compensation — 6,329 — — 6,329 Change in fair value of catalyst lease obligations — (8,982 ) — — (8,982 ) Change in non-cash lower of cost or market inventory adjustment (2,091 ) 83,238 — — 81,147 Non-cash change in inventory repurchase obligations — 53,370 — — 53,370 Pension and other post retirement benefit costs 5,769 13,571 — — 19,340 Gain on disposition of property, plant and equipment (251 ) (232 ) (650 ) — (1,133 ) Equity in earnings of subsidiaries 793,606 — — (793,606 ) — Changes in current assets and current liabilities: Accounts receivable 149,427 7,589 (1,371 ) — 155,645 Due to/from affiliates (729,595 ) 818,461 (76,300 ) — 12,566 Inventories (34,187 ) (54,258 ) (22,385 ) — (110,830 ) Prepaid expenses and other current assets (17,976 ) (5,019 ) — — (22,995 ) Accounts payable (113,856 ) (654 ) (8,404 ) 166 (122,748 ) Accrued expenses (206,906 ) (27,197 ) (108,678 ) — (342,781 ) Deferred revenue 2,947 — — — 2,947 Other assets and liabilities (3,430 ) (18,276 ) (178 ) — (21,884 ) Net cash provided by (used in) operating activities 268,345 145,866 (156,608 ) 166 257,769 Cash flows from investing activities: Expenditures for property, plant and equipment (188,364 ) (99,567 ) — — (287,931 ) Expenditures for deferred turnaround costs — (39,725 ) — — (39,725 ) Expenditures for other assets — (7,275 ) — — (7,275 ) Investment in subsidiaries 5,000 — — (5,000 ) — Proceeds from sale of assets 60,902 — 107,368 — 168,270 Net cash (used in) provided by investing activities (122,462 ) (146,567 ) 107,368 (5,000 ) (166,661 ) Cash flows from financing activities: Proceeds from members' capital contributions — — 5,000 (5,000 ) — Distribution to Parent — — (10,000 ) 10,000 — Proceeds from intercompany notes payable 29,773 — — — 29,773 Proceeds from Rail Facility revolver borrowings — — 102,075 — 102,075 Repayments of Rail Facility revolver borrowings — — (71,938 ) — (71,938 ) Net cash provided by financing activities 29,773 — 25,137 5,000 59,910 Net increase (decrease) in cash and cash equivalents 175,656 (701 ) (24,103 ) 166 151,018 Cash and equivalents, beginning of period 185,381 704 34,334 (2,016 ) 218,403 Cash and equivalents, end of period $ 361,037 $ 3 $ 10,231 $ (1,850 ) $ 369,421 13. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF CASH FLOW (UNAUDITED) Nine Months Ended September 30, 2014 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 538,783 $ (818,711 ) $ 7,287 $ 811,424 $ 538,783 Adjustments to reconcile net income to net cash from operating activities: Depreciation and amortization 15,123 125,053 687 — 140,863 Stock-based compensation — 4,725 — — 4,725 Change in fair value of catalyst lease obligations — (1,204 ) — — (1,204 ) Non-cash change in inventory repurchase obligations — (31,602 ) — — (31,602 ) Pension and other post retirement benefit costs 4,607 11,855 — — 16,462 (Gain) loss on disposition of property, plant and equipment (186 ) 24 — — (162 ) Equity in earnings of subsidiaries 811,424 — — (811,424 ) — Changes in current assets and current liabilities: Accounts receivable (69,105 ) (776 ) (31,871 ) — (101,752 ) Due to/from affiliates (890,671 ) 947,290 (52,621 ) — 3,998 Inventories (322,231 ) 24,320 (80,627 ) — (378,538 ) Prepaid expenses and other current assets 25,583 29 — — 25,612 Accounts payable (76,856 ) (20,905 ) 24,171 (2,418 ) (76,008 ) Accrued expenses 133,070 (2,376 ) 137,955 — 268,649 Deferred revenue (6,017 ) — — — (6,017 ) Other assets and liabilities (1,851 ) (13,889 ) — — (15,740 ) Net cash provided by (used in) operating activities 161,673 223,833 4,981 (2,418 ) 388,069 Cash flows from investing activities: Expenditures for property, plant and equipment (44,993 ) (152,755 ) (55,706 ) — (253,454 ) Expenditures for refinery turnarounds costs — (58,423 ) — — (58,423 ) Expenditures for other assets — (13,446 ) — — (13,446 ) Investment in subsidiaries (22,990 ) — — 22,990 — Proceeds from sale of assets 74,343 — — — 74,343 Net cash provided by (used in) investing activities 6,360 (224,624 ) (55,706 ) 22,990 (250,980 ) Cash flows from financing activities: Proceeds from members' capital contributions 328,664 — 22,990 (22,990 ) 328,664 Distributions to members (283,680 ) — — — (283,680 ) Proceeds from intercompany notes payable 90,761 — — — 90,761 Proceeds from Rail Facility revolver borrowings — — 35,925 — 35,925 Proceeds from revolver borrowings 395,000 — — — 395,000 Repayments of revolver borrowings (410,000 ) — — — (410,000 ) Deferred financing costs and other (7,164 ) — (3,218 ) — (10,382 ) Net cash provided by (used in) financing activities 113,581 — 55,697 (22,990 ) 146,288 Net increase (decrease) in cash and cash equivalents 281,614 (791 ) 4,972 (2,418 ) 283,377 Cash and equivalents, beginning of period 76,179 791 — — 76,970 Cash and equivalents, end of period $ 357,793 $ — $ 4,972 $ (2,418 ) $ 360,347

DESCRIPTION OF THE BUSINESS A27

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION (Details) - shares	May. 14, 2014	Sep. 30, 2015	Dec. 31, 2014
Common Units [Member] | IPO [Member]
Description of Business [Line Items]
Shares issued	15,812,500
PBF Energy [Member] | Class A Common Stock [Member]
Description of Business [Line Items]
Percentage of ownership in PBF LLC		94.40%	89.90%

INVENTORIES (Details)

INVENTORIES (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Jun. 30, 2015	Dec. 31, 2014
Inventory [Line Items]
Crude oil and feedstocks	$ 976,032		$ 976,032			$ 979,878
Refined products and blendstocks	855,517		855,517			775,767
Warehouse stock and other	40,890		40,890			36,726
Inventory, Gross	1,872,439		1,872,439			1,792,371
Lower of cost or market reserve	(771,257)		(771,257)		$ 562,944	(690,110)
Inventories	1,101,182		1,101,182			1,102,261
Operating Income (Loss)	65,073	$ 271,003	468,736	$ 613,283
Titled Inventory [Member]
Inventory [Line Items]
Crude oil and feedstocks	954,744		954,744			918,756
Refined products and blendstocks	545,279		545,279			520,308
Warehouse stock and other	40,890		40,890			36,726
Inventory, Gross	1,540,913		1,540,913			1,475,790
Lower of cost or market reserve	(662,638)		(662,638)			(609,774)
Inventories	878,275		878,275			866,016
Inventory Supply and Offtake Arrangements [Member]
Inventory [Line Items]
Crude oil and feedstocks	21,288		21,288			61,122
Refined products and blendstocks	310,238		310,238			255,459
Warehouse stock and other	0		0			0
Inventory, Gross	331,526		331,526			316,581
Lower of cost or market reserve	(108,619)		(108,619)			(80,336)
Inventories	222,907		222,907			$ 236,245
Scenario, Adjustment [Member]
Inventory [Line Items]
Operating Income (Loss)	$ (208,313)		$ (81,147)

DEFERRED CHARGES AND OTHER AS29

DEFERRED CHARGES AND OTHER ASSETS, NET (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Deferred turnaround costs, net	$ 183,618	$ 204,987
Catalyst, net	71,516	77,322
Deferred financing costs, net	25,006	30,128
Linefill	10,230	10,230
Restricted cash	1,500	1,521
Intangible assets, net	231	357
Other	9,830	5,972
Deferred charges and other assets	$ 301,931	$ 330,517

ACCRUED EXPENSES (Details)

ACCRUED EXPENSES (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Accrued Expenses:
Inventory-related accruals	$ 407,678	$ 588,297
Accrued distributions	268,066	0
Inventory supply and intermediation arrangements	212,930	253,549
Accrued transportation costs	49,548	59,959
Accrued salaries and benefits	37,766	55,993
Excise and sales tax payable	20,430	40,444
Accrued utilities	9,633	22,337
Customer deposits	8,910	24,659
Accrued interest	6,601	22,946
Accrued construction in progress	4,634	31,452
Other	23,041	30,334
Total accrued expenses	$ 1,049,237	$ 1,129,970

INTERCOMPANY NOTE PAYABLE (Deta

INTERCOMPANY NOTE PAYABLE (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Intercompany notes payable	$ 152,037	$ 122,264
Notes Payable, Other Payables [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate	2.50%
Debt instrument, term	5 years

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - PBF Logistics LP [Member] $ in Thousands	May. 15, 2015bbl / d$ / bbl	Oct. 01, 2014bbl / d$ / bbl	May. 14, 2014bbl / d$ / bbl	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Jun. 30, 2015USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)	Jul. 01, 2015$ / bbl
Omnibus Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, annual fee | $						$ 2,225	$ 2,350
Cost of Sales [Member] | Delaware City Terminaling Services Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction | $				$ 2,442			3,720
Cost of Sales [Member] | DCR Terminaling Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction | $				15,890	$ 13,800		47,153	$ 21,000
Cost of Sales [Member] | Toledo Terminaling Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction | $				1,766	944		3,608	1,526
Cost of Sales [Member] | West Ladder Rack Terminaling Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction | $				8,096			24,024
Cost of Sales [Member] | Toledo Tank Farm Storage and Terminaling Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction | $				6,355			19,113
Cost of Sales [Member] | Delaware City Pipeline Services Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction | $				2,533			3,795
General and Administrative Expense [Member] | Omnibus Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction | $				1,471	800		3,860	1,222
Operating Expense [Member] | Services Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction | $				$ 1,122	$ 125		$ 3,333	$ 191
Delaware City West Heavy Crude Unloading Rack [Member] | West Ladder Rack Terminaling Agreement [Member]
Related Party Transaction [Line Items]
Oil And Gas Plant, Terminaling Services Fee, Fee For Volume Above Minimum		1.50
Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d		40,000
Oil And Gas Plant, Terminaling Services Fee, Base Commitment		2.20
Toledo Storage Facility [Member] | Toledo Tank Farm Storage and Terminaling Agreement [Member]
Related Party Transaction [Line Items]
Oil And Gas Plant, Storage Services Fee		0.50
Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d		4,400
Oil And Gas Plant, Terminaling Services Fee, Base Commitment		2.52
Delaware City Products Pipeline [Member] | Delaware City Pipeline Services Agreement [Member]
Related Party Transaction [Line Items]
Term of Agreement	10 years
Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d	50,000
Oil And Gas Plant, Terminaling Services Fee, Base Commitment	0.5266									0.5507
Delaware City Truck Rack [Member] | Delaware City Terminaling Services Agreement [Member]
Related Party Transaction [Line Items]
Term of Agreement	10 years
Services Agreement [Member] | Delaware City Rail Unloading Terminal [Member] | DCR Terminaling Agreement [Member]
Related Party Transaction [Line Items]
Oil And Gas Plant, Terminaling Services Fee, Fee For Volume Above Minimum			0.50
Oil And Gas Plant, Terminaling Services Fee, Base Commitment			2.032
Services Agreement [Member] | Toledo Truck Unloading Terminal [Member] | Toledo Terminaling Agreement [Member]
Related Party Transaction [Line Items]
Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d			5,500
Oil And Gas Plant, Terminaling Services Fee, Base Commitment			1.016
Agreement Period Two [Member] | Services Agreement [Member] | Delaware City Rail Unloading Terminal [Member] | DCR Terminaling Agreement [Member]
Related Party Transaction [Line Items]
Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d			85,000
Refined Clean Product [Member] | Delaware City Truck Rack [Member] | Delaware City Terminaling Services Agreement [Member]
Related Party Transaction [Line Items]
Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d	30,000
Oil And Gas Plant, Terminaling Services Fee, Base Commitment	0.462
LPGs [Member] | Delaware City Truck Rack [Member] | Delaware City Terminaling Services Agreement [Member]
Related Party Transaction [Line Items]
Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity | bbl / d	5,000
Oil And Gas Plant, Terminaling Services Fee, Base Commitment	2.52

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2015USD ($)ppm	Dec. 31, 2010ppm	Dec. 31, 2014USD ($)
Loss Contingencies [Line Items]
Percent of tax benefit received from increases in tax basis paid to stockholders	85.00%
PBF Energy [Member] | Class A Common Stock [Member]
Loss Contingencies [Line Items]
Percentage of ownership in PBF LLC	94.40%		89.90%
Environmental Issue [Member]
Loss Contingencies [Line Items]
Environmental liability	$ 10,714,000		$ 10,476,000
Discount rate used for environmental liability assessment	8.00%
Maximum amount of sulfur allowed in heating oil (in ppm) | ppm	10
Public Utilities, Description of Specific Regulatory Liabilities	80
Environmental Issue [Member] | Valero [Member]
Loss Contingencies [Line Items]
Maximum pre-disposal environmental obligations of Valero	$ 20,000,000
Environmental Issue [Member] | PBF Energy and Valero [Member]
Loss Contingencies [Line Items]
Maximum pre-disposal environmental obligations of Valero	$ 75,000,000
Term of insurance policies	10 years
Environmental Issue [Member] | New York [Member]
Loss Contingencies [Line Items]
Maximum amount of sulfur allowed in heating oil (in ppm) | ppm		15

EMPLOYEE BENEFIT PLANS (Details

EMPLOYEE BENEFIT PLANS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Pension Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 5,790	$ 5,134	$ 17,369	$ 14,276
Interest cost	710	616	2,126	1,787
Expected return on plan assets	(830)	(546)	(2,489)	(1,609)
Amortization of prior service costs	13	13	39	26
Amortization of loss	311	277	933	757
Net periodic benefit cost	5,994	5,494	17,978	15,237
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	243	269	731	747
Interest cost	134	125	403	353
Amortization of prior service costs	76	52	228	107
Amortization of loss	0	0	0	(4)
Net periodic benefit cost	$ 453	$ 446	$ 1,362	$ 1,203

FAIR VALUE MEASUREMENTS (Measur

FAIR VALUE MEASUREMENTS (Measured on Recurring Basis) (Details) - Fair Value, Measurements, Recurring [Member] - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$ 9,441	$ 5,494
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	9,441	5,494
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0
Catalyst lease obligations [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative, Collateral, Right to Reclaim Cash	0	0
Catalyst lease obligations	27,577	36,559
Catalyst lease obligations [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Catalyst lease obligations	0	0
Catalyst lease obligations [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Catalyst lease obligations	27,577	36,559
Catalyst lease obligations [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Catalyst lease obligations	0	0
Commodity contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	137,670	397,676
Derivative, Collateral, Right to Reclaim Cash	(137,670)	(397,676)
Derivative Liability		0
Commodity contract [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	134,702
Derivative Liability		390,144
Commodity contract [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	1,945
Derivative Liability		7,338
Commodity contract [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	1,023
Derivative Liability		194
Derivatives included with inventory supply arrangement obligations [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	1,031	4,251
Derivative assets, Effect of Counter-party Netting	0	0
Derivative assets, Net Carrying Value on Balance Sheet	1,031	4,251
Derivatives included with inventory supply arrangement obligations [Member] | Level 1 [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
Derivatives included with inventory supply arrangement obligations [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	1,031	4,251
Derivatives included with inventory supply arrangement obligations [Member] | Level 3 [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
Money market funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	342,414	5,575
Money market funds [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	342,414	5,575
Money market funds [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	0	0
Money market funds [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	0	0
Commodity contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	160,455	428,831
Derivative assets, Effect of Counter-party Netting	(137,670)	(397,676)
Derivative assets, Net Carrying Value on Balance Sheet	22,785	31,155
Commodity contract [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	148,907
Derivative assets, Net Carrying Value on Balance Sheet		415,023
Commodity contract [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	10,710
Derivative assets, Net Carrying Value on Balance Sheet		12,093
Commodity contract [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	838
Derivative assets, Net Carrying Value on Balance Sheet		1,715
Derivatives included with intermediation agreement obligations [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	44,684	94,834
Derivative assets, Effect of Counter-party Netting		0
Derivative assets, Net Carrying Value on Balance Sheet	44,684	94,834
Derivatives included with intermediation agreement obligations [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	0
Derivative assets, Net Carrying Value on Balance Sheet		0
Derivatives included with intermediation agreement obligations [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	44,684
Derivative assets, Net Carrying Value on Balance Sheet		94,834
Derivatives included with intermediation agreement obligations [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	$ 0
Derivative assets, Net Carrying Value on Balance Sheet		$ 0

FAIR VALUE MEASUREMENTS (Change

FAIR VALUE MEASUREMENTS (Change in Fair Value at Level 3) (Details) - Commodity Contract [Member] - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Change in Fair Value Measurement Categorized in Level 3 [Roll Forward]
Balance at beginning of period	$ 1,905	$ 2,689	$ 1,521	$ (23,365)
Purchases	0	0	0	0
Settlements	(1,238)	(9,020)	(12,549)	(5,353)
Unrealized loss included in earnings	(852)	19,377	10,843	41,764
Transfers into Level 3	0	0	0	0
Transfers out of Level 3	0	0	0	0
Balance at end of period	$ (185)	$ 13,046	$ (185)	$ 13,046

FAIR VALUE MEASUREMENTS (Fair V

FAIR VALUE MEASUREMENTS (Fair Value and Carrying Value of Debt) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, Carrying value	$ 764,422	$ 742,349
Long-term debt, Fair value	775,616	749,409
Current portion of long-term debt	0	0
Long-Term Debt And Capital Lease Obligations, Current, Fair Value Disclosure	0	0
Long-term debt	764,422	742,349
Long-term debt, excluding current maturities, Fair value	775,616	749,409
Senior secured notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, Carrying value	669,354	668,520
Long-term debt, Fair value	680,548	675,580
Long-term Line of Credit	0	0
Lines of Credit, Fair Value Disclosure	0	0
Rail Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Line of Credit	67,491	37,270
Lines of Credit, Fair Value Disclosure	67,491	37,270
Catalyst lease [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, Carrying value	27,577	36,559
Long-term debt, Fair value	$ 27,577	$ 36,559

DERIVATIVES (Narrative) (Detail

DERIVATIVES (Narrative) (Details)	3 Months Ended	9 Months Ended
	Sep. 30, 2015USD ($)bbl	Sep. 30, 2015USD ($)bbl	Dec. 31, 2014bbl
Derivative [Line Items]
Loss on fair value hedge ineffectiveness | $	$ 0	$ 0
Crude Oil and Feedstock Inventory [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	0	0	0
Crude Oil and Feedstock Inventory [Member] | Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, notional amount, volume			662,579
Crude Oil and Feedstock Inventory [Member] | Fair Value Hedging [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	238,306	238,306
Intermediates and Refined Products Inventory [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	0	0	0
Intermediates and Refined Products Inventory [Member] | Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, notional amount, volume	3,130,766	3,130,766	3,106,325
Crude Oil Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	45,651,000	45,651,000	47,339,000
Refined Product Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	2,277,000	2,277,000	1,970,871

DERIVATIVES (Fair Value of Deri

DERIVATIVES (Fair Value of Derivative Instruments) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Designated as Hedging Instrument [Member] | Inventory Supply Arrangement Obligation [Member] | Accrued Expenses [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	$ 1,031	$ 4,251
Designated as Hedging Instrument [Member] | Inventory Intermediation Agreement Obligation [Member] | Accrued Expenses [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	44,684	94,834
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Accounts Receivable [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	$ 22,785	$ 31,155

DERIVATIVES (Gain (Loss) Recogn

DERIVATIVES (Gain (Loss) Recognized in Income) (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on Fair Value Hedge Ineffectiveness, Net	$ 0		$ 0
Designated as Hedging Instrument [Member] | Inventory Supply Arrangement Obligation [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	1,409,000	$ 2,729,000	(3,220,000)	$ 1,660,000
Designated as Hedging Instrument [Member] | Inventory Intermediation Agreement Obligation [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	34,424,000	20,900,000	(50,150,000)	29,942,000
Designated as Hedging Instrument [Member] | Crude Oil and Feedstock Inventory [Member] | Cost of Sales [Member] | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	(1,409,000)	(2,729,000)	3,220,000	(1,660,000)
Designated as Hedging Instrument [Member] | Intermediates and Refined Products Inventory [Member] | Cost of Sales [Member] | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	(34,424,000)	(20,900,000)	50,150,000	(29,942,000)
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	$ 31,017,000	$ 70,624,000	$ (14,080,000)	$ 101,902,000

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - USD ($) $ / shares in Units, $ in Thousands	Nov. 01, 2015	Oct. 29, 2015	Oct. 13, 2015	Sep. 30, 2015	Sep. 30, 2014
Subsequent Event [Line Items]
Conversion of Delaware Economic Development Authority loan to grant				$ 0	$ 4,000
Proceeds from sale of assets				$ 168,270	$ 74,343
Subsequent Event [Member] | PBF Energy [Member] | Class A Common Stock [Member]
Subsequent Event [Line Items]
Dividends declared per share		$ 0.3
Stockholders' Equity, Capital Distributions		$ 30,752
Chalmette Refining L.L.C. [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Business Combination, Consideration Transferred	$ 322,000
Estimated inventory and working capital acquired	$ 233,083
Public Offering [Member] | Subsequent Event [Member] | PBF Energy Inc. [Member] | Class A Common Stock [Member]
Subsequent Event [Line Items]
Stock Issued During Period, Shares, New Issues			11,500,000
Proceeds from Issuance or Sale of Equity			$ 344,000
Over-Allotment Option [Member] | Subsequent Event [Member] | PBF Energy Inc. [Member] | Class A Common Stock [Member]
Subsequent Event [Line Items]
Stock Issued During Period, Shares, New Issues			1,500,000
MOEM Pipeline [Member] | Subsequent Event [Member] | Charlmette Refining [Member]
Subsequent Event [Line Items]
Ownership percentage	100.00%
Collins Pipeline Company [Member] | Subsequent Event [Member] | Charlmette Refining [Member]
Subsequent Event [Line Items]
Ownership percentage	80.00%

CONDENSED CONSOLIDATING FINAN42

CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 3,217,640	$ 5,260,003	$ 9,763,440	$ 15,308,155
Cost of sales, excluding depreciation	2,858,409	4,685,652	8,414,423	13,776,574
Net income	48,179	252,515	411,803	538,783
Equity in earnings of subsidiaries	0	0	0	0
Accounts receivable	(395,624)		(395,624)		$ (551,269)
Accounts payable	(212,434)		$ (212,434)		(335,182)
PBF Services Company [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries			100.00%
Delaware City Refining Company LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries			100.00%
Delaware Pipeline Company LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries			100.00%
PBF Power Marketing LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries			100.00%
Paulsboro Refining Company LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries			100.00%
Paulsboro Natural Gas Pipeline Company LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries			100.00%
Toledo Refining Company LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries			100.00%
Investments LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries			100.00%
Guarantors Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Revenues	132,000	462,817	$ 668,576	1,201,888
Cost of sales, excluding depreciation	176,823	461,744	749,706	1,199,614
Net income	(292,138)	(268,034)	(852,587)	(818,711)
Equity in earnings of subsidiaries	0	0	0	0
Accounts receivable	(18,649)		(18,649)		(26,238)
Accounts payable	(92,332)		(92,332)		(92,984)
Issuer [Member]
Condensed Financial Statements, Captions [Line Items]
Revenues	3,215,163	5,258,747	9,737,169	15,305,698
Cost of sales, excluding depreciation	2,843,303	4,694,537	8,370,720	13,785,158
Net income	48,179	252,515	411,803	538,783
Equity in earnings of subsidiaries	(262,000)	$ (259,908)	(793,606)	$ (811,424)
Accounts receivable	(369,071)		(369,071)		(518,498)
Accounts payable	$ (121,933)		$ (121,933)		$ (235,791)

CONDENSED CONSOLIDATING FINAN43

CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Balance Sheet) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014	Sep. 30, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$ 369,421	$ 218,403	$ 360,347	$ 76,970
Accounts receivable	395,624	551,269
Accounts receivable - affiliate	3,299	3,223
Inventories	1,101,182	1,102,261
Prepaid expense and other current assets	55,152	32,157
Due from related party	0	0
Total current assets	1,924,678	1,907,313
Property, plant and equipment, net	1,814,507	1,806,060
Investment in subsidiaries	0	0
Deferred charges and other assets, net	301,931	330,517
Total assets	4,041,116	4,043,890
Current liabilities:
Accounts payable	212,434	335,182
Accounts payable - affiliate	24,272	11,630
Accrued expenses	1,049,237	1,129,970
Current portion of long-term debt	0	0
Deferred revenue	4,174	1,227
Due to related parties	0	0
Total current liabilities	1,290,117	1,478,009
Delaware Economic Development Authority loan	8,000	8,000
Long-term debt	764,422	742,349
Intercompany notes payable	152,037	122,264
Other long-term liabilities	63,081	62,752
Total liabilities	$ 2,277,657	$ 2,413,374
Commitments and contingencies
Equity:
Member's equity	$ 1,131,992	$ 1,144,100
Retained earnings (accumulated deficit)	657,028	513,292
Accumulated other comprehensive loss	(25,561)	(26,876)
Total equity	1,763,459	1,630,516
Total liabilities and equity	4,041,116	4,043,890
Issuer [Member]
Current assets:
Cash and cash equivalents	361,037	185,381	357,793	76,179
Accounts receivable	369,071	518,498
Accounts receivable - affiliate	802	529
Inventories	547,225	510,947
Prepaid expense and other current assets	44,940	26,964
Due from related party	19,279,650	16,189,384
Total current assets	20,602,725	17,431,703
Property, plant and equipment, net	21,630	68,218
Investment in subsidiaries	1,757,810	2,569,636
Deferred charges and other assets, net	33,906	34,840
Total assets	22,416,071	20,104,397
Current liabilities:
Accounts payable	121,933	235,791
Accounts payable - affiliate	24,272	11,600
Accrued expenses	536,121	487,783
Deferred revenue	4,174	1,227
Due to related parties	19,118,950	16,924,490
Total current liabilities	19,805,450	17,660,891
Delaware Economic Development Authority loan	0	0
Long-term debt	669,354	668,520
Intercompany notes payable	152,037	122,264
Other long-term liabilities	25,771	22,206
Total liabilities	$ 20,652,612	$ 18,473,881
Commitments and contingencies
Equity:
Member's equity	$ 1,131,992	$ 1,144,100
Retained earnings (accumulated deficit)	657,028	513,292
Accumulated other comprehensive loss	(25,561)	(26,876)
Total equity	1,763,459	1,630,516
Total liabilities and equity	22,416,071	20,104,397
Guarantors Subsidiaries [Member]
Current assets:
Cash and cash equivalents	3	704	0	791
Accounts receivable	18,649	26,238
Accounts receivable - affiliate	2,497	2,694
Inventories	376,182	435,924
Prepaid expense and other current assets	10,212	5,193
Due from related party	20,178,357	18,805,509
Total current assets	20,585,900	19,276,262
Property, plant and equipment, net	1,692,834	1,683,294
Investment in subsidiaries	0	0
Deferred charges and other assets, net	265,963	293,098
Total assets	22,544,697	21,252,654
Current liabilities:
Accounts payable	92,332	92,984
Accounts payable - affiliate	0	30
Accrued expenses	430,464	450,856
Deferred revenue	0	0
Due to related parties	20,342,238	18,151,095
Total current liabilities	20,865,034	18,694,965
Delaware Economic Development Authority loan	8,000	8,000
Long-term debt	27,577	36,559
Intercompany notes payable	0	0
Other long-term liabilities	37,310	40,546
Total liabilities	$ 20,937,921	$ 18,780,070
Commitments and contingencies
Equity:
Member's equity	$ 736,016	$ 749,278
Retained earnings (accumulated deficit)	879,148	1,731,694
Accumulated other comprehensive loss	(8,388)	(8,388)
Total equity	1,606,776	2,472,584
Total liabilities and equity	22,544,697	21,252,654
Non-Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	10,231	34,334	4,972	0
Accounts receivable	7,904	6,533
Accounts receivable - affiliate	0	0
Inventories	177,775	155,390
Prepaid expense and other current assets	0	0
Due from related party	2,867,690	1,607,878
Total current assets	3,063,600	1,804,135
Property, plant and equipment, net	100,043	54,548
Investment in subsidiaries	0	0
Deferred charges and other assets, net	2,062	2,579
Total assets	3,165,705	1,861,262
Current liabilities:
Accounts payable	19	8,423
Accounts payable - affiliate	0	0
Accrued expenses	82,652	191,331
Deferred revenue	0	0
Due to related parties	2,864,509	1,527,186
Total current liabilities	2,947,180	1,726,940
Delaware Economic Development Authority loan	0	0
Long-term debt	67,491	37,270
Intercompany notes payable	0	0
Other long-term liabilities	0	0
Total liabilities	$ 3,014,671	$ 1,764,210
Commitments and contingencies
Equity:
Member's equity	$ 39,346	$ 44,346
Retained earnings (accumulated deficit)	111,688	52,706
Accumulated other comprehensive loss	0	0
Total equity	151,034	97,052
Total liabilities and equity	3,165,705	1,861,262
Combining and Consolidated Adjustments [Member]
Current assets:
Cash and cash equivalents	(1,850)	(2,016)	$ (2,418)	$ 0
Accounts receivable	0	0
Accounts receivable - affiliate	0	0
Inventories	0	0
Prepaid expense and other current assets	0	0
Due from related party	(42,325,697)	(36,602,771)
Total current assets	(42,327,547)	(36,604,787)
Property, plant and equipment, net	0	0
Investment in subsidiaries	(1,757,810)	(2,569,636)
Deferred charges and other assets, net	0	0
Total assets	(44,085,357)	(39,174,423)
Current liabilities:
Accounts payable	(1,850)	(2,016)
Accounts payable - affiliate	0	0
Accrued expenses	0	0
Deferred revenue	0	0
Due to related parties	(42,325,697)	(36,602,771)
Total current liabilities	(42,327,547)	(36,604,787)
Delaware Economic Development Authority loan	0	0
Long-term debt	0	0
Intercompany notes payable	0	0
Other long-term liabilities	0	0
Total liabilities	$ (42,327,547)	$ (36,604,787)
Commitments and contingencies
Equity:
Member's equity	$ (775,362)	$ (793,624)
Retained earnings (accumulated deficit)	(990,836)	(1,784,400)
Accumulated other comprehensive loss	8,388	8,388
Total equity	(1,757,810)	(2,569,636)
Total liabilities and equity	$ (44,085,357)	$ (39,174,423)

CONDENSED CONSOLIDATING FINAN44

CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Statement of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues	$ 3,217,640	$ 5,260,003	$ 9,763,440	$ 15,308,155
Costs and expenses:
Cost of sales, excluding depreciation	2,858,409	4,685,652	8,414,423	13,776,574
Operating expenses, excluding depreciation	200,014	200,858	625,542	679,538
General and administrative expenses	47,802	34,786	116,115	103,505
Gain on sale of asset	(142)	18	(1,133)	(162)
Depreciation and amortization expense	46,484	67,686	139,757	135,417
Total cost and expenses	3,152,567	4,989,000	9,294,704	14,694,872
Income from operations	65,073	271,003	468,736	613,283
Other income (expenses)
Equity in earnings of subsidiaries	0	0	0	0
Change in fair value of catalyst leases	4,994	5,543	8,982	1,204
Interest expense, net	(21,888)	(24,031)	(65,915)	(75,704)
Net income	48,179	252,515	411,803	538,783
Comprehensive income	48,698	252,597	413,118	539,399
Combining and Consolidated Adjustments [Member]
Revenues	(551,829)	(847,147)	(1,893,262)	(1,585,477)
Costs and expenses:
Cost of sales, excluding depreciation	(551,829)	(847,147)	(1,893,262)	(1,585,477)
Operating expenses, excluding depreciation	0	0	0	0
General and administrative expenses	0	0	0	0
Gain on sale of asset	0	0	0	0
Depreciation and amortization expense	0	0	0	0
Total cost and expenses	(551,829)	(847,147)	(1,893,262)	(1,585,477)
Income from operations	0	0	0	0
Other income (expenses)
Equity in earnings of subsidiaries	262,000	259,908	793,606	811,424
Change in fair value of catalyst leases	0	0	0	0
Interest expense, net	0	0	0	0
Net income	262,000	259,908	793,606	811,424
Comprehensive income	262,000	260,003	793,606	811,424
Guarantors Subsidiaries [Member]
Revenues	132,000	462,817	668,576	1,201,888
Costs and expenses:
Cost of sales, excluding depreciation	176,823	461,744	749,706	1,199,614
Operating expenses, excluding depreciation	200,384	200,716	629,846	679,361
General and administrative expenses	6,827	4,302	15,987	12,701
Gain on sale of asset	1	18	(232)	24
Depreciation and amortization expense	43,820	64,165	130,496	125,031
Total cost and expenses	427,855	730,945	1,525,803	2,016,731
Income from operations	(295,855)	(268,128)	(857,227)	(814,843)
Other income (expenses)
Equity in earnings of subsidiaries	0	0	0	0
Change in fair value of catalyst leases	4,994	5,543	8,982	1,204
Interest expense, net	(1,277)	(5,449)	(4,342)	(5,072)
Net income	(292,138)	(268,034)	(852,587)	(818,711)
Comprehensive income	(292,138)	(268,129)	(852,587)	(818,711)
Non-Guarantor Subsidiaries [Member]
Revenues	422,306	385,586	1,250,957	386,046
Costs and expenses:
Cost of sales, excluding depreciation	390,112	376,518	1,187,259	377,279
Operating expenses, excluding depreciation	(275)	17	(490)	17
General and administrative expenses	973	(17)	1,798	(17)
Gain on sale of asset	(73)	0	(650)	0
Depreciation and amortization expense	547	222	1,597	264
Total cost and expenses	391,284	376,740	1,189,514	377,543
Income from operations	31,022	8,846	61,443	8,503
Other income (expenses)
Equity in earnings of subsidiaries	0	0	0	0
Change in fair value of catalyst leases	0	0	0	0
Interest expense, net	(884)	(720)	(2,462)	(1,216)
Net income	30,138	8,126	58,981	7,287
Comprehensive income	30,138	8,126	58,981	7,287
Issuer [Member]
Revenues	3,215,163	5,258,747	9,737,169	15,305,698
Costs and expenses:
Cost of sales, excluding depreciation	2,843,303	4,694,537	8,370,720	13,785,158
Operating expenses, excluding depreciation	(95)	125	(3,814)	160
General and administrative expenses	40,002	30,501	98,330	90,821
Gain on sale of asset	(70)	0	(251)	(186)
Depreciation and amortization expense	2,117	3,299	7,664	10,122
Total cost and expenses	2,885,257	4,728,462	8,472,649	13,886,075
Income from operations	329,906	530,285	1,264,520	1,419,623
Other income (expenses)
Equity in earnings of subsidiaries	(262,000)	(259,908)	(793,606)	(811,424)
Change in fair value of catalyst leases	0	0	0	0
Interest expense, net	(19,727)	(17,862)	(59,111)	(69,416)
Net income	48,179	252,515	411,803	538,783
Comprehensive income	$ 48,698	$ 252,597	$ 413,118	$ 539,399

CONDENSED CONSOLIDATING FINAN45

CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Statement of Cash Flows) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Cash flows from operating activities:
Net income	$ 48,179	$ 252,515	$ 411,803	$ 538,783
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization			145,975	140,863
Stock-based compensation			6,329	4,725
Change in fair value of catalyst lease obligations			(8,982)	(1,204)
Non-cash change in inventory repurchase obligations			53,370	(31,602)
Non-cash lower of cost or market inventory adjustment			81,147
(Gain) loss on sale of assets	(142)	18	(1,133)	(162)
Pension and other post retirement benefit costs			19,340	16,462
Equity in earnings of subsidiaries	0	0	0	0
Changes in current assets and current liabilities:
Accounts receivable			155,645	(101,752)
Inventories			(110,830)	(378,538)
Prepaid expense and other current assets			(22,995)	25,612
Accounts payable			(122,748)	(76,008)
Accrued expenses			(342,781)	268,649
Deferred revenue			2,947	(6,017)
Amounts due to/from related parties			12,566	3,998
Other assets and liabilities			(21,884)	(15,740)
Net cash provided by operations			257,769	388,069
Cash flows from investing activities:
Expenditures for property, plant and equipment			(287,931)	(253,454)
Expenditures for deferred turnaround costs			(39,725)	(58,423)
Expenditures for other assets			(7,275)	(13,446)
Investment in subsidiary			0	0
Proceeds from sale of assets			168,270	74,343
Net cash used in investing activities			(166,661)	(250,980)
Proceeds from revolver borrowings			0	395,000
Proceeds from members' capital contributions			0	328,664
Parent Distribution			0
Cash flows from financing activities:
Proceeds from Issuance of Other Long-term Debt				35,925
Repayments of Debt			(71,938)
Proceeds from intercompany notes payable			29,773	90,761
Distribution to members			0	(283,680)
Proceeds from Rail Facility revolver borrowings			102,075	35,925
Payment of contingent consideration related to acquisition of Toledo refinery			71,938	0
Repayments of revolver borrowings			0	(410,000)
Deferred financing costs and other				(10,382)
Net cash provided by financing activities			59,910	146,288
Net increase in cash and cash equivalents			151,018	283,377
Cash and equivalents, beginning of period			218,403	76,970
Cash and equivalents, end of period	369,421	360,347	369,421	360,347
Issuer [Member]
Cash flows from operating activities:
Net income	48,179	252,515	411,803	538,783
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization			13,085	15,123
Stock-based compensation			0	0
Change in fair value of catalyst lease obligations			0	0
Non-cash change in inventory repurchase obligations			0	0
Non-cash lower of cost or market inventory adjustment			(2,091)
(Gain) loss on sale of assets	(70)	0	(251)	(186)
Pension and other post retirement benefit costs			5,769	4,607
Equity in earnings of subsidiaries	262,000	259,908	793,606	811,424
Changes in current assets and current liabilities:
Accounts receivable			149,427	(69,105)
Inventories			(34,187)	(322,231)
Prepaid expense and other current assets			(17,976)	25,583
Accounts payable			(113,856)	(76,856)
Accrued expenses			(206,906)	133,070
Deferred revenue			2,947	(6,017)
Amounts due to/from related parties			(729,595)	(890,671)
Other assets and liabilities			(3,430)	(1,851)
Net cash provided by operations			268,345	161,673
Cash flows from investing activities:
Expenditures for property, plant and equipment			(188,364)	(44,993)
Expenditures for deferred turnaround costs			0	0
Expenditures for other assets			0	0
Investment in subsidiary			5,000	(22,990)
Proceeds from sale of assets			60,902	74,343
Net cash used in investing activities			(122,462)	6,360
Proceeds from revolver borrowings				395,000
Proceeds from members' capital contributions			0	328,664
Parent Distribution			0
Cash flows from financing activities:
Proceeds from Issuance of Other Long-term Debt				0
Repayments of Debt			0
Proceeds from intercompany notes payable			29,773	90,761
Distribution to members				(283,680)
Proceeds from Rail Facility revolver borrowings			0
Repayments of revolver borrowings				(410,000)
Deferred financing costs and other				(7,164)
Net cash provided by financing activities			29,773	113,581
Net increase in cash and cash equivalents			175,656	281,614
Cash and equivalents, beginning of period			185,381	76,179
Cash and equivalents, end of period	361,037	357,793	361,037	357,793
Guarantors Subsidiaries [Member]
Cash flows from operating activities:
Net income	(292,138)	(268,034)	(852,587)	(818,711)
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization			130,513	125,053
Stock-based compensation			6,329	4,725
Change in fair value of catalyst lease obligations			(8,982)	(1,204)
Non-cash change in inventory repurchase obligations			53,370	(31,602)
Non-cash lower of cost or market inventory adjustment			83,238
(Gain) loss on sale of assets	1	18	(232)	24
Pension and other post retirement benefit costs			13,571	11,855
Equity in earnings of subsidiaries	0	0	0	0
Changes in current assets and current liabilities:
Accounts receivable			7,589	(776)
Inventories			(54,258)	24,320
Prepaid expense and other current assets			(5,019)	29
Accounts payable			(654)	(20,905)
Accrued expenses			(27,197)	(2,376)
Deferred revenue			0	0
Amounts due to/from related parties			818,461	947,290
Other assets and liabilities			(18,276)	(13,889)
Net cash provided by operations			145,866	223,833
Cash flows from investing activities:
Expenditures for property, plant and equipment			(99,567)	(152,755)
Expenditures for deferred turnaround costs			(39,725)	(58,423)
Expenditures for other assets			(7,275)	(13,446)
Investment in subsidiary			0	0
Proceeds from sale of assets			0	0
Net cash used in investing activities			(146,567)	(224,624)
Proceeds from revolver borrowings				0
Proceeds from members' capital contributions			0	0
Parent Distribution			0
Cash flows from financing activities:
Proceeds from Issuance of Other Long-term Debt				0
Repayments of Debt			0
Proceeds from intercompany notes payable			0	0
Distribution to members				0
Proceeds from Rail Facility revolver borrowings			0
Repayments of revolver borrowings				0
Deferred financing costs and other				0
Net cash provided by financing activities			0	0
Net increase in cash and cash equivalents			(701)	(791)
Cash and equivalents, beginning of period			704	791
Cash and equivalents, end of period	3	0	3	0
Non-Guarantor Subsidiaries [Member]
Cash flows from operating activities:
Net income	30,138	8,126	58,981	7,287
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization			2,377	687
Stock-based compensation			0	0
Change in fair value of catalyst lease obligations			0	0
Non-cash change in inventory repurchase obligations			0	0
Non-cash lower of cost or market inventory adjustment			0
(Gain) loss on sale of assets	(73)	0	(650)	0
Pension and other post retirement benefit costs			0	0
Equity in earnings of subsidiaries	0	0	0	0
Changes in current assets and current liabilities:
Accounts receivable			(1,371)	(31,871)
Inventories			(22,385)	(80,627)
Prepaid expense and other current assets			0	0
Accounts payable			(8,404)	24,171
Accrued expenses			(108,678)	137,955
Deferred revenue			0	0
Amounts due to/from related parties			(76,300)	(52,621)
Other assets and liabilities			(178)	0
Net cash provided by operations			(156,608)	4,981
Cash flows from investing activities:
Expenditures for property, plant and equipment			0	(55,706)
Expenditures for deferred turnaround costs			0	0
Expenditures for other assets			0	0
Investment in subsidiary			0	0
Proceeds from sale of assets			107,368	0
Net cash used in investing activities			107,368	(55,706)
Proceeds from revolver borrowings				0
Proceeds from members' capital contributions			5,000	22,990
Parent Distribution			(10,000)
Cash flows from financing activities:
Proceeds from Issuance of Other Long-term Debt				35,925
Repayments of Debt			(71,938)
Proceeds from intercompany notes payable			0	0
Distribution to members				0
Proceeds from Rail Facility revolver borrowings			102,075
Repayments of revolver borrowings				0
Deferred financing costs and other				(3,218)
Net cash provided by financing activities			25,137	55,697
Net increase in cash and cash equivalents			(24,103)	4,972
Cash and equivalents, beginning of period			34,334	0
Cash and equivalents, end of period	10,231	4,972	10,231	4,972
Combining and Consolidated Adjustments [Member]
Cash flows from operating activities:
Net income	262,000	259,908	793,606	811,424
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization			0	0
Stock-based compensation			0	0
Change in fair value of catalyst lease obligations			0	0
Non-cash change in inventory repurchase obligations			0	0
Non-cash lower of cost or market inventory adjustment			0
(Gain) loss on sale of assets	0	0	0	0
Pension and other post retirement benefit costs			0	0
Equity in earnings of subsidiaries	(262,000)	(259,908)	(793,606)	(811,424)
Changes in current assets and current liabilities:
Accounts receivable			0	0
Inventories			0	0
Prepaid expense and other current assets			0	0
Accounts payable			166	(2,418)
Accrued expenses			0	0
Deferred revenue			0	0
Amounts due to/from related parties			0	0
Other assets and liabilities			0	0
Net cash provided by operations			166	(2,418)
Cash flows from investing activities:
Expenditures for property, plant and equipment			0	0
Expenditures for deferred turnaround costs			0	0
Expenditures for other assets			0	0
Investment in subsidiary			(5,000)	22,990
Proceeds from sale of assets			0	0
Net cash used in investing activities			(5,000)	22,990
Proceeds from revolver borrowings				0
Proceeds from members' capital contributions			(5,000)	(22,990)
Parent Distribution			10,000
Cash flows from financing activities:
Proceeds from Issuance of Other Long-term Debt				0
Repayments of Debt			0
Proceeds from intercompany notes payable			0	0
Distribution to members				0
Proceeds from Rail Facility revolver borrowings			0
Repayments of revolver borrowings				0
Deferred financing costs and other				0
Net cash provided by financing activities			5,000	(22,990)
Net increase in cash and cash equivalents			166	(2,418)
Cash and equivalents, beginning of period			(2,016)	0
Cash and equivalents, end of period	$ (1,850)	$ (2,418)	$ (1,850)	$ (2,418)