Torrance Logistics S-4 15 Nov 16 Registration of securities issued in business combination transactions Financial data

Document and Entity Information

Document and Entity Information	9 Months Ended
	Sep. 30, 2016
Entity Information [Line Items]
Entity Registrant Name	PBF HOLDING CO LLC
Entity Central Index Key	1,566,011
Document Type	S4
Amendment Flag	false
Document Period End Date	Sep. 30, 2016
Entity Filer Category	Non-accelerated Filer
PBF Finance Corporation [Member]
Entity Information [Line Items]
Entity Registrant Name	PBF FINANCE CORPORATION
Entity Central Index Key	1,566,097
Entity Filer Category	Non-accelerated Filer

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($)	Dec. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 914,749,000	$ 218,403,000
Accounts receivable	454,759,000	551,269,000
Accounts receivable - affiliate	3,438,000	3,223,000
Inventories	1,174,272,000	1,102,261,000
Prepaid expense and other current assets	33,701,000	32,157,000
Total current assets	2,580,919,000	1,907,313,000
Property, plant and equipment, net	2,211,090,000	1,806,060,000
Deferred charges and other assets, net	290,713,000	300,389,000
Total assets	5,082,722,000	4,013,762,000
Current liabilities:
Accounts payable	314,843,000	335,182,000
Accounts payable - affiliate	23,949,000	11,630,000
Accrued expenses	1,117,435,000	1,129,970,000
Current portion of long-term debt	0	0
Deferred revenue	4,043,000	1,227,000
Total current liabilities	1,460,270,000	1,478,009,000
Delaware Economic Development Authority loan	4,000,000	8,000,000
Long-term debt	1,236,720,000	712,221,000
Intercompany notes payable	470,047,000	122,264,000
Deferred tax liabilities	20,577,000	0
Other long-term liabilities	69,824,000	62,752,000
Total liabilities	3,261,438,000	2,383,246,000
Commitments and contingencies (Note 13)
Equity:
Member's equity	1,479,175,000	1,144,100,000
Retained earnings	349,654,000	513,292,000
Accumulated other comprehensive loss	(24,770,000)	(26,876,000)
Total PBF Holding Company LLC equity	1,804,059,000	1,630,516,000
Noncontrolling interest	17,225,000	0
Total equity	1,821,284,000	1,630,516,000
Total liabilities and equity	5,082,722,000	4,013,762,000
Accounts receivable - affiliate	3,438,000	3,223,000
Investment in equity method investee	0
Accounts payable	23,949,000	$ 11,630,000
Deferred tax liabilities	$ 0

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Statement [Abstract]
Revenues	$ 4,508,613	$ 3,217,640	$ 11,164,571	$ 9,763,440	$ 13,123,929	$ 19,828,155	$ 19,151,455
Cost and expenses:
Cost of sales, excluding depreciation	3,904,258	2,858,409	9,634,989	8,414,423	11,611,599	18,514,054	17,803,314
Operating expenses, excluding depreciation	404,045	200,014	972,223	625,542	889,368	880,701	812,652
General and administrative expenses	39,912	47,802	111,272	116,115	166,904	140,150	95,794
Equity (income) loss in investee	(1,621)	0	(1,621)	0
(Gain) loss on sale of assets	8,159	(142)	11,381	(1,133)	(1,004)	(895)	(183)
Depreciation and amortization expense	52,678	46,484	155,890	139,757	191,110	178,996	111,479
Total cost and expenses	4,407,431	3,152,567	10,884,134	9,294,704	12,857,977	19,713,006	18,823,056
Income from operations	101,182	65,073	280,437	468,736	265,952	115,149	328,399
Other income (expense)
Change in fair value of catalyst lease	77	4,994	(4,556)	8,982	10,184	3,969	4,691
Interest expense, net	(33,896)	(21,888)	(98,446)	(65,915)	(88,194)	(98,001)	(94,214)
Income before income taxes	67,363	48,179	177,435	411,803	187,942	21,117	238,876
Income tax expense	2,291	0	29,287	0	648	0	0
Net income	65,072	48,179	148,148	411,803	187,294	21,117	238,876
Less income attributable to noncontrolling interests	45	0	438	0	274	0	0
Net income attributable to PBF Holding Company LLC	$ 65,027	$ 48,179	$ 147,710	$ 411,803	$ 187,020	$ 21,117	$ 238,876

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement of Comprehensive Income [Abstract]
Net income	$ 65,072	$ 48,179	$ 148,148	$ 411,803	$ 187,294	$ 21,117	$ 238,876
Other comprehensive income (loss):
Unrealized gain (loss) on available for sale securities	(76)	119	329	115	124	127	(308)
Net gain (loss) on pension and other post-retirement benefits	502	400	1,134	1,200	1,982	(12,465)	(5,289)
Total other comprehensive income (loss)	426	519	1,463	1,315	2,106	(12,338)	(5,597)
Comprehensive income	65,498	48,698	149,611	413,118	189,400	8,779	233,279
Less: comprehensive income attributable to noncontrolling interests	45	0	438	0	274	0	0
Comprehensive income attributable to PBF Holding Company LLC	$ 65,453	$ 48,698	$ 149,173	$ 413,118	$ 189,126	$ 8,779	$ 233,279

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity Statement - USD ($) $ in Thousands	Total	Member's Equity [Member]	Accumulated Other Comprehensive Loss [Member]	Retained Earnings [Member]	Noncontrolling Interest [Member]
Beginning balance at Dec. 31, 2012	$ 1,751,654	$ 930,098	$ (8,941)	$ 830,497
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Member distributions	(215,846)			(215,846)
Member capital contributions	1,757	1,757
Distribution of assets to PBF LLC	0
Stock based compensation	1,309	1,309
Net income	238,876			238,876
Net income	238,876
Other comprehensive income	(5,597)		(5,597)
Ending balance at Dec. 31, 2013	1,772,153	933,164	(14,538)	853,527
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Member distributions	(361,352)			(361,352)
Member capital contributions	328,664	328,664
Distribution of assets to PBF LLC	(126,280)	(126,280)
Stock based compensation	6,095	6,095
Exercise of options and other	2,457	2,457
Net income	21,117			21,117
Net income	21,117
Other comprehensive income	(12,338)		(12,338)
Ending balance at Dec. 31, 2014	1,630,516	1,144,100	(26,876)	513,292
Net Income (Loss) Attributable to Noncontrolling Interest					$ 274
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Member distributions	(350,658)			(350,658)
Member capital contributions	345,000	345,000
Distribution of assets to PBF LLC	(19,233)	(19,233)
Stock based compensation	9,218	9,218
Exercise of options and other	90	90
Net income	187,294
Net income	187,020			187,020
Other comprehensive income	2,106		2,106
Noncontrolling interest acquired in Chalmette Acquisition	16,951				16,951
Ending balance at Dec. 31, 2015	1,821,284	$ 1,479,175	$ (24,770)	$ 349,654	$ 17,225
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	148,148
Net income	147,710
Other comprehensive income	1,463
Ending balance at Sep. 30, 2016	$ 1,888,667

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement of Cash Flows [Abstract]
Net income	$ 148,148	$ 411,803	$ 187,294	$ 21,117	$ 238,876
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization	162,565	145,975	199,383	186,412	118,001
Stock-based compensation	12,658	6,329	9,218	6,095	3,753
Change in fair value of catalyst lease obligation	4,556	(8,982)	(10,184)	(3,969)	(4,691)
Deferred income taxes	27,813	0
Non-cash change inventory repurchase obligations	29,317	53,370	63,389	(93,246)	(20,492)
Non-cash lower of cost or market inventory adjustment	(320,833)	81,147	427,226	690,110	0
Pension and other post retirement benefits costs	25,894	19,340	26,982	22,600	16,728
Equity (income) loss in investee	(1,621)	0
Gain on disposition of property, plant and equipment	11,381	(1,133)	(1,004)	(895)	(183)
Changes in current assets and current liabilities:
Accounts receivable	(194,898)	155,645	97,636	45,378	(92,851)
Due to/from affiliates	8,194	12,566
Due to/from affiliates			12,104	8,407	14,721
Inventories	54,052	(110,830)	(271,892)	(394,031)	45,991
Prepaid expense and other current assets	(20,203)	(22,995)	(631)	23,686	(42,455)
Accounts payable	50,297	(122,748)	(25,015)	(67,111)	42,236
Accrued expenses	308,047	(342,781)	(37,737)	59,899	214,817
Deferred revenue	8,029	2,947	2,816	(6,539)	(202,777)
Other assets and liabilities	(21,880)	(21,884)	(27,182)	(2,225)	(20,403)
Net cash provided by operations	291,516	257,769	652,403	495,688	311,271
Cash flow from investing activities:
Acquisition of Chalmette Refining, net of cash acquired	(971,932)	0	(565,304)	0	0
Expenditures for property, plant and equipment	(187,743)	(287,931)	(352,365)	(470,460)	(318,394)
Expenditures for deferred turnaround costs	(138,936)	(39,725)	(53,576)	(137,688)	(64,616)
Expenditures for other assets	(27,735)	(7,275)	(8,236)	(17,255)	(32,692)
Chalmette Acquisition working capital settlement	(2,659)	0
Proceeds from sale of assets	13,030	168,270	168,270	202,654	102,428
Net cash used in investing activities	(1,315,975)	(166,661)	(811,211)	(422,749)	(313,274)
Cash flows from financing activities:
Contributions from PBF LLC related to TVPC	175,000	0
Proceeds from members' capital contributions			345,000	328,664	1,757
Distributions to members	(92,503)	0	(350,658)	(361,352)	(215,846)
Repayments of affiliate notes payable	(517)	0
Proceeds from intercompany notes payable	635	29,773	347,783	90,631	31,835
Proceeds from revolver borrowings	550,000	0	170,000	395,000	1,450,000
Repayments of revolver borrowings	(11,457)	(71,938)	(170,000)	(410,000)	(1,435,000)
Proceeds from Rail Facility revolver borrowings	0	102,075	102,075	83,095	0
Repayments of Rail Facility revolver borrowings			(71,938)	(45,825)	0
Proceeds from 2023 Senior Secured Notes			500,000	0	0
Proceeds from catalyst lease	7,927	0	0	0	14,337
Payment of contingent consideration related to acquisition of Toledo refinery		(71,938)	0	0	(21,357)
Deferred financing costs and other			(17,108)	(11,719)	(1,044)
Net cash provided by (used in) financing activities	629,085	59,910	855,154	68,494	(175,318)
Net increase (decrease) in cash and cash equivalents	(395,374)	151,018	696,346	141,433	(177,321)
Cash and equivalents, beginning of period	914,749	218,403	218,403	76,970	254,291
Cash and equivalents, end of period	519,375	369,421	914,749	218,403	76,970
Non-cash activities:
Conversion of Delaware Economic Development Authority loan to grant			4,000	4,000	8,000
Acquisition of Torrance refinery and related logistics assets	0	268,066
Distribution of assets to PBF Energy Company LLC	173,426	15,975
Accrued construction in progress and unpaid fixed assets	$ 16,813	$ 4,670	7,974	33,296	33,747
Distribution of assets to PBF Energy Company LLC			19,233	126,280	0
Cash paid during the year for:
Interest (including capitalized interest of $3,529, $7,487 and $5,672 in 2015, 2014 and 2013, respectively)			$ 83,371	$ 96,346	$ 92,848

Consolidated Statements of Cas7

Consolidated Statements of Cash Flows (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement of Cash Flows [Abstract]
Capitalized interest	$ 3,529	$ 7,487	$ 5,672

DESCRIPTION OF THE BUSINESS AND

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 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" or the "Company"), 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 95.2% of the outstanding economic interest in, PBF LLC as of September 30, 2016 . 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 Refining"), Paulsboro Natural Gas Pipeline Company LLC, Toledo Refining Company LLC ("Toledo Refining" or "TRC"), Chalmette Refining, L.L.C. (“Chalmette Refining”) and PBF Western Region LLC (“PBF Western Region”) are PBF LLC’s principal operating subsidiaries and are all wholly-owned subsidiaries of PBF Holding. PBF Western Region owns Torrance Refining Company LLC and Torrance Logistics Company LLC, which collectively own the operating assets of the Torrance refinery and related logistics assets. In addition, PBF LLC, through Chalmette Refining, holds a 100% interest in MOEM Pipeline LLC and an 80% interest in and consolidates Collins Pipeline Company and T&M Terminal Company. 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. Subsequent to the PBFX Offering, PBF Holding and PBF LLC entered into a series of drop-down transactions with PBFX. During 2014, PBF Holding distributed to PBF LLC all of the equity interests of certain of its wholly-owned subsidiaries, whose assets consist of a heavy crude oil rail unloading facility (also, capable of unloading light crude oil) at the Delaware City refinery (the "DCR West Rack") and a tank farm and related facilities located at our Toledo refinery, including a propane storage and loading facility (the "Toledo Storage Facility"), which were subsequently acquired by PBFX. In addition, on May 14, 2015, PBF Holding distributed to PBF LLC, which subsequently contributed to PBFX, all of the issued and outstanding limited liability company interests of Delaware Pipeline Company LLC and Delaware City Logistics Company LLC, whose assets consist of a product pipeline, truck rack and related facilities located at our Delaware City refinery (collectively referred to as the “Delaware City Products Pipeline and Truck Rack”). On August 31, 2016, PBFX entered into a contribution agreement (the "TVPC Contribution Agreement") between PBFX and PBF LLC. Pursuant to the TVPC Contribution Agreement, PBFX acquired from PBF LLC 50% of the issued and outstanding limited liability company interests of Torrance Valley Pipeline Company LLC (“TVPC”), whose assets consist of the San Joaquin Valley Pipeline system (which was acquired as a part of the Torrance Acquisition as defined in "Note 2 - Acquisitions"), including the M55, M1 and M70 pipelines including pipeline stations with tankage and truck unloading capability (collectively, the “Torrance Valley Pipeline"). The total consideration paid to PBF LLC was $ 175,000 in cash, which was subsequently contributed to PBF Holding. Refer to "Note 8 - Related Party Transactions" of our Notes to Condensed Consolidated Financial Statements for further information on agreements entered into with PBFX. On August 31, 2016, in connection with the TVPC Contribution Agreement, PBF Holding contributed 50% of the issued and outstanding limited liability company interests of TVPC to PBF LLC. Substantially all of the Company’s operations are in the United States. As of September 30, 2016 , the Company’s oil refineries are all engaged in the refining of crude oil and other feedstocks into petroleum products, and have been aggregated to form one reportable segment. 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 accounting principles generally accepted in the United States of America ("GAAP") for interim financial information. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. These interim condensed consolidated financial statements should be read in conjunction with the financial statements included in the Annual Report on Form 10-K for the year ended December 31, 2015 of PBF Holding Company LLC and PBF Finance Corporation. The results of operations for the three and nine months ended September 30, 2016 are not necessarily indicative of the results to be expected for the full year. Noncontrolling Interest Subsequent to the Chalmette Acquisition (as defined in "Note 2 - Acquisitions"), PBF Holding recorded noncontrolling interest in two subsidiaries of Chalmette Refining. PBF Holding, through Chalmette Refining, owns an 80% ownership interest in both Collins Pipeline Company and T&M Terminal Company. The Company recorded aggregate earnings related to the noncontrolling interest in these subsidiaries of $45 and $438 for the three and nine months ended September 30, 2016 , respectively. Investment in Equity Method Investee Subsequent to the closing of the TVPC Contribution Agreement, the Company accounts for its 50% equity ownership of TVPC as an investment in an equity method investee. Investee companies that are not consolidated, but over which the Company exercises significant influence, are accounted for under the equity method of accounting. Whether or not the Company exercises significant influence with respect to an investee depends on an evaluation of several factors including, among others, representation on the investee company's board of directors and ownership level, which is generally a 20% to 50% interest in the voting securities of the investee company. Under the equity method of accounting, an investee company's accounts are not reported in the Company's consolidated balance sheets and statements of operations; however, the Company's share of the earnings or losses of the investee company is reflected in the caption ''Equity income (loss) in investee" in the consolidated statements of operations. The Company's carrying value in an equity method investee company is reported in the caption ''Investment in equity method investee'' in the Company's consolidated balance sheets. When the Company's carrying value in an equity method investee company is reduced to zero, no further losses are recorded in the Company's consolidated financial statements unless the Company guaranteed obligations of the investee company or has committed additional funding. When the investee company subsequently reports income, the Company will not record its share of such income until it equals or exceeds the amount of its share of losses not previously recognized. Prior Period Correction During the quarter ended March 31, 2016, the Company recorded an out-of-period adjustment increasing deferred income tax liabilities and income tax expense by $30,481 as described in "Note 6 - Income Taxes" of our Notes to Condensed Consolidated Financial Statements. The Company has considered existing guidance in evaluating whether a restatement of prior financial statements is required as a result of these misstatements. The Company has quantitatively and qualitatively assessed the materiality of the errors and concluded that this correction did not have a material impact on the financial statements as of and for the three months ended March 31, 2016 nor as of and for the nine months ended September 30, 2016 and the errors were not material to the prior period financial statements, and accordingly, the Company has not restated any prior period amounts. Recently Adopted Accounting Guidance Effective January 1, 2016, the Company adopted Accounting Standard Update ("ASU") No. 2015-02, "Consolidation (Topic 810): Amendments to the Consolidation Analysis" ("ASU 2015-02"), which changed existing consolidation requirements associated with the analysis a reporting entity must perform to determine whether it should consolidate certain types of legal entities, including limited partnerships and variable interest entities. The Company’s adoption of this guidance did not impact our consolidated financial statements. Effective January 1, 2016, the Company adopted 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. The adoption of this guidance did not materially affect any of the Company's financial statements or related disclosures. Recent Accounting Pronouncements In August 2015, the Financial Accounting Standards Board ("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 No. 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”) for all entities by one year. Additional ASUs have been issued in 2016 that provide certain implementation guidance related to ASU 2014-09 (collectively, the Company refers to ASU 2014-09 and these additional ASUs as the "Updated Revenue Recognition Guidance"). The Updated Revenue Recognition Guidance 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 is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In November 2015, the FASB issued ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes” (“ASU 2015-17”), which requires deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. Under ASU 2015-17, this guidance becomes effective for annual periods beginning after December 15, 2016 and interim periods within annual periods beginning after December 15, 2016 and interim periods within those years with early adoption permitted as of the beginning of an annual or interim period after the issuance of the ASU. The Company expects that the impact of adopting this new standard will be to reclassify all of its current deferred tax assets and deferred tax liabilities to a net noncurrent asset or liability on its balance sheet. In January 2016, the FASB issued ASU No. 2016-01, “Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” (“ASU 2016-01”), which amends how entities measure equity investments that do not result in consolidation and are not accounted for under the equity method and how they present changes in the fair value of financial liabilities measured under the fair value option that are attributable to their own credit. ASU 2016-01 also changes certain disclosure requirements and other aspects of current GAAP but does not change the guidance for classifying and measuring investments in debt securities and loans. Under ASU 2016-01, this guidance becomes effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted in certain circumstances. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842)” (“ASU 2016-02”), to increase the transparency and comparability about leases among entities. The new guidance requires lessees to recognize a lease liability and a corresponding lease asset for virtually all lease contracts. It also requires additional disclosures about leasing arrangements. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In March 2016, the FASB issued ASU No. 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments No. 2016-06 March 2016 a consensus of the FASB Emerging Issues Task Force” (“ASU 2016-06”), to increase consistency in practice in applying guidance on determining if an embedded derivative is clearly and closely related to the economic characteristics of the host contract, specifically for assessing whether call (put) options that can accelerate the repayment of principal on a debt instrument meet the clearly and closely related criterion. The guidance in ASU 2016-06 applies to all entities that are issuers of or investors in debt instruments (or hybrid financial instruments that are determined to have a debt host) with embedded call (put) options. ASU 2016-06 is effective for interim and annual periods beginning after December 15, 2016, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In March 2016, the FASB issued ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”) which is intended to simplify certain aspects of the accounting for share-based payments to employees. The guidance in ASU 2016-09 requires all income tax effects of awards to be recognized in the income statement when the awards vest or are settled rather than recording excess tax benefits or deficiencies in additional paid-in capital. The guidance in ASU 2016-09 also allows an employer to repurchase more of an employee’s shares than it can today for tax withholding purposes without triggering liability accounting and to make a policy election to account for forfeitures as they occur. ASU 2016-09 also contains additional guidance for nonpublic entities that do not apply to the Company. ASU 2016-09 is effective for interim and annual periods beginning after December 15, 2016, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In June 2016, the FASB issued ASU No. 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” (“ASU 2016-13”) which requires credit losses on available-for-sale debt securities to be presented as an allowance rather than as a write-down. ASU 2016-13 is effective for interim and annual periods beginning after December 15, 2019, and requires a modified retrospective approach to adoption. Early adoption is permitted for interim and annual periods beginning after December 15, 2018. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In August 2016, the FASB issued ASU No. 2016-15, "Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments" ("ASU 2016-15"), which reduces the existing diversity in practice in how certain cash receipts and cash payments are presented and classified in the statement of cash flows under Topic 230. ASU 2016-15 is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted, including adoption in an interim period. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In October 2016, the FASB issued ASU No. 2016-16, "Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory" ("ASU 2016-16"), which reduces the existing diversity in practice in how income tax consequences of an intra-entity transfer of an asset other than inventory should be recognized. The amendments in ASU 2016-16 require an entity to recognize such income tax consequences when the intra-entity transfer occurs rather than waiting until such time as the asset has been sold to an outside party. The amendments do not contain any new disclosure requirements but point out that certain existing income tax disclosures might be applicable in the period an intra-entity transfer of an asset other than inventory occurs. ASU 2016-16 is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted as of the beginning of an annual reporting period for which interim or annual statements have not been issued. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In October 2016, the FASB issued ASU No. 2016-17, "Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control" ("ASU 2016-2017"), which amends the consolidation guidance on how a reporting entity that is the single decision maker of a variable interest entity (“VIE”) should treat indirect interests in the entity held through related parties that are under common control with the reporting entity when determining whether it is the primary beneficiary of that VIE. The amendments in this ASU do not change the characteristics of a primary beneficiary in current GAAP. The amendments in this ASU require that reporting entity, in determining whether it satisfies the second characteristic of a primary beneficiary, to include all of its direct variable interests in a VIE and, on a proportionate basis, its indirect variable interests in a VIE held through related parties, including related parties that are under common control with the reporting entity. ASU 2016-2017 is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption is permitted, including adoption in an interim period. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.	DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION Description of the Business PBF Holding Company LLC (“PBF Holding” or the “Company”), 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 95.1% of the outstanding economic interest, in PBF LLC as of December 31, 2015 . PBF Finance Corporation (“PBF Finance”) is a wholly-owned subsidiary of PBF Holding. Delaware City Refining Company LLC (“DCR”), PBF Power Marketing LLC, PBF Energy Limited, Paulsboro Refining Company LLC (“Paulsboro Refining”), Paulsboro Natural Gas Pipeline Company LLC, Toledo Refining Company LLC (“Toledo Refining” or “TRC”), Chalmette Refining, L.L.C. (“Chalmette Refining”) and MOEM Pipeline LLC are PBF LLC's principal operating subsidiaries and are all wholly-owned subsidiaries of PBF Holding. In addition, PBF LLC, through Chalmette Refining, holds an 80% interest in and consolidates Collins Pipeline Company and T&M Terminal Company. 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. PBF Logistics GP LLC (“PBF GP”) serves as the general partner of PBFX. PBF GP is wholly-owned by PBF LLC. In connection with the PBFX Offering, PBF Holding distributed to PBF LLC the assets and liabilities of certain crude oil terminaling assets, which were immediately contributed by PBF LLC to PBFX. The assets were previously owned and operated by PBF Holding’s subsidiaries, DCR and Toledo Refining. The initial assets distributed 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” and together with DCR Rail Terminal, the “Contributed Assets”), which was part of PBF Holding’s Toledo, Ohio refinery. The Contributed Assets did not generate third party or intra-entity revenue prior to the PBFX Offering. The exchange for the Contributed Assets is described in the Contribution Agreement (as defined herein) (refer to Note 12 “Related Party Transactions” of our Notes to Consolidated Financial Statements). Effective September 30, 2014, PBF Holding distributed to PBF LLC all of the equity interests of DCR's wholly-owned subsidiary, Delaware City Terminaling Company II LLC (“DCT II”), which assets consist 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 for total consideration of $150,000 , consisting of $135,000 of cash and $15,000 of PBFX common units, or 589,536 common units (the “DCR West Rack Acquisition”). Effective 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 interest of Toledo Terminaling for total consideration to PBF LLC of $150,000 , consisting of $135,000 of cash and $15,000 of PBFX common units, or 620,935 common units (the “Toledo Storage Facility Acquisition”). On May 14, 2015, PBF Holding distributed all of the equity interests of DPC and Delaware City Logistics Company LLC (“DCLC”) to PBF LLC immediately prior to the contribution by PBF LLC to PBFX. The contributed assets consisted of the Delaware City Products Pipeline and Truck Rack, for a total consideration payable to PBF LLC of $143,000 , consisting of $112,500 of cash and $30,500 of PBFX common units, or 1,288,420 common units. Substantially all of the Company’s operations are in the United States. The Company’s four 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.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Principles of Consolidation and Presentation These consolidated financial statements include the accounts of PBF Holding and its consolidated subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation. Reclassification Certain amounts previously reported in the Company's consolidated financial statements for prior periods have been reclassified to conform to the 2015 presentation. These reclassifications include presentation of deferred financing costs and debt due to the adoption of a recently adopted accounting pronouncement (as discussed below). Use of Estimates The preparation of the financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures. Actual results could differ from those estimates. Business Combinations We use the acquisition method of accounting for the recognition of assets acquired and liabilities assumed in business combinations at their estimated fair values as of the date of acquisition. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired is recorded as goodwill. Significant judgment is required in estimating the fair value of assets acquired. As a result, in the case of significant acquisitions, we obtain the assistance of third-party valuation specialists in estimating fair values of tangible and intangible assets based on available historical information and on expectations and assumptions about the future, considering the perspective of marketplace participants. While management believes those expectations and assumptions are reasonable, they are inherently uncertain. Unanticipated market or macroeconomic events and circumstances may occur, which could affect the accuracy or validity of the estimates and assumptions. Cash and Cash Equivalents The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents. The carrying amount of the cash equivalents approximates fair value due to the short-term maturity of those instruments. Concentrations of Credit Risk For the year ended December 31, 2015 no single customer amounted to greater than or equal to 10% of the Company's revenue. Only one customer, ExxonMobil Oil Corporation (“ExxonMobil”), accounted for 10% or more of our total trade accounts receivables as of December 31, 2015 . Following the Chalmette Acquisition on November 1, 2015, ExxonMobil and its affiliates represented approximately 18% of our total trade accounts receivable as of December 31, 2015 . For the year ended December 31, 2014 , no single customer amounted to greater than or equal to 10% of the Company's revenues. No single customer accounted for 10% or more of our total trade accounts receivable as of December 31, 2014 . For the year ended December 31, 2013 , Morgan Stanley Capital Group, Inc. (“MSCG”) and Sunoco, Inc. (R&M) (“Sunoco”) accounted for 29% and 10% of the Company’s revenues, respectively. Revenue, Deferred Revenue and Accounts Receivable The Company sells various refined products primarily through its refinery subsidiaries and recognizes revenue related to the sale of products when there is persuasive evidence of an agreement, the sales prices are fixed or determinable, collectability is reasonably assured and when products are shipped or delivered in accordance with their respective agreements. Revenue for services is recorded when the services have been provided. Certain of the Company's refineries have products offtake agreements with third-parties under which these third parties purchase a portion of the refineries' daily gasoline production. The refineries also sell their products through short-term contracts or on the spot market. Prior to July 1, 2013, the Company’s Paulsboro and Delaware City refineries sold light finished products, certain intermediates and lube base oils to MSCG under products offtake agreements with each refinery (the “Offtake Agreements”). On a daily basis, MSCG purchased and paid for the refineries’ production of light finished products as they were produced, delivered to the refineries’ storage tanks, and legal title passed to MSCG. Revenue on these product sales was deferred until they shipped out of the storage facility by MSCG. Under the Offtake Agreements, the Company’s Paulsboro and Delaware City refineries also entered into purchase and sale transactions of certain intermediates and lube base oils whereby MSCG purchased and paid for the refineries’ production of certain intermediates and lube products as they were produced and legal title passed to MSCG. The intermediate products were held in the refineries’ storage tanks until they were needed for further use in the refining process. The intermediates may also have been sold to third parties. The refineries had the right to repurchase lube products and did so to supply other third parties with that product. When the refineries needed intermediates or lube products, the products were drawn out of the storage tanks, title passed back to the refineries and MSCG was paid for those products. These transactions occurred at the daily market price for the related products. These transactions were considered to be made in contemplation of each other and, accordingly, did not result in the recognition of a sale when title passed from the refineries to MSCG. Inventory remained at cost and the net cash receipts resulted in a liability that was recorded at market price for the volumes held in storage with any change in the market price being recorded in costs of sales. The liability represented the amount the Company expected to pay to repurchase the volumes held in storage. While MSCG had legal title, it had the right to encumber and/or sell these products and any such sales by MSCG resulted in sales being recognized by the refineries when products were shipped out of the storage facility. As the exclusive vendor of intermediate products to the refineries, MSCG had the obligation to provide the intermediate products to the refineries as they were needed. Accordingly, sales by MSCG to others were limited and only made with the Company or its subsidiaries’ approval. As of July 1, 2013, the Company terminated the Offtake Agreements for the Company’s Paulsboro and Delaware City refineries. The Company entered into two separate inventory intermediation agreements (“Inventory Intermediation Agreements”) with J. Aron & Company (“J. Aron”) on June 26, 2013 which commenced upon the termination of the Offtake Agreements with MSCG. On May 29, 2015, PBF Holding entered into amended and restated inventory intermediation agreements (the “A&R Intermediation Agreements”) with J. Aron pursuant to which certain terms of the existing inventory intermediation agreements were amended, including, among other things, pricing and an extension of the term for a period of two years from the original expiry date of July 1, 2015, subject to certain early termination rights. In addition, the A&R Intermediation Agreements include one-year renewal clauses by mutual consent of both parties. Pursuant to each A&R Intermediation Agreement, J. Aron will continue to purchase and hold title to certain of the intermediate and finished products (the “Products”) produced by the Paulsboro and Delaware City refineries (the “Refineries”), respectively, and delivered into tanks at the Refineries. Furthermore, J. Aron agrees to sell the Products back to Paulsboro refinery and Delaware City refinery as the Products are discharged out of the Refineries' tanks. J. Aron has the right to store the Products purchased in tanks under the A&R Intermediation Agreements and will retain these storage rights for the term of the agreements. PBF Holding will continue to market and sell the Products independently to third parties. Until December 31, 2015, the Company's Delaware City refinery sold and purchased feedstocks under a supply agreement with Statoil (the “Crude Supply Agreement”). This Crude Supply Agreement expired on December 31, 2015. Statoil purchased the refineries' production of certain feedstocks or purchased feedstocks from third parties on the refineries' behalf. Legal title to the feedstocks were held by Statoil and the feedstocks were held in the refineries' storage tanks until they were needed for further use in the refining process. At that time, the products were drawn out of the storage tanks and purchased by the refinery. These purchases and sales were settled monthly at the daily market prices related to those products. These transactions were considered to be made in contemplation of each other and, accordingly, did not result in the recognition of a sale when title passed from the refineries to Statoil. Inventory remained at cost and the net cash receipts resulted in a liability which is discussed further in the Inventory note below. The Company terminated its supply agreement with Statoil for its Paulsboro refinery in March 2013, at which time the Company began to purchase from Statoil the feedstocks owned by them at that date that had been purchased on its behalf. Subsequent to the expiration of the Delaware City Crude Supply Agreement, the Company began to purchase all of its crude and feedstock needs independently from a variety of suppliers on the spot market or through term agreements. Accounts receivable are carried at invoiced amounts. An allowance for doubtful accounts is established, if required, to report such amounts at their estimated net realizable value. In estimating probable losses, management reviews accounts that are past due and determines if there are any known disputes. There was no allowance for doubtful accounts at December 31, 2015 and 2014 . Excise taxes on sales of refined products that are collected from customers and remitted to various governmental agencies are reported on a net basis. Inventory Inventories are carried at the lower of cost or market. The cost of crude oil, feedstocks, blendstocks and refined products are determined under the last-in first-out (“LIFO”) method using the dollar value LIFO method with increments valued based on average purchase prices during the year. The cost of supplies and other inventories is determined principally on the weighted average cost method. The Company had the obligation to purchase and sell feedstocks under a supply agreement with Statoil for its Delaware City refinery. This Crude Supply Agreement expired on December 31, 2015. The Company's Paulsboro refinery also had a crude supply agreement with Statoil that was terminated in March 2013. Prior to the expiration or termination of these agreements, Statoil purchased the refineries' production of certain feedstocks or purchased feedstocks from third parties on the refineries' behalf. The Company took title to the crude oil as it was delivered to the processing units, in accordance with the Crude Supply Agreement; however, the Company was obligated to purchase all the crude oil held by Statoil on the Company’s behalf upon termination of the agreement at the then market price. The Paulsboro crude supply agreement also included an obligation to purchase a fixed volume of feedstocks from Statoil on the later of maturity or when the arrangement is terminated based on a forward market price of West Texas Intermediate crude oil. As a result of the purchase obligations, the Company recorded the inventory of crude oil and feedstocks in the refineries’ storage facilities. The Company determined the purchase obligations were contracts that contain derivatives that changed in value based on changes in commodity prices. Such changes in the fair value of these derivatives were included in cost of sales. Prior to July 31, 2014, the Company’s Toledo refinery acquired substantially all of its crude oil from MSCG under a crude oil acquisition agreement (the “Toledo Crude Oil Acquisition Agreement”). Under the Toledo Crude Oil Acquisition Agreement, the Company took title to crude oil at various pipeline locations for delivery to the refinery or sale to third parties. The Company recorded the crude oil inventory when it received title. Payment for the crude oil was due to MSCG under the Toledo Crude Oil Acquisition Agreement three days after the crude oil was delivered to the Toledo refinery processing units or upon sale to a third party. The Company terminated the Toledo Crude Oil Acquisition Agreement effective July 31, 2014 and began to source its crude oil needs independently. Property, Plant and Equipment Property, plant and equipment additions are recorded at cost. The Company capitalizes costs associated with the preliminary, pre-acquisition and development/construction stages of a major construction project. The Company capitalizes the interest cost associated with major construction projects based on the effective interest rate of total borrowings. The Company also capitalizes costs incurred in the acquisition and development of software for internal use, including the costs of software, materials, consultants and payroll-related costs for employees incurred in the application development stage. Depreciation is computed using the straight-line method over the following estimated useful lives: Process units and equipment 5-25 years Pipeline and equipment 5-25 years Buildings 25 years Computers, furniture and fixtures 3-7 years Leasehold improvements 20 years Railcars 50 years Maintenance and repairs are charged to operating expenses as they are incurred. Improvements and betterments, which extend the lives of the assets, are capitalized. Deferred Charges and Other Assets, Net Deferred charges and other assets include refinery turnaround costs, catalyst, precious metals catalyst, linefill, deferred financing costs and intangible assets. Refinery turnaround costs, which are incurred in connection with planned major maintenance activities, are capitalized when incurred and amortized on a straight-line basis over the period of time estimated to lapse until the next turnaround occurs (generally 3 to 5 years ). Precious metals catalyst and linefill are considered indefinite-lived assets as they are not expected to deteriorate in their prescribed functions. Such assets are assessed for impairment in connection with the Company’s review of its long-lived assets as indicators of impairment develop. Deferred financing costs are capitalized when incurred and amortized over the life of the loan (generally 1 to 8 years ). Intangible assets with finite lives primarily consist of catalyst, emission credits and permits and are amortized over their estimated useful lives (generally 1 to 10 years ). Long-Lived Assets and Definite-Lived Intangibles The Company reviews its long-lived assets for impairment whenever events or changes in circumstances indicate the carrying value may not be recoverable. Impairment is evaluated by comparing the carrying value of the long-lived assets to the estimated undiscounted future cash flows expected to result from use of the assets and their ultimate disposition. If such analysis indicates that the carrying value of the long-lived assets is not considered to be recoverable, the carrying value is reduced to the fair value. Impairment assessments inherently involve judgment as to assumptions about expected future cash flows and the impact of market conditions on those assumptions. Although management would utilize assumptions that it believes are reasonable, future events and changing market conditions may impact management’s assumptions, which could produce different results. Asset Retirement Obligations The Company records an asset retirement obligation at fair value for the estimated cost to retire a tangible long-lived asset at the time the Company incurs that liability, which is generally when the asset is purchased, constructed, or leased. The Company records the liability when it has a legal or contractual obligation to incur costs to retire the asset and when a reasonable estimate of the fair value of the liability can be made. If a reasonable estimate cannot be made at the time the liability is incurred, the Company will record the liability when sufficient information is available to estimate the liability’s fair value. Certain of the Company’s asset retirement obligations are based on its legal obligation to perform remedial activity at its refinery sites when it permanently ceases operations of the long-lived assets. The Company therefore considers the settlement date of these obligations to be indeterminable. Accordingly, the Company cannot calculate an associated asset retirement liability for these obligations at this time. The Company will measure and recognize the fair value of these asset retirement obligations when the settlement date is determinable. Environmental Matters Liabilities for future remediation costs are recorded when environmental assessments and/or remedial efforts are probable and the costs can be reasonably estimated. Other than for assessments, the timing and magnitude of these accruals generally are based on the completion of investigations or other studies or a commitment to a formal plan of action. Environmental liabilities are based on best estimates of probable future costs using currently available technology and applying current regulations, as well as the Company’s own internal environmental policies. The measurement of environmental remediation liabilities may be discounted to reflect the time value of money if the aggregate amount and timing of cash payments of the liabilities are fixed or reliably determinable. The actual settlement of the Company’s liability for environmental matters could materially differ from its estimates due to a number of uncertainties such as the extent of contamination, changes in environmental laws and regulations, potential improvements in remediation technologies and the participation of other responsible parties. Stock-Based Compensation Stock-based compensation includes the accounting effect of options to purchase PBF Energy Class A common stock granted by PBF Energy to certain PBF Holding employees, Series A warrants issued or granted by PBF LLC to employees in connection with their acquisition of PBF LLC Series A units, options to acquire Series A units of PBF LLC granted by PBF LLC to certain employees, Series B units of PBF LLC that were granted to certain members of management and restricted PBF LLC Series A Units and restricted PBF Energy Class A common stock granted to certain directors and officers. The estimated fair value of the options to purchase PBF Energy Class A common stock and the PBF LLC Series A warrants and options, is based on the Black-Scholes option pricing model and the fair value of the PBF LLC Series B units is estimated based on a Monte Carlo simulation model. The estimated fair value is amortized as stock-based compensation expense on a straight-line method over the vesting period and included in general and administration expense. Income Taxes As PBF Holding is a limited liability company treated as a “flow-through” entity for income tax purposes, there is no benefit or provision for federal or state income tax in the accompanying financial statements apart from the income taxes attributable to two subsidiaries acquired in connection with the acquisition of Chalmette Refining that are treated as C-corporations for tax purposes. The Federal and state tax returns for all years since 2012 are subject to examination by the respective tax authorities. Pension and Other Post-Retirement Benefits The Company recognizes an asset for the overfunded status or a liability for the underfunded status of its pension and post-retirement benefit plans. The funded status is recorded within other long-term liabilities or assets. Changes in the plans’ funded status are recognized in other comprehensive income in the period the change occurs. Fair Value Measurement A fair value hierarchy (Level 1, Level 2, or Level 3) is used to categorize fair value amounts based on the quality of inputs used to measure fair value. Accordingly, fair values derived from Level 1 inputs utilize quoted prices in active markets for identical assets or liabilities. Fair values derived from Level 2 inputs are based on quoted prices for similar assets and liabilities in active markets, and inputs other than quoted prices that are either directly or indirectly observable for the asset or liability. Level 3 inputs are unobservable inputs for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability. The Company uses appropriate valuation techniques based on the available inputs to measure the fair values of its applicable assets and liabilities. When available, the Company measures fair value using Level 1 inputs because they generally provide the most reliable evidence of fair value. In some valuations, the inputs may fall into different levels in the hierarchy. In these cases, the asset or liability level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurements. Financial Instruments The estimated fair value of financial instruments has been determined based on the Company’s assessment of available market information and appropriate valuation methodologies. The Company’s non-derivative financial instruments that are included in current assets and current liabilities are recorded at cost in the consolidated balance sheets. The estimated fair value of these financial instruments approximates their carrying value due to their short-term nature. Derivative instruments are recorded at fair value in the consolidated balance sheets. The Company’s commodity contracts are measured and recorded at fair value using Level 1 inputs based on quoted prices in an active market, Level 2 inputs based on quoted market prices for similar instruments, or Level 3 inputs based on third party sources and other available market based data. The Company’s catalyst lease obligation and derivatives related to the Company’s crude oil and feedstocks and refined product purchase obligations are measured and recorded at fair value using Level 2 inputs on a recurring basis, based on observable market prices for similar instruments. Derivative Instruments The Company is exposed to market risk, primarily related to changes in commodity prices for the crude oil and feedstocks used in the refining process as well as the prices of the refined products sold. The accounting treatment for commodity contracts depends on the intended use of the particular contract and on whether or not the contract meets the definition of a derivative. All derivative instruments, not designated as normal purchases or sales, are recorded in the balance sheet as either assets or liabilities measured at their fair values. Changes in the fair value of derivative instruments that either are not designated or do not qualify for hedge accounting treatment or normal purchase or normal sale accounting are recognized currently in earnings. Contracts qualifying for the normal purchase and sales exemption are accounted for upon settlement. Cash flows related to derivative instruments that are not designated or do not qualify for hedge accounting treatment are included in operating activities. The Company designates certain derivative instruments as fair value hedges of a particular risk associated with a recognized asset or liability. At the inception of the hedge designation, the Company documents the relationship between the hedging instrument and the hedged item, as well as its risk management objective and strategy for undertaking various hedge transactions. Derivative gains and losses related to these fair value hedges, including hedge ineffectiveness, are recorded in cost of sales along with the change in fair value of the hedged asset or liability attributable to the hedged risk. Cash flows related to derivative instruments that are designated as fair value hedges are included in operating activities. Economic hedges are hedges not designated as fair value or cash flow hedges for accounting purposes that are used to (i) manage price volatility in certain refinery feedstock and refined product inventories, and (ii) manage price volatility in certain forecasted refinery feedstock purchases and refined product sales. These instruments are recorded at fair value and changes in the fair value of the derivative instruments are recognized currently in cost of sales. Derivative accounting is complex and requires management judgment in the following respects: identification of derivatives and embedded derivatives, determination of the fair value of derivatives, documentation of hedge relationships, assessment and measurement of hedge ineffectiveness and election and designation of the normal purchases and sales exception. All of these judgments, depending upon their timing and effect, can have a significant impact on the Company’s earnings. Recently Issued Accounting Pronouncements In February 2015, the FASB issued ASU No. 2015-02, “Consolidations (Topic 810): Amendments to the Consolidation Analysis” (“ASU 2015-02”), which amends current consolidation guidance including changes to both the variable and voting interest models used by companies to evaluate whether an entity should be consolidated. The requirements from ASU 2015-02 are 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 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 early adopted the new standard in its consolidated financial statements and related disclosures, which resulted in a reclassification of $32,217 and $30,128 of deferred financing costs from other assets to long-term debt as of December 31, 2015 and December 31, 2014 , respectively. 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 and expects to early adopt this guidance for periods beginning after December 31, 2015. In November 2015, the FASB issued ASU 2015-17 (Topic 740), “Balance Sheet Classification of Deferred Taxes” (“ASU 2015-17”) which is intended to simplify the presentation of deferred taxes in a classified balance sheet. This guidance states that deferred tax assets and deferred tax liabilities should be presented as noncurrent in a classified statement of financial position. Under ASU 2015-17, this guidance becomes effective for annual periods beginning after December 15, 2016 and interim periods within those annual periods with early adoption permitted as of the beginning of an annual or interim period after issuance of the ASU. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures and expects to early adopt this guidance for periods beginning after December 31, 2015. In January 2016, the FASB issued ASU No. 2016-01, “Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” (“ASU 2016-01”), which amends how entities measure equity investments that do not result in consolidation and are not accounted for under the equity method and how they present changes in the fair value of financial liabilities measured under the fair value option that are attributable to their own credit. ASU 2016-01 also changes certain disclosure requirements and other aspects of current GAAP but does not change the guidance for classifying and measuring investments in debt securities and loans. Under ASU 2016-01, this guidance becomes effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted in certain circumstances. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842)” (“ASU 2016-02”), to increase the transparency and comparability about leases among entities. The new guidance requires lessees to recognize a lease liability and a corresponding lease asset for virtually all lease contracts. It also requires additional disclosures about leasing arrangements. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In March 2016, the FASB issued ASU No. 2016-06, “Derivatives and Hedging (Topic 815) Contingent Put and Call Options in Debt Instruments No. 2016-06 March 2016 a consensus of the FASB Emerging Issues Task Force” (“ASU 2016-06”), to increase consistency in practice in applying guidance on determining if an embedded derivative is clearly and closely related to the economic characteristics of the host contract, specifically for assessing whether call (put) options that can accelerate the repayment of principal on a debt instrument meet the clearly and closely related criterion. The guidance in ASU 2016-06 applies to all entities that are issuers of or investors in debt instruments (or hybrid financial instruments that are determined to have a debt host) with embedded call (put) options. ASU 2016-06 is effective for interim and annual periods beginning after December 15, 2016, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.

ACQUISITIONS

ACQUISITIONS	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Business Combinations [Abstract]
ACQUISITIONS	ACQUISITIONS Chalmette Acquisition On November 1, 2015, the Company acquired from ExxonMobil Oil Corporation, Mobil Pipe Line Company and PDV Chalmette, L.L.C., 100% of the ownership interests of 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 is strategically positioned on the Gulf Coast with logistics connectivity that offers flexible raw material sourcing and product distribution opportunities, including the potential to export products and provides geographic diversification into PADD 3. 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 inventory and final working capital of $245,963 . As described below, the valuation of the working capital was finalized in the first quarter of 2016. The transaction was financed through a combination of cash on hand and borrowings under the Company’s asset based revolving credit agreement (the "Revolving Loan"). The Company accounted for the Chalmette Acquisition as a business combination under GAAP whereby we recognize assets acquired and liabilities assumed in an acquisition at their estimated fair values as of the date of acquisition. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired is recorded as goodwill. The final purchase price and fair value allocation were completed as of March 31, 2016. During the measurement period, which ended in March 2016, adjustments were made to the Company's preliminary fair value estimates related primarily to inventories and accounts payable. The total purchase consideration and the fair values of the assets and liabilities at the acquisition date were as follows: Purchase Price Net cash $ 587,005 Cash acquired (19,042 ) Total consideration $ 567,963 The following table summarizes the final amounts recognized for assets acquired and liabilities assumed as of the acquisition date: Fair Value Allocation Accounts receivable $ 1,126 Inventories 271,434 Prepaid expenses and other current assets 913 Property, plant and equipment 356,961 Deferred charges and other assets 8,312 Accounts payable (4,870 ) Accrued expenses (28,371 ) Deferred tax liability (25,721 ) Noncontrolling interests (11,821 ) Fair value of net assets acquired $ 567,963 In addition, in connection with the acquisition of Chalmette Refining, the Company acquired Collins Pipeline Company and T&M Terminal Company, which are both C-corporations for tax purposes. As a result, the Company recognized a deferred tax liability of $25,721 attributable to the book and tax basis difference in the C-corporation assets, which had a corresponding impact on noncontrolling interests of $5,144 . The Company’s condensed consolidated financial statements for the three and nine months ended September 30, 2016 include the results of operations of the Chalmette refinery whereas the same periods in 2015 do not include the results of operations of the Chalmette refinery. On an unaudited pro forma basis, the revenues and net income of the Company assuming the acquisition had occurred on January 1, 2014, are shown below. The unaudited pro forma information does not purport to present what the Company’s actual results would have been had the acquisition occurred on January 1, 2014, nor is the financial information indicative of the results of future operations. The unaudited pro forma financial information includes the depreciation and amortization expense related to the acquisition and interest expense associated with the financing of the Chalmette Acquisition. Nine Months Ended September 30, 2015 Pro forma revenues $ 13,151,698 Pro forma net income attributable to PBF Holding Company LLC $ 682,671 The unaudited amount of revenues and net income above have been calculated after conforming Chalmette Refining's accounting policies to those of the Company and certain one-time adjustments. Torrance Acquisition On July 1, 2016, the Company acquired from ExxonMobil Oil Corporation and its subsidiary, Mobil Pacific Pipe Line Company, the Torrance refinery and related logistics assets (collectively, the "Torrance Acquisition"). The Torrance refinery, located in Torrance, California, is a high-conversion, delayed-coking refinery. The facility is strategically positioned in Southern California with advantaged logistics connectivity that offers flexible raw material sourcing and product distribution opportunities primarily in the California, Las Vegas and Phoenix area markets. The Torrance Acquisition provides the Company with a broader more diversified asset base and increases the number of operating refineries from four to five and the Company's combined crude oil throughput capacity. The acquisition also provides the Company with a presence in the attractive PADD 5 market. In addition to refining assets, the transaction includes a number of high-quality logistics assets including a sophisticated network of crude and products pipelines, product distribution terminals and refinery crude and product storage facilities. The most significant of the logistics assets is a crude gathering and transportation system which delivers San Joaquin Valley crude oil directly from the field to the refinery. Additionally, included in the transaction are several pipelines which provide access to sources of crude oil including the Ports of Long Beach and Los Angeles, as well as clean product outlets with a direct pipeline supplying jet fuel to the Los Angeles airport. The aggregate purchase price for the Torrance Acquisition was $521,350 in cash including post close purchase price adjustments, plus working capital of $450,582 . In addition, the Company assumed certain pre-existing environmental and regulatory emission credit obligations in connection with the Torrance Acquisition. The transaction was financed through a combination of cash on hand including proceeds from PBF Energy's October 2015 equity offering and borrowings under our Revolving Loan. The Company accounted for the Torrance Acquisition as a business combination under GAAP whereby we recognize assets acquired and liabilities assumed in an acquisition at their estimated fair values as of the date of acquisition. The purchase price and fair value allocation may be subject to adjustment pending completion of the final purchase valuation which was in process as of September 30, 2016. The total purchase consideration and the fair values of the assets and liabilities at the acquisition date, which may be subject to adjustment as noted above, were as follows: Purchase Price Gross purchase price $ 537,500 Working capital 450,582 Post close purchase price adjustments (16,150 ) Total consideration $ 971,932 The following table summarizes the preliminary amounts recognized for assets acquired and liabilities assumed as of the acquisition date: Fair Value Allocation Inventories $ 404,542 Prepaid expenses and other current assets 1,186 Property, plant and equipment 701,617 Deferred charges and other assets, net 68,053 Accounts payable (2,688 ) Accrued expenses (62,311 ) Other long-term liabilities (138,467 ) Fair value of net assets acquired $ 971,932 The Company’s condensed consolidated financial statements for the three and nine months ended September 30, 2016 include the results of operations of the Torrance refinery and related logistics assets subsequent to the Torrance Acquisition whereas the same periods in 2015 do not include the results of operations of such assets. During the period since its acquisition on July 1, 2016, the Torrance refinery contributed revenues of $928,225 and net income of $51,457 . On an unaudited pro forma basis, the revenues and net income of the Company assuming the Torrance Acquisition had occurred on January 1, 2015, are shown below. The unaudited pro forma information does not purport to present what the Company’s actual results would have been had the acquisition occurred on January 1, 2015, nor is the financial information indicative of the results of future operations. The unaudited pro forma financial information includes the depreciation and amortization expense attributable to the Torrance Acquisition and interest expense associated with the related financing. The unaudited amount of revenues and net income above have been calculated after conforming accounting policies of the Torrance refinery and related logistics assets to those of the Company and certain one-time adjustments. Nine Months Ended September 30, 2016 Nine Months Ended September 30, 2015 Pro forma revenues $ 12,243,582 $ 12,195,070 Pro forma net income (loss) attributable to PBF Holding LLC $ (60,908 ) $ 115,236 Acquisition Expenses The Company incurred acquisition related costs consisting primarily of consulting and legal expenses related to the Chalmette Acquisition, the Torrance Acquisition, and other pending and non-consummated acquisitions of $3,912 and $13,622 in the three and nine months ended September 30, 2016, respectively. In the three and nine months ended September 30, 2015, the Company incurred acquisition related costs of $1,555 and $1,704 respectively. These costs are included in the condensed consolidated statements of operations in General and administrative expenses.
ACQUISITIONS		ACQUISITIONS Chalmette Acquisition On November 1, 2015, the Company acquired from ExxonMobil, Mobil Pipe Line Company and PDV Chalmette, L.L.C., 100% of the ownership interests of 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 is strategically positioned on the Gulf Coast with strong logistics connectivity that offers flexible raw material sourcing and product distribution opportunities, including the potential to export products and provides geographic diversification into PADD 3. 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 $243,304 , which is subject to final valuation upon agreement of both parties. The transaction was financed through a combination of cash on hand and borrowings under the Company’s existing revolving credit line. The Company accounted for the Chalmette Acquisition as a business combination under US GAAP whereby we recognize assets acquired and liabilities assumed in an acquisition at their estimated fair values as of the date of acquisition. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired is recorded as goodwill. The final purchase price and its allocation are dependent on final reconciliations of working capital and other items subject to agreement by both parties. The following table summarizes the preliminary amounts recognized for assets acquired and liabilities assumed as of the acquisition date.The total purchase consideration and the estimated fair values of the assets and liabilities at the acquisition date were as follows: Purchase Price Net cash $ 565,083 Preliminary estimate of payable to Seller for working capital adjustments 19,263 Cash acquired (19,042 ) Total estimated consideration $ 565,304 Fair Value Allocation Accounts receivable $ 1,126 Inventories 268,751 Prepaid expenses and other current assets 913 Property, plant and equipment 356,961 Deferred charges and other assets 8,312 Accounts payable (4,870 ) Accrued expenses (28,347 ) Deferred tax liability (20,577 ) Noncontrolling interest (16,965 ) Estimated fair value of net assets acquired $ 565,304 In addition, in connection with the acquisition of Chalmette Refining, the Company acquired Collins Pipeline Company and T&M Terminal Company, which are both C-corporations for tax purposes. As a result, the Company recognized a deferred tax liability of $20,577 attributable to the book and tax basis difference in the C-corporation assets. The Company’s consolidated financial statements for the year ended December 31, 2015 include the results of operations of the Chalmette refinery since November 1, 2015 during which period the Chalmette refinery contributed revenues of $643,267 and net income of $53,539 . On an unaudited pro forma basis, the revenues and net income of the Company assuming the acquisition had occurred on January 1, 2014, are shown below. The unaudited pro forma information does not purport to present what the Company’s actual results would have been had the acquisition occurred on January 1, 2014, nor is the financial information indicative of the results of future operations. The unaudited pro forma financial information includes the depreciation and amortization expense related to the acquisition and interest expense associated with the Chalmette acquisition financing. Years ended December 31, (Unaudited) 2015 2014 Revenues $ 16,811,922 $ 26,685,661 Net income attributable to PBF Holdings LLC 397,108 47,030 The amount of revenues and net income above have been calculated after conforming Chalmette Refining's accounting policies to those of the Company and certain one-time adjustments. Acquisition Expenses The Company incurred acquisition related costs consisting primarily of consulting and legal expenses related to the Chalmette Acquisition and other pending and non-consummated acquisitions of $5,833 in the year ended December 31, 2015 . Acquisition related expenses were not material for the years ended December 31, 2014 and 2013 . These costs are included in the consolidated income statement in “General and Administrative expenses”.

INVENTORIES

INVENTORIES	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Inventory Disclosure [Abstract]
INVENTORIES	INVENTORIES Inventories consisted of the following: September 30, 2016 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 1,218,399 $ — $ 1,218,399 Refined products and blendstocks 976,556 359,297 1,335,853 Warehouse stock and other 87,846 — 87,846 $ 2,282,801 $ 359,297 $ 2,642,098 Lower of cost or market reserve (677,448 ) (119,055 ) (796,503 ) Total inventories $ 1,605,353 $ 240,242 $ 1,845,595 December 31, 2015 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 1,137,605 $ — $ 1,137,605 Refined products and blendstocks 687,389 411,357 1,098,746 Warehouse stock and other 55,257 — 55,257 $ 1,880,251 $ 411,357 $ 2,291,608 Lower of cost or market reserve (966,564 ) (150,772 ) (1,117,336 ) Total inventories $ 913,687 $ 260,585 $ 1,174,272 Inventory under inventory supply and intermediation arrangements included certain crude oil stored at the Company’s Delaware City refinery's storage facilities that the Company was obligated to purchase as it was consumed in connection with its Crude Supply Agreement that expired on December 31, 2015; and light finished products sold to counterparties in connection with the A&R Intermediation Agreements and stored in the Paulsboro and Delaware City refineries' storage facilities. Due to the lower crude oil and refined product pricing environment beginning at the end of 2014 and continuing throughout 2015 and 2016, the Company recorded adjustments to value its inventories to the lower of cost or market. During the three months ended September 30, 2016 , the Company recorded an adjustment to value its inventories to the lower of cost or market which increased both operating income and net income by $103,990 reflecting the net change in the lower of cost or market inventory reserve from $900,493 at June 30, 2016 to $796,503 at September 30, 2016 . During the nine months ended September 30, 2016 , the Company recorded an adjustment to value its inventories to the lower of cost or market which increased both operating income and net income by $320,833 reflecting the net change in the lower of cost or market inventory reserve from $1,117,336 at December 31, 2015 to $796,503 at September 30, 2016 . 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 .	INVENTORIES Inventories consisted of the following: December 31, 2015 Titled Inventory Inventory Supply and Offtake Arrangements Total Crude oil and feedstocks $ 1,137,605 $ — $ 1,137,605 Refined products and blendstocks 687,389 411,357 1,098,746 Warehouse stock and other 55,257 — 55,257 $ 1,880,251 $ 411,357 $ 2,291,608 Lower of cost or market adjustment (966,564 ) (150,772 ) (1,117,336 ) Total inventories $ 913,687 $ 260,585 $ 1,174,272 December 31, 2014 Titled Inventory Inventory Supply and Offtake 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 adjustment (609,774 ) (80,336 ) (690,110 ) Total inventories $ 866,016 $ 236,245 $ 1,102,261 Inventory under inventory supply and intermediation arrangements included certain crude oil stored at the Company's Delaware City refinery's storage facilities that the Company was obligated to purchase as it was consumed in connection with its Crude Supply Agreement that expired on December 31, 2015; and light finished products sold to counterparties in connection with the A&R 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 2015, the Company recorded adjustments to value its inventories to the lower of cost or market. During the year ended December 31, 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 $427,226 reflecting the net change in the lower of cost or market inventory reserve from $690,110 at December 31, 2014 to $1,117,336 at December 31, 2015 . In the year ended December 31, 2014 , the Company first recorded an adjustment to value its inventories to the lower of cost or market which decreased both operating income and net income by $690,110 .

PROPERTY, PLANT AND EQUIPMENT,

PROPERTY, PLANT AND EQUIPMENT, NET	12 Months Ended
	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
PROPERTY, PLANT AND EQUIPMENT, NET	PROPERTY, PLANT AND EQUIPMENT, NET Property, plant and equipment consisted of the following: December 31, December 31, Land $ 91,256 $ 59,575 Process units, pipelines and equipment 2,209,712 1,843,157 Buildings and leasehold improvements 34,265 28,397 Computers, furniture and fixtures 72,642 68,431 Construction in progress 150,388 69,413 2,558,263 2,068,973 Less—Accumulated depreciation (347,173 ) (262,913 ) $ 2,211,090 $ 1,806,060 Depreciation expense for the years ended December 31, 2015 , 2014 and 2013 was $88,474 , $113,533 and $79,413 , respectively. The Company capitalized $3,529 and $7,487 in interest during 2015 and 2014 , respectively, in connection with construction in progress. For the year ended December 31, 2014, the Company determined that it would abandon a capital project at the Delaware City refinery. The project was related to the construction of a new hydrocracker (the “Hydrocracker Project”). The carrying value for the Hydrocracker Project was $28,508 . The total pre-tax impairment charge of $28,508 was recorded in depreciation and amortization expense for the year ended December 31, 2014. No additional cash expenditures were incurred related to the Hydrocracker Project subsequent to the impairment charge.

DEFERRED CHARGES AND OTHER ASSE

DEFERRED CHARGES AND OTHER ASSETS, NET	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 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 $ 253,823 $ 177,236 Catalyst, net 106,311 77,725 Linefill 19,485 13,504 Restricted cash 1,500 1,500 Environmental credits 37,811 — Intangible assets, net 598 219 Other 29,743 20,529 Total deferred charges and other assets, net $ 449,271 $ 290,713	DEFERRED CHARGES AND OTHER ASSETS, NET Deferred charges and other assets, net consisted of the following: December 31, December 31, 2014 Deferred turnaround costs, net $ 177,236 $ 204,987 Catalyst 77,725 77,322 Linefill 13,504 10,230 Restricted cash 1,500 1,521 Intangible assets, net 219 357 Other 20,529 5,972 $ 290,713 $ 300,389 The Company recorded amortization expense related to deferred turnaround costs, catalyst and intangible assets of $102,636 , $65,452 and $32,066 for the years ended December 31, 2015 , 2014 and 2013 respectively. The restricted cash consists primarily of cash held as collateral securing the Rail Facility. Intangible assets, net was comprised of permits and emission credits as follows: December 31, December 31, 2014 Gross amount $ 3,597 $ 3,599 Accumulated amortization (3,378 ) (3,242 ) Net amount $ 219 $ 357

ACCRUED EXPENSES

ACCRUED EXPENSES	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Payables and Accruals [Abstract]
ACCRUED EXPENSES	ACCRUED EXPENSES Accrued expenses consisted of the following: September 30, December 31, Inventory-related accruals $ 845,772 $ 548,800 Inventory supply and intermediation arrangements 245,983 252,380 Renewable energy credit and emissions obligations 106,366 19,472 Accrued transportation costs 96,479 91,546 Excise and sales tax payable 70,871 34,129 Accrued utilities 39,390 25,192 Accrued interest 31,838 22,313 Accrued salaries and benefits 14,434 61,011 Accrued construction in progress 14,203 7,400 Customer deposits 12,871 20,395 Environmental liabilities 9,525 — Other 33,756 34,797 Total accrued expenses $ 1,521,488 $ 1,117,435 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 A&R Intermediation Agreements with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. ("J. Aron"). As of September 30, 2016 and December 31, 2015 , 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 A&R Inventory Intermediation Agreements, with any change in the market price being recorded in cost of sales. 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 expenses and other current assets when the amount of RINs earned and purchased is greater than the RINs liability.	ACCRUED EXPENSES Accrued expenses consisted of the following: December 31, December 31, 2014 Inventory-related accruals $ 548,800 $ 588,297 Inventory supply and intermediation arrangements 252,380 253,549 Accrued transportation costs 91,546 59,959 Accrued salaries and benefits 61,011 55,993 Excise and sales tax payable 34,129 40,444 Accrued construction in progress 7,400 31,452 Customer deposits 20,395 24,659 Accrued interest 22,313 22,946 Accrued utilities 25,192 22,337 Renewable energy credit obligations 19,472 286 Other 34,797 30,048 $ 1,117,435 $ 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 A&R Intermediation Agreements with J. Aron. As of December 31, 2015 , 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 had the obligation to purchase and sell feedstocks under a supply agreement with Statoil for its Delaware City refinery. This Crude Supply Agreement expired on December 31, 2015. Prior to its expiration, Statoil purchased the refinery's production of certain feedstocks or purchased feedstocks from third parties on the refineries' behalf. Legal title to the feedstocks was held by Statoil and the feedstocks were held in the refinery's storage tanks until they were needed for further use in the refining process. At that time, the products were drawn out of the storage tanks and purchased by the refinery. These purchases and sales were settled monthly at the daily market prices related to those products. These transactions were considered to be made in contemplation of each other and, accordingly, did not result in the recognition of a sale when title passed from the refinery to Statoil. Inventory remained at cost and the net cash receipts resulted 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 our 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 expenses 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.

DELAWARE ECONOMIC DEVELOPMENT A

DELAWARE ECONOMIC DEVELOPMENT AUTHORITY LOAN	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
DELAWARE ECONOMIC DEVELOPMENT AUTHORITY LOAN	DELAWARE ECONOMIC DEVELOPMENT AUTHORITY LOAN In June 2010, in connection with the Delaware City acquisition, the Delaware Economic Development Authority (the “Authority”) granted the Company a $20,000 loan to assist with operating costs and the cost of restarting the refinery. The loan is represented by a zero interest rate note and the entire unpaid principal amount is payable in full on March 1, 2017, unless the loan is converted to a grant. The Company recorded the loan as a long-term liability pending approval from the Authority that it has met the requirements to convert the remaining loan balance to a grant. The loan converts to a grant in tranches of up to $4,000 annually over a five -year period, starting at the one -year anniversary of the “certified restart date” as defined in the agreement and certified by the Authority. In order for the loan to be converted to a grant, the Company is required to utilize at least 600 man hours of labor in connection with the reconstruction and restarting of the Delaware City refinery, expend at least $125,000 in qualified capital expenditures, commence refinery operations, and maintain certain employment levels, all as defined in the agreement. In February 2013, October 2013, August 2014 and December 2015, the Company received confirmation from the Authority that the Company had satisfied the conditions necessary for the first four $4,000 tranches of the loan to be converted to a grant. As a result of the grant conversion, property, plant and equipment, net was reduced by $4,000 in each of the years ended December 31, 2015 and December 31, 2014 , respectively, as the proceeds from the loan were used for capital projects.

CREDIT FACILITY AND LONG-TERM D

CREDIT FACILITY AND LONG-TERM DEBT	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
CREDIT FACILITY AND LONG-TERM DEBT	CREDIT FACILITY AND LONG-TERM DEBT PBF Holding Revolving Loan On August 15, 2014, PBF Holding amended and restated the terms of its asset based revolving credit agreement (“Revolving Loan”) to, among other things, increase the commitments from $1,610,000 to $2,500,000 , and extend the maturity to August 2019. In addition, the amended and restated agreement reduced the interest rate on advances and the commitment fee paid on the unused portion of the facility. The amended and restated agreement also increased the sublimit for letters of credit from $1,000,000 to $1,500,000 and reduced the combined LC Participation Fee and Fronting Fee paid on each issued and outstanding letter of credit. As defined in the agreement, the LC Participation Fee ranges from 1.25% to 2.0% depending on the Company's debt rating and the Fronting Fee is equal to 0.25% . An accordion feature allows for increases in the aggregate commitment of up to $2,750,000 . In November 2015 and December 2015, PBF Holding increased the maximum availability under the Revolving Loan to $2,600,000 and $2,635,000 , respectively. At the option of PBF Holding, advances under the Revolving Loan will bear interest either at the Alternate Base Rate plus the Applicable Margin, or the Adjusted LIBOR Rate plus the Applicable Margin, all as defined in the agreement. The Applicable Margin ranges from 1.50% to 2.25% for Adjusted LIBOR Rate Loans and from 0.50% to 1.25% for Alternative Base Rate Loans, depending on the Company's debt rating. Interest is paid in arrears, either quarterly in the case of Alternate Base Rate Loans or at the maturity of each Adjusted LIBOR Rate Loan. Advances under the Revolving Loan, plus all issued and outstanding letters of credit may not exceed the lesser of $2,635,000 or the Borrowing Base, as defined in the agreement. The Revolving Loan can be prepaid, without penalty, at any time. The Revolving Loan has a financial covenant which requires that if at any time Excess Availability, as defined in the agreement, is less than the greater of (i) 10% of the lesser of the then existing Borrowing Base and the then aggregate Revolving Commitments of the Lenders (the “Financial Covenant Testing Amount”), and (ii) $100,000 and until such time as Excess Availability is greater than the Financial Covenant Testing Amount and $100,000 for a period of 12 or more consecutive days, PBF Holding will not permit the Consolidated Fixed Charge Coverage Ratio, as defined in the agreement and determined as of the last day of the most recently completed quarter, to be less than 1.1 to 1.0 . PBF Holding's obligations under the Revolving Loan (a) are guaranteed by each of its domestic operating subsidiaries that are not Excluded Subsidiaries (as defined in the agreement) and (b) are secured by a lien on (x) PBF LLC’s equity interests in PBF Holding and (y) certain assets of PBF Holding and the subsidiary guarantors, including all deposit accounts (other than zero balance accounts, cash collateral accounts, trust accounts and/or payroll accounts, all of which are excluded from the collateral); all accounts receivable; all hydrocarbon inventory (other than the intermediate and finished products owned by J. Aron pursuant to the Inventory Intermediation Agreements) and to the extent evidencing, governing, securing or otherwise related to the foregoing, all general intangibles, chattel paper, instruments, documents, letter of credit rights and supporting obligations; and all products and proceeds of the foregoing. There were no outstanding borrowings under the Revolving Loan as of December 31, 2015 and December 31, 2014 , and standby letters of credit were $351,511 and $400,262 , respectively. PBF Rail Revolving Credit Facility Effective March 25, 2014, PBF Rail Logistics Company LLC (“PBF Rail”), an indirect wholly-owned subsidiary of PBF Holding, entered into a $250,000 secured revolving credit agreement (the “Rail Facility”) with a consortium of banks, including Credit Agricole Corporate & Investment Bank (“CA-CIB”) as Administrative Agent. The primary purpose of the Rail Facility is to fund the acquisition by PBF Rail of coiled and insulated crude tank cars and non-coiled and non-insulated general purpose crude tank cars (the “Eligible Railcars”) before December 2015. The amount available to be advanced under the Rail Facility equals 70% of the lesser of the aggregate Appraised Value of the Eligible Railcars, or the aggregate Purchase Price of such Eligible Railcars, as these terms are defined in the Rail Facility. On the first anniversary of the closing, the advance rate adjusts automatically to 65% . At any time prior to maturity PBF Rail may repay and re-borrow any advances without premium or penalty. At PBF Rail's election, advances bear interest at a rate per annum equal to one month LIBOR plus the Facility Margin for Eurodollar Loans, or the Corporate Base Rate plus the Facility Margin for Base Rate Loans (the Corporate Base Rate is equal to the higher of the prime rate as determined by CA-CIB, the Federal Funds Rate plus 50 basis points, or one month LIBOR plus 100 basis points), all as defined in the Rail Facility. In addition, there is a commitment fee on the unused portion. Interest and fees are payable monthly. The lenders received a perfected, first priority security interest in all of PBF Rail's assets, including but not limited to (i) the Eligible Railcars, (ii) all railcar marks and other intangibles, (iii) the rights of PBF Rail under the Transportation Services Agreement (“TSA”) entered into between PBF Rail and PBF Holding, (iv) the accounts of PBF Rail, and (v) proceeds from the sale or other disposition of the Eligible Railcars, including insurance proceeds. In addition, the lenders received a pledge of the membership interest of PBF Rail held by PBF Transportation Company LLC, a wholly-owned subsidiary of PBF Holding. The obligations of PBF Holding under the TSA are guaranteed by each of Delaware City Refining, Paulsboro Refining, and Toledo Refining. On April 29, 2015, PBF Rail entered into the First Amendment to the Rail Facility. The amendments to the Rail Facility include the extension of the maturity to April 29, 2017, the reduction of the total commitment from $250,000 to $150,000 , and the reduction of the commitment fee on the unused portion of the Rail Facility. On the first anniversary of the closing of the amendment, the advance rate adjusts automatically to 65% . There was $67,491 and $37,270 outstanding under the Rail Facility at December 31, 2015 and December 31, 2014 , respectively. Senior Secured Notes On February 9, 2012, PBF Holding completed the offering of $675,500 aggregate principal amount of 8.25% Senior Secured Notes due 2020 (the “2020 Senior Secured Notes”). The net proceeds, after deducting the original issue discount, the initial purchasers’ discounts and commissions, and the fees and expenses of the offering, were used to repay all of the outstanding indebtedness plus accrued interest owed under the Toledo Promissory Note, the Paulsboro Promissory Note, and the Term Loan, as well as to reduce the outstanding balance of the Revolving Loan. On November 24, 2015, PBF Holding and PBF Holding’s wholly-owned subsidiary, PBF Finance Corporation completed an offering of $500,000 in aggregate principal amount of 7.00% Senior Secured Notes due 2023 (the “2023 Senior Secured Notes”, and together with the 2020 Senior Secured Notes, the “Senior Secured Notes”). The net proceeds from this offering were approximately $490,000 after deducting the initial purchasers’ discount and offering expenses. The Company intends to use the proceeds for general corporate purposes, including to fund a portion of the purchase price for the pending acquisition of the Torrance refinery and related logistics assets. The 2023 Senior Secured Notes include a registration payment arrangement whereby the Company has agreed to file with the SEC and use reasonable efforts to cause to become effective within 365 days of the closing date of the 2023 Senior Secured Notes offering, a registration statement relating to an offer to exchange the 2023 Senior Secured Notes for an issue of registered notes with terms substantially identical to the notes. The Company fully intends to file a registration statement for the exchange of the 2023 Senior Secured Notes within the 365 day period following the closing of the 2023 Senior Secured Notes. In addition, there are no restrictions or hindrances that the Company is aware of that would prohibit it from filing such registration statement and maintaining its effectiveness as stipulated in the registration rights agreement. As such, the Company asserts that it is not probable that it will have to transfer any consideration as a result of the registration rights agreement and thus no loss contingency was recorded. The Senior Secured Notes are secured on a first-priority basis by substantially all of the present and future assets of PBF Holding and its subsidiaries (other than assets securing the Revolving Loan). Payment of the Senior Secured Notes is jointly and severally guaranteed by substantially all of PBF Holding’s subsidiaries. PBF Holding has optional redemption rights to repurchase all or a portion of the Senior Secured Notes at varying prices no less than 100% of the principal amounts of the notes plus accrued and unpaid interest. The holders of the Senior Secured Notes have repurchase options exercisable only upon a change in control, certain asset sale transactions, or in event of a default as defined in the indenture agreement. In addition, the Senior Secured Notes contain covenant restrictions limiting certain types of additional debt, equity issuances, and payments. At all times after (a) a covenant suspension event (which requires that the Senior Secured Notes have investment grade ratings from both Moody’s Investment Services, Inc. and Standard & Poor’s), or (b) a Collateral Fall-Away Event, as defined in the indenture, the Senior Secured Notes will become unsecured. Catalyst Leases Subsidiaries of the Company have entered into agreements at each of its refineries whereby the Company sold certain of its catalyst precious metals to major commercial banks and then leased them back. The catalyst is required to be repurchased by the Company at market value at lease termination. The Company treated these transactions as financing arrangements, and the lease payments are recorded as interest expense over the agreements’ terms. 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 value of the underlying catalyst. The fair value of these repurchase obligations as reflected in the fair value of long-term debt outstanding table below is measured using Level 2 inputs. Details on the catalyst leases at each of our refineries as of December 31, 2015 are included in the following table: Annual lease fee Annual interest rate Expiration date Paulsboro catalyst lease $ 180 1.95 % December 2016 * Delaware City catalyst lease $ 322 1.96 % October 2016 * Toledo catalyst lease $ 326 1.99 % June 2017 Chalmette catalyst lease $ 185 3.85 % November 2018 * The Paulsboro and Delaware catalyst leases are included in long-term debt as of December 31, 2015 as the Company has the ability and intent to finance these debts through availability under other credit facilities if the catalyst leases are not renewed at maturity. Long-term debt outstanding consisted of the following: December 31, 2015 December 31, 2014 2020 Senior Secured Notes $ 669,644 $ 668,520 2023 Senior Secured Notes 500,000 — Revolving Loan — — Rail Facility 67,491 37,270 Catalyst leases 31,802 36,559 Unamortized deferred financing costs (32,217 ) (30,128 ) 1,236,720 712,221 Less—Current maturities — — Long-term debt $ 1,236,720 $ 712,221 Debt Maturities Debt maturing in the next five years and thereafter is as follows: Year Ending December 31, 2016 $ 17,252 2017 77,164 2018 4,877 2019 — 2020 669,644 Thereafter 500,000 $ 1,268,937

AFFILIATE NOTE PAYABLE

AFFILIATE NOTE PAYABLE	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
INTERCOMPANY NOTE PAYABLE [Abstract]
AFFILIATE NOTES PAYABLE	AFFILIATE NOTES PAYABLE As of September 30, 2016 , PBF Holding had outstanding notes payable with PBF Energy and PBF LLC for an aggregate principal amount of $470,165 ( $470,047 as of December 31, 2015 ). 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.	INTERCOMPANY NOTES PAYABLE During 2013, PBF Holding entered into notes payable with PBF Energy and PBF LLC. As of December 31, 2015 and 2014 , PBF Holding had outstanding notes payable with PBF Energy and PBF LLC for an aggregate principal amount of $470,047 and $122,264 , respectively. 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.

INTERCOMPANY NOTE PAYABLE

INTERCOMPANY NOTE PAYABLE	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
INTERCOMPANY NOTE PAYABLE [Abstract]
INTERCOMPANY NOTE PAYABLE	AFFILIATE NOTES PAYABLE As of September 30, 2016 , PBF Holding had outstanding notes payable with PBF Energy and PBF LLC for an aggregate principal amount of $470,165 ( $470,047 as of December 31, 2015 ). 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.	INTERCOMPANY NOTES PAYABLE During 2013, PBF Holding entered into notes payable with PBF Energy and PBF LLC. As of December 31, 2015 and 2014 , PBF Holding had outstanding notes payable with PBF Energy and PBF LLC for an aggregate principal amount of $470,047 and $122,264 , respectively. 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.

OTHER LONG-TERM LIABILITIES

OTHER LONG-TERM LIABILITIES	12 Months Ended
	Dec. 31, 2015
Other Liabilities Disclosure [Abstract]
OTHER LONG-TERM LIABILITIES	OTHER LONG-TERM LIABILITIES Other long-term liabilities consisted of the following: December 31, December 31, 2014 Defined benefit pension plan liabilities $ 42,509 $ 40,142 Post retiree medical plan 17,729 14,740 Environmental liabilities 8,189 7,870 Other 1,397 — $ 69,824 $ 62,752

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONS TVPC Contribution On August 31, 2016, PBF Holding contributed 50% of the issued and outstanding limited liability company interests of TVPC to PBF LLC. PBFX then acquired 50% of the issued and outstanding limited liability company interests of TVPC from PBF LLC pursuant to the TVPC Contribution Agreement. TVPC's assets consist of the Torrance Valley Pipeline. The total consideration paid to PBF LLC was $175,000 in cash, which was funded by PBFX with $20,000 of cash on hand, $76,200 in proceeds from the sale of marketable securities, and $78,800 in net proceeds from the August 2016 PBFX Equity Offering. PBFX’s wholly-owned subsidiary, PBFX Operating Company LP ("PBFX Op Co"), serves as TVPC's managing member. PBFX, through its ownership of PBFX Op Co, has the sole ability to direct the activities of TVPC that most significantly impact its economic performance. Accordingly, PBFX, and not PBF Holding, is considered to be the primary beneficiary for accounting purposes and as a result PBFX fully consolidates TVPC. Subsequent to the TVPC Contribution, PBF Holding records an investment in equity method investee on its balance sheet for the 50% of TVPC that it owns. PBF Holding's equity investment in TVPC is included in our Non-Guarantor results as this subsidiary is not a guarantor of the Senior Secured Notes as disclosed in "Note 14 - Condensed Consolidating Financial Statements of PBF Holding". Commercial Agreements PBF Holding entered into long-term, fee-based commercial agreements with PBFX. Under these agreements, PBFX provides various rail and truck terminaling services, pipeline services and storage services to PBF Holding and PBF Holding has committed to provide PBFX with minimum fees based on minimum monthly throughput volumes. The fees under each of these agreements are indexed for inflation and any increase in operating costs for providing such services to the Company. Prior to the PBFX Offering and completion of the subsequent drop-down transactions with PBFX, PBFX's assets, other than the East Coast Terminals (as defined below), were owned, operated and maintained by PBF Holding. Therefore, PBF Holding did not previously pay a fee for the utilization of the facilities. On April 29, 2016, PBFX closed on the purchase of four refined product terminals located in the greater Philadelphia region (the "East Coast Terminals") from an affiliate of Plains All American Pipeline, L.P. (the "PBFX Plains Asset Purchase"). In connection with the PBFX Plains Asset Purchase, PBFX assumed certain commercial agreements that Plains All American Pipeline, L.P. had previously entered into with PBF Holding and subsequent to the PBFX Plains Asset Purchase on April 29, 2016, PBF Holding entered into additional commercial agreements with PBFX related to the East Coast Terminals. These agreements have initial terms ranging from approximately three months to one year and include: • tank lease agreements, under which PBFX provides tank lease services to PBF Holding at the East Coast Terminals, with fees ranging from $0.45 to $0.55 per barrel received into the tank, up to 448,000 barrels, and $0.30 to $0.351 for all additional barrels received in excess of that amount. Additionally, the lease agreements include ancillary fees for tank to tank transfers; and • terminaling service agreements, under which PBFX provides terminaling and other services to PBF Holding at the East Coast Terminals, with fees ranging from $0.10 to $1.25 per barrel based on services provided, with additional flat rate fees for certain unloading/loading activities at the terminal. The tank lease agreements contain minimum requirements for the amount of leased tank capacity contracted by PBF Holding. Additionally, the fees under each commercial agreement are indexed for inflation based on the changes in the U.S Consumer Price Index for All Urban Consumers (the “CPI-U”). Each of these commercial agreements also include automatic renewal options ranging from three months to one year terms, unless written notice is provided by either PBFX or PBF Holding thirty days prior to the end of the previous term. In connection with the TVPC Contribution Agreement described above, PBF Holding and TVPC entered into a ten-year transportation services agreement (including the services orders thereunder, collectively the “Transportation Services Agreement”) under which PBFX, through TVPC, will provide transportation and storage services to PBF Holding on the Torrance Valley Pipeline in return for throughput fees. The Transportation Services Agreement can be extended by PBF Holding for two additional five -year periods. This agreement includes the following: • Transportation Services. The minimum throughput commitment for transportation services on the northern portion of the Torrance Valley Pipeline is approximately 50,000 barrels per day for a fee equal to $0.5625 per barrel of crude throughput 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 $0.5625 per barrel. The minimum throughput commitment for the southern portion of the Torrance Valley Pipeline is approximately 70,000 bpd with a fee equal to approximately $1.5625 per barrel and a fee of $0.3125 per barrel for amounts 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 $1.5625 per barrel; provided, however, that PBF Holding will receive a credit to PBF Holding’s account for the amount of such shortfall, and such credit will be applied in subsequent monthly invoices against excess throughput fees during any of the succeeding three months; and • Storage Services. PBF Holding will pay TVPC $0.85 per barrel fixed rate for the shell capacity of the Midway tank, which rate includes throughput equal to the shell capacity of the tank. PBF Holding will pay $0.85 per barrel fixed rate for each of the Belridge and Emidio storage tanks, which rate includes throughput equal to the shell capacity of each individual storage tank, subject to adjustment. PBF Holding will also pay $0.425 per barrel for throughput in excess of the shell capacity for each storage tank; provided that PBF Holding has a commitment for a minimum incremental throughput in excess of the shell capacity of (A) 715,000 barrels per month for the Belridge Tank (the “Belridge Storage MTC”), and (B) 600,000 barrels per month for the Emidio tank. If, during any month, actual throughput in excess of the shell capacity of all individual storage tanks by PBF Holding is less than the throughput storage minimum commitment, then PBF Holding will pay TVPC an amount equal to the storage rate multiplied by the throughput storage minimum commitment less the actual excess volumes. TVPC is required to maintain the Torrance Valley Pipeline in a condition and with a capacity sufficient to handle a volume of PBF Holding’s crude at least equal to the current operating capacity or the reserved crude capacity, as the case may be, subject to interruptions for routine repairs and maintenance and force majeure events. Failure to meet such obligations may result in a reduction of fees payable under the Transportation Services Agreement. Below is a summary of the commercial agreements entered into during the years ended December 31, 2015 and 2014 with PBFX having initial terms ranging from seven to ten years and corresponding fees for the use of each of the assets (no such agreements were entered into in the nine months ended September 30, 2016 other than in connection with the PBFX Plains Asset Purchase and TVPC Contribution). Each of these commercial agreements contains minimum volume commitments. The fees under each commercial agreement are indexed for inflation and the agreements give PBF Holding the option to renew for two additional five year terms following the expiration of the initial term. • a rail terminaling services agreement with PBFX with an initial term of approximately seven years, under which PBFX provides terminaling services at the DCR Rail Terminal (the "DCR Terminaling Agreement"). Pursuant to the DCR Terminaling Agreement, and based on the change in the U.S. Producer Price Index (the “PPI”), effective January 1, 2016, the terminaling service fee was decreased to $2.014 per barrel up to the minimum throughput commitment and $0.503 per barrel for volumes that exceed the minimum throughput commitment; • a truck unloading and terminaling services agreement with PBFX, with an initial term of approximately seven years, under which PBFX provides terminaling services at the Toledo Truck Terminal (the "Toledo Terminaling Agreement"). Pursuant to the Toledo Terminaling Agreement, and based on the change in the PPI, effective January 1, 2016, the terminaling service fee was decreased to $1.007 per barrel; • a terminaling services agreement, with an initial term of approximately seven years, under which PBFX provides rail terminaling services to PBF Holding at the DCR West Rack (the "West Ladder Rack Terminaling Agreement"); • a storage and terminaling services agreement, with an initial term of ten years, under which PBFX provides storage and terminaling services to PBF Holding at the Toledo Storage Facility (the "Toledo Storage Facility Storage and Terminaling Agreement"). Additionally, the Toledo Storage Facility Storage and Terminaling Agreement contains minimum requirements for the amount of storage contracted by PBF Holding; • a pipeline service agreement with PBFX, with an initial term of approximately ten years, under which PBFX, through Delaware Pipeline Company (“DPC”), provides pipeline services to PBF Holding at the Delaware City Products Pipeline (the "Delaware City Pipeline Services Agreement"). Effective July 2016, the throughput fee was decreased to $0.5396 per barrel due to a decrease in the Federal Energy Regulatory Commission tariff; and • a truck loading service agreement with PBFX, with an initial term of approximately ten years, under which PBFX, through Delaware City Logistics Company LLC (“DCLC”), provides terminaling services to PBF Holding at the Delaware City Truck Rack (the "Delaware City Truck Loading Agreement"). Other Agreements In addition to the commercial agreements described above, PBF Holding also entered into an omnibus agreement with PBFX, PBF GP and PBF LLC, which addresses the payment of an annual fee for the provision of various general and administrative services, among other matters (as amended from time to time, the "Omnibus Agreement").On August 31, 2016, the Omnibus Agreement was amended and restated which increased the annual fee to $ 4,000 to include the Torrance Valley Pipeline. PBF Holding and certain of its subsidiaries entered into an operation and management services and secondment agreement with PBFX under which PBFX reimburses PBF Holding for the provision of certain operational services to PBFX in support of its operations, including operational services performed by certain of PBF Holding's field-level employees (as amended from time to time, the "Services Agreement"). On August 31, 2016, the Services Agreement was amended and restated which increased the annual fee to $6,386 , to include the Torrance Valley Pipeline. Summary of Transactions A summary of revenue and expense transactions with our affiliates is as follows: Three Months Ended Nine Months Ended 2016 2015 2016 2015 Revenues under affiliate agreements: Omnibus Agreement $ 1,201 $ 1,471 $ 3,460 $ 3,941 Services Agreement 1,280 1,122 3,523 3,412 Total expenses under commercial agreements 43,842 37,082 118,356 104,796	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 and storage services agreements with PBFX under which PBFX provides commercial transportation, terminaling, storage and pipeline services to the Company. These agreements with PBFX include: Contribution Agreements On May 8, 2014, PBFX, PBF GP, PBF Energy, PBF LLC, PBF Holding, DCR, Delaware City Terminaling Company LLC (“Delaware City Terminaling”) and TRC entered into the Contribution and Conveyance Agreement (the “Contribution Agreement I”). On May 14, 2014, concurrent with the closing of the PBFX Offering, the following transactions occurred pursuant to the Contribution Agreement I: • DCR distributed all of the interests in Delaware City Terminaling and TRC distributed the Toledo Truck Terminal, in each case, to PBF Holding at their historical cost. • PBF Holding contributed, at their historical cost, (i) all of the interests in Delaware City Terminaling and (ii) the Toledo Truck Terminal to PBFX in exchange for (a) 74,053 common units and 15,886,553 subordinated units representing an aggregate 50.2% limited partner interest in PBFX, (b) all of PBFX’s incentive distribution rights, (c) the right to receive a distribution of $30,000 from PBFX as reimbursement for certain preformation capital expenditures attributable to the contributed assets, and (d) the right to receive a distribution of $298,664 ; and in connection with the foregoing, PBFX redeemed PBF Holding’s initial partner interests in PBFX for $1 . • PBF Holding distributed to PBF LLC (i) its interest in PBF GP, (ii) the common units, subordinated units and incentive distribution rights, (iii) the right to receive a distribution of $30,000 as reimbursement for certain preformation capital expenditures, and (iv) the right to receive a distribution of $298,664 . On September 30, 2014, PBF Holding, PBF LLC and PBFX closed the transaction contemplated by the Contribution Agreement dated September 16, 2014 (the “Contribution Agreement II”). Pursuant to the terms of the Contribution Agreement II, PBF Holding distributed to PBF LLC all of the equity interests of DCT II, which assets consisted solely of the DCR West Rack, immediately prior to the transfer of such equity interests by PBF LLC to PBFX. The DCR West Rack was previously owned and operated by PBF Holding’s subsidiary, DCT II, and is located at the Company's Delaware City refinery. PBFX paid to PBF LLC total consideration of $150,000 , consisting of $135,000 of cash and $15,000 of PBFX common units in exchange for the DCR West Rack. On December 11, 2014, PBF Holding, PBF LLC and PBFX closed the transaction contemplated by the Contribution Agreement dated December 2, 2014 (the “Contribution Agreement III”). Pursuant to the terms of the Contribution Agreement III, PBF Holding distributed to PBF LLC all of the issued and outstanding limited liability company interests of Toledo Terminaling, which assets consisted of the Toledo Storage Facility. PBF LLC then contributed to PBFX all of the equity interests of Toledo Terminaling for total consideration of $150,000 , consisting of $135,000 of cash and $15,000 of PBFX common units, or 620,935 common units. On May 14, 2015 PBF Holding, PBF LLC and PBFX closed the transactions contemplated by the Contribution Agreement dated May 5, 2015 (the “Contribution Agreement IV”). Pursuant to the terms of the Contribution Agreement IV, PBF Holding distributed all of the equity interests of Delaware Pipeline Company LLC (“DPC”) and Delaware City Logistics Company LLC (“DCLC”) to PBF LLC immediately prior to the contibution of such interests by PBF LLC to PBFX. The assets consisted of a products pipeline, truck rack and related facilities located at our Delaware City refinery (collectively the “Delaware City Products Pipeline and Truck Rack”), for total consideration of $143,000 consisting of $112,500 of cash and $30,500 of PBFX common units, or 1,288,420 common units. Commercial Agreements In connection with the contribution agreements described above, PBF Holding entered into long-term, fee-based commercial agreements with PBFX. Under these agreements, PBFX provides various rail and truck terminaling and storage services to PBF Holding and PBF Holding has committed to provide PBFX with minimum fees based on minimum monthly throughput volumes. The fees under each of these agreements are indexed for inflation and any increase in operating costs for providing such services to the Company. Prior to the PBFX Offering, the DCR Rail Terminal, Toledo Truck Terminal, the DCR West Rack and the Toledo Storage Facility and other assets contributed to PBFX subsequent to the PBFX Offering were owned, operated and maintained by PBF Holding. Therefore, PBF Holding did not previously pay a fee for the utilization of the facilities. Below is a summary of the agreements and corresponding fees for the use of each of the assets. Delaware City Rail Terminaling Services Agreement On May 14, 2014, concurrent with the closing of the PBFX Offering, 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 bpd ( 75,000 bpd through September 30, 2014) for each quarter thereafter (in each case, calculated on a quarterly average basis) for a terminaling service fee of $2.00 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. The terminaling service fee is subject to (i) increase or decrease on January 1 of each year, beginning on January 1, 2015, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) increase by the increase in any operating costs that increase greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the DCR Terminaling Agreement. Effective January 1, 2015, the service fee was increased to $2.032 per barrel up to the minimum throughput commitment and $0.508 per barrel for volumes that exceed the minimum throughput commitment. The agreement will terminate on the first December 31st following the seventh anniversary of the closing of the PBFX Offering and may be extended, at PBF Holding's option, for up to two additional five -year terms. For the year ended December 31, 2015 and 2014 , PBF Holding paid PBFX $63,043 and $36,640 , respectively, for fees related to the DCR Terminaling Agreement. Toledo Truck Unloading & Terminaling Agreement On May 14, 2014, concurrent with the closing of the PBFX Offering, 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 was obligated to throughput aggregate volumes of crude oil of at least 4,000 bpd (calculated on a quarterly average basis) for a terminaling service fee of $1.00 per barrel. The Toledo Terminaling Agreement was amended and restated effective as of June 1, 2014, to among other things, increase the minimum throughput volume commitment from 4,000 bpd to 5,500 bpd beginning August 1, 2014. PBF Holding also pays PBFX for providing related ancillary services at the terminal which are specified in the Toledo Terminaling Agreement. The terminaling service fee is subject to (i) increase or decrease on January 1 of each year, beginning on January 1, 2015, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) increase by the increase in any operating costs that increase greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the Toledo Terminaling Agreement. Effective January 1, 2015, the terminaling fee was increased to $1.016 . The agreement will terminate on the first December 31st following the seventh anniversary of the closing of the PBFX Offering and may be extended, at PBF Holding's option, for up to two additional five-year terms. For the year ended December 31, 2015 and 2014 , PBF Holding paid PBFX $5,578 and $2,131 , respectively, for fees related to the Toledo Terminaling Agreement. Delaware City West Ladder Rack Terminaling Services Agreement On October 1, 2014, PBF Holding and DCT II entered into a seven -year terminaling services agreement (the “West Ladder Rack Terminaling Agreement”) under which PBFX, through DCT II, provides rail terminaling services to PBF Holding. DCT II, immediately following the closing of the Contribution Agreement II, was merged with and into Delaware City Terminaling, a wholly-owned subsidiary of PBFX, with all property, rights, liabilities and obligations of DCT II vesting in Delaware City Terminaling as the surviving company. The agreement may be extended by PBF Holding for two additional five -year periods. 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. The terminaling service fee is subject to (i) increase or decrease on January 1 of each year, beginning on January 1, 2016, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) increase by the increase in any operating costs that increase greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the West Ladder Rack Terminaling Agreement. For the year ended December 31, 2015 and 2014 , PBF Holding paid PBFX $32,120 and $9,639 , respectively, related to the West Ladder Rack Terminaling Agreement. Toledo Storage Facility Storage and Terminaling Services Agreement On December 12, 2014, PBF Holding and Toledo Terminaling entered into a ten -year storage and terminaling services agreement (the “Toledo Storage Facility Storage and Terminaling Agreement”) under which PBFX, through Toledo Terminaling, will provide storage and terminaling services to PBF Holding. The Toledo Storage Facility Storage and Terminaling Agreement can be extended by PBF Holding for two additional five -year periods. Under the Toledo Storage Facility Storage and Terminaling Agreement, PBFX will provide 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 products rack and the overall capacity of the Toledo Storage Facility Assets. PBF Holding will pay 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 will be 4,400 barrels per day (“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. PBFX is required to maintain the Toledo Storage Facility Assets in a condition and with a capacity sufficient to store and handle a volume of PBF Holding's products at least equal to the current operating capacity for the storage facility as a whole subject to interruptions for routine repairs and maintenance and force majeure events. Failure to meet such obligations may result in a reduction of fees payable under the Toledo Storage Facility Storage and Terminaling Agreement. For the year ended December 31, 2015 and 2014 , PBF Holding paid PBFX $25,495 and $1,420 , respectively, related to the Toledo Tank Farm Storage and Terminaling Agreement. Delaware City Pipeline Services Agreement On May 15, 2015, 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, after which PBF Holding has the option to extend the agreement for two additional five year periods, 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 pipeline service fee was raised to $0.5507 per barrel, due to an increase in the Federal Energy Regulatory Commission (“FERC”) tariff. For the year ended December 31, 2015 , PBF Holding paid PBFX fees of $6,328 , related to the Delaware City Pipeline Services Agreement. For the year ended December 31, 2014 , PBF Holding paid PBFX no fees related to the Delaware City Pipeline Services Agreement. Delaware City Truck Loading Agreement On May 15, 2015, PBF Holding entered into a terminaling services agreement with PBFX (the “Delaware City Truck Loading Agreement”). Under the Delaware City Truck Loading Agreement, PBFX provides PBF Holding with terminaling services in return for fees. The Delaware City Truck Loading Agreement has an initial term of approximately ten years, after which PBF Holding has the option to extend the agreement for two additional five year periods, under which PBFX provides loading services to PBF Holding at the Delaware City Terminal. The minimum throughput commitment for the truck rack is at least 30,000 bpd for refined clean products with a fee equal to $0.462 per barrel and at least 5,000 bpd for LPGs with a fee equal to $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 year ended December 31, 2015 , PBF Holding paid PBFX fees of $6,155 , related to the Delaware City Truck Loading Agreement. For the year ended December 31, 2014 , PBF Holding paid PBFX no fees related to the Delaware City Truck Loading Agreement. Third Amended and Restated Omnibus Agreement On May 14, 2014, PBF Holding entered into an Omnibus Agreement (the “Original Omnibus Agreement”) by and among PBFX, PBF GP, PBF LLC and PBF Holding 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 Original Omnibus Agreement addresses the following matters: • PBFX’s obligation to pay PBF Holding, an administrative fee, in the amount of $2,300 per year, for the provision by PBF LLC of centralized corporate services (which fee is in addition to certain expenses of PBF GP and its affiliates that are reimbursed under the First Amended and Restated Agreement of Limited Partnership of PBFX (the “PBFX Partnership Agreement”)); • PBFX’s obligation to reimburse PBF Holding for the salaries and benefits costs of employees who devote more than 50% of their time to PBFX; • PBFX’s agreement to reimburse PBF Holding for all other direct or allocated costs and expenses incurred by PBF LLC on PBFX’s behalf; • PBF LLC’s agreement not to compete with PBFX under certain circumstances, subject to certain exceptions; • PBFX’s right of first offer for ten years to acquire certain logistics assets retained by PBF Energy following the PBFX Offering, including certain logistics assets that PBF LLC or its subsidiaries may construct or acquire in the future, subject to certain exceptions; • a license to use the PBF Logistics trademark and name; and • PBF Holding’s agreement to reimburse PBFX for certain expenditures up to $20,000 per event (net of any insurance recoveries) related to the contributed assets for a period of five years after the closing of the PBFX Offering, and PBFX's agreement to bear the costs associated with the expansion of the DCR Rail Terminal crude unloading capability. The liability arising from this agreement is classified as “Accounts Payable - Affiliate” on the PBF Holding consolidated balance sheet. On September 30, 2014, the Original Omnibus Agreement was amended and restated in connection with the Contribution Agreement II (the “Amended and Restated Omnibus Agreement”). The annual fee payable under the Amended and Restated Omnibus Agreement increased from $2,300 to $2,525 as a result of the inclusion of the DCR West Rack. On December 12, 2014, PBF Holding, PBFX, PBF GP, and PBF LLC entered into a Second Amended and Restated Omnibus Agreement (the “Second A&R Omnibus Agreement”) to amend and restate the Amended and Restated Omnibus Agreement dated as of September 30, 2014, by and among the same parties. The Second A&R Omnibus Agreement clarified the reimbursements to be made by PBFX to BF LLC and from PBF LLC to PBFX. The Second A&R Omnibus Agreement incorporated the Toledo Storage Facility Assets into its provisions and increased the annual administrative fee to be paid by PBFX to PBF Energy from $2,525 to $2,700 . Pursuant to the Omnibus Agreement, as amended, the annual fee of $2,700 per year was reduced to $2,225 per year effective as of January 1, 2015. On May 15, 2015, the Second A&R Omnibus Agreement was amended and restated to include the Delaware City Products Pipeline and Truck Rack (the “Third A&R Omnibus Agreement”). Pursuant to Third A&R Omnibus Agreement, the annual administrative fee was increased to $2,350 per year from $2,225 per year. For the years ended December 31, 2015 and 2014 , PBF Holding received from PBFX $5,216 and $2,174 , respectively, for fees related to the Omnibus Agreement (as amended). 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 (the “Services Agreement”) with PBFX, pursuant to which PBF Holding and its subsidiaries will provide PBFX with the personnel necessary for PBFX to perform its obligations under its commercial agreements. PBFX will reimburse PBF Holding for the use of such employees and the provision of certain infrastructure-related services to the extent applicable to its operations, including storm water discharge and waste water treatment, steam, potable water, access to certain roads and grounds, sanitary sewer access, electrical power, emergency response, filter press, fuel gas, API solids treatment, fire water and compressed air. In addition, PBFX will pay an annual fee of $490 to PBF Holding for the provision of such services pursuant to the Services Agreement. The Services Agreement will terminate upon the termination of the Omnibus Agreement, provided that PBFX may terminate any service on 30 days’ notice. On September 30, 2014, the Services Agreement was amended and restated in connection with the Contribution Agreement II (the “Amended and Restated Services Agreement”). The annual fee payable under the Amended and Restated Services Agreement increased from $490 to $797 (indexed for inflation) as a result of the inclusion of the DCR West Rack. On December 12, 2014, PBF Holding, Delaware City Refining Company LLC, Delaware City Terminaling Company LLC, Toledo Terminaling, Toledo Refining Company LLC, PBFX and PBF GP entered into the Second Amended and Restated Operation and Management Services and Secondment Agreement (the “Second A&R Services Agreement”) to incorporate the Toledo Storage Facility Assets into its provisions and increases the fee to be paid by PBFX to PBF Holding from $797 to $4,400 . On May 15, 2015, the Second A&R Services Agreement was amended and restated in connection with the Delaware City Pipeline and Truck Rack Acquisition (the “Third A&R Services Agreement”) resulting in an increase in the annual fee payable from $4,400 to $4,486 . For the year ended December 31, 2015 and 2014 , PBF Holding received from PBFX $4,455 and $579 , respectively, for fees related to the Services Agreement (as amended). Fuel Strategies International, Inc. Agreement The Company engaged Fuel Strategies International, Inc, the principal of which is the brother of the Executive Chairman of the Board of Directors of PBF Energy, to provide consulting services relating to petroleum coke and commercial operations. For the year ended December 31, 2015 there were no charges under this agreement. For the years ended December 31, 2014 and 2013 , the Company incurred charges of $588 and $646 , respectively, under this agreement. Agreement with the Executive Chairman of the Board of Directors The Company has an agreement with the Executive Chairman of the Board of Directors of PBF Energy, for the use of an airplane that is owned by a company owned by the Executive Chairman of PBF Energy. The Company pays a charter rate that is the lowest rate this aircraft is chartered to third-parties. For the years ended December 31, 2015 , 2014 and 2013 , the Company incurred charges of $957 , $1,214 , and $1,274 , respectively, related to the use of this airplane. Financial Sponsors As of December 31, 2013, each of Blackstone and First Reserve, PBF Energy’s financial sponsors, had received the full return of its aggregate amount invested in PBF LLC Series A Units. As a result, pursuant to the amended and restated limited liability company agreement of PBF LLC, the holders of PBF LLC Series B Units are entitled to an interest in the amounts received by Blackstone and First Reserve in excess of their original investment in the form of PBF LLC distributions and from the shares of PBF Energy Class A Common Stock issuable to Blackstone and First Reserve (for their own account and on behalf of the holders of PBF LLC Series B Units) upon an exchange, and the proceeds from the sale of such shares. Such proceeds received by Blackstone and First Reserve are distributed to the holders of the PBF LLC Series B Units in accordance with the distribution percentages specified in the PBF LLC amended and restated limited liability company agreement. The total amount distributed to the PBF LLC Series B Unit holders for the years ended December 31, 2015 , 2014 and 2013 was $19,592 , $130,523 , and $6,427 respectively. There were no amounts distributed to PBF LLC Series B Unit holders prior to 2013.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 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 $11,198 recorded as of September 30, 2016 ( $10,367 as of December 31, 2015 ) 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, 2016 and December 31, 2015 , 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 connection with the acquisition of the Chalmette refinery, the Company obtained $3,936 in financial assurance (in the form of a surety bond) to cover estimated potential site remediation costs associated with an agreed to Administrative Order of Consent with the EPA. The estimated cost assumes remedial activities will continue for a minimum of 30 years. Further, in connection with the acquisition of the Chalmette refinery, the Company purchased a ten year, $100,000 environmental insurance policy to insure against unknown environmental liabilities at the refinery. In connection with the acquisition of the Torrance refinery and related logistics assets, the Company assumed certain pre-existing environmental liabilities totaling $146,300 as of September 30, 2016 , related to certain environmental remediation obligations to address existing soil and groundwater contamination and monitoring activities, which reflects the current estimated cost of the remediation obligations. The Company expects to make aggregate payments for this liability of $31,402 over the next five years. The current portion of the environmental liability is recorded in Accrued expenses and the non-current portion is recorded in Other long-term liabilities. In addition, in connection with the acquisition of the Torrance refinery and related logistics assets, the Company purchased a ten year, $100,000 environmental insurance policy to insure against unknown environmental liabilities. Furthermore, in connection with the acquisition, the Company assumed responsibility for certain specified environmental matters that occurred prior to the Company’s ownership of the refinery. Specifically, the Company assumed responsibility for (i) a Notice of Violation issued on March 12, 2015 by the Southern California Air Quality Management District (“SCAQMD”) relating to self-reported Title V deviations for the Torrance Refinery for compliance year 2012, (ii) a Notice of Violation issued on March 10, 2016 for self-reported Title V deviations for the Torrance Refinery for compliance year 2013, (iii) a Notice of Violation issued on March 10, 2016 for self-reported Title V deviations for the Torrance Refinery for compliance year 2014 and (iv) a Notice of Violation issued on March 10, 2016 for self-reported Title V deviations for the Torrance Refinery for compliance year 2015. No settlement or penalty demand have been received to date with respect to these Notices. It is possible that SCAQMD will assess penalties in these matters in excess of $100 but any such amount is not expected to be material to the Company, individually or in the aggregate. 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, all of the Northeastern states and Washington DC have adopted sulfur controls on heating oil. Most of the Northeastern states will now require heating oil with 15 PPM or less sulfur by July 1, 2018 (except for Pennsylvania and Maryland - 500 ppm sulfur required). 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 Renewable Fuels Standard (“RFS”) for 2014 no later than November 29, 2013 and for 2015 no later than November 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. The EPA published the final 2014-2016 Renewable standards late in 2015. The EPA essentially set the standards for 2014 and 2015 at the estimated actual renewable fuel used in each year given they were for the most part regulating activities that had already occurred. In setting the 2016 standards the EPA recognized the E10 blend wall and used the general waiver authority to set the 2016 renewable fuel requirement lower than the original requirements stated in the Energy Independence Security Act (“EISA”). These new standards are being challenged by both renewable fuel producers and obligated parties in legal actions. The courts are attempting to consolidate some of these challenges. It appears unlikely the courts will be able resolve these issues before EPA releases the final 2017 standards late in 2016 assuming they stay on schedule. The EPA did propose the 2017 standards in May of 2016 and raised the requirements above the 2016 standards. Estimated 2016 production for the two categories are less than half of what will be needed to satisfy the proposed requirements in 2017. It is not clear that renewable fuel producers will be able to produce the volumes of these fuels required for blending in 2017. There are alternative options that could be used to satisfy these demands but using them will draw down available supply of excess RINs sometimes referred to as the “RIN bank” and will tighten the RIN market potentially raising RIN prices further. Industry organizations have pointed out the issues with the proposal to the EPA in commenting on the proposed standards. The EPA is continuing to receive comments on the new proposal and is targeting to release the final rule by the end of November 2016 as required. The Company is currently evaluating the final standards and they may have a material impact on the Company's cost of compliance with RFS 2. 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. In addition, on December 1, 2015 the EPA finalized revisions to an existing air regulation concerning Maximum Achievable Control Technologies ("MACT") for Petroleum Refineries. The regulation requires additional continuous monitoring systems for eligible process safety valves relieving to atmosphere, minimum flare gas heat (Btu) content, and delayed coke drum vent controls to be installed by January 30, 2019. In addition, a program for ambient fence line monitoring for benzene will need to be implemented by January 30, 2018. The Company is currently evaluating the final standards to evaluate the impact of this regulation, and at this time does not anticipate it will have a material impact on the Company's financial position, results of operations or cash flows. In connection with the closing of the Torrance Acquisition, the Company became subject to greenhouse gas emission control regulations in the state of California to comply with Assembly Bill 32 (“AB 32”). AB 32 created a statewide cap on greenhouse gas emissions, including emissions from transportation fuels, with the aim of returning the state to 1990 emission levels by 2020. AB32 is implemented through two market mechanisms including the Low Carbon Fuel Standard (“LCFS”) and Cap and Trade. The Company is responsible for the AB 32 obligations related to the Torrance refinery beginning on July 1, 2016 and must purchase emission credits to comply with these obligations. Additionally, in September 2016, the state of California enacted Senate Bill 32 (“SB 32”) which further reduces greenhouse gas emissions targets to 40 percent below 1990 levels by 2030. However, subsequent to the acquisition, the Company is recovering the majority of these costs from its customers, and as such does not expect this obligation to materially impact the Company’s financial position, results of operations, or cash flows. To the degree there are unfavorable changes to AB 32 or SB 32 regulations or the Company is unable to recover such compliance costs from customers, these regulations could have a material adverse effect on our financial position, results of operations, and liquidity. The Company is subject to obligations to purchase Renewable Identification Numbers (“RINs”) required to comply with the Renewable Fuels Standard. In late 2015, the Environmental Protection Agency (“EPA”) initiated enforcement proceedings against companies it believes produced invalid RINs. On October 13, 2016, the Company and its subsidiaries including, Toledo Refining Company LLC and Delaware City Refining Company LLC were notified by the EPA that its records indicated that these entities used potentially invalid RINs. The EPA directed each of the subsidiaries to resubmit reports to remove the potentially invalid RINs and to replace the invalid RINs with valid RINs with the same D Code. The Company is in the process of identifying whether any of those RINs are invalid and assessing how the invalid RINs will be replaced, including seeking indemnification from the counterparty who supplied the potentially invalid RINS. While we do not know what actions the EPA will take, or penalties it will impose with respect to these identified RINs or any other RINs we have purchased that the EPA may identify as being invalid, at this time, we do not expect any such action or penalties would have a material effect on our financial condition, results of operations or cash flows. 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 95.2% interest in PBF LLC as of September 30, 2016 ( 95.1% as of December 31, 2015 ). 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.	COMMITMENTS AND CONTINGENCIES Lease and Other Commitments The Company leases office space, office equipment, refinery facilities and equipment, and railcars under non-cancelable operating leases, with terms ranging from one to twenty years, subject to certain renewal options as applicable. Total rent expense was $126,060 , $98,473 , and $70,581 for the years ended December 31, 2015 , 2014 and 2013 , respectively. The Company is party to agreements which provide for the treatment of wastewater and the supply of hydrogen and steam for certain of its refineries. The Company made purchases of $36,139 , $40,444 and $38,383 under these supply agreements for the years ended December 31, 2015 , 2014 and 2013 , respectively. The fixed and determinable amounts of the obligations under these agreements and total minimum future annual rentals, exclusive of related costs, are approximately: Year Ending December 31, 2016 $ 138,890 2017 131,057 2018 122,286 2019 95,397 2020 94,666 Thereafter 237,435 $ 819,731 Employment Agreements PBF Investments (“PBFI”) is party to amended employment agreements with members of executive management and certain other key personnel that include automatic annual renewals, unless canceled. Under some of the agreements, certain of the executives would receive a lump sum payment of between one and a half to 2.99 times their base salary and continuation of certain employee benefits for the same period upon termination by the Company “Without Cause”, or by the employee “For Good Reason”, or upon a “Change in Control”, as defined in the agreements. Upon death or disability, certain of the Company’s executives, or their estates, would receive a lump sum payment of at least one half of their base salary. Environmental Matters The Company’s refineries 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 $10,367 recorded as of December 31, 2015 ( $10,476 as of December 31, 2014 ) represents the present value of expected future costs discounted at a rate of 8% . At December 31, 2015 the undiscounted liability is $15,646 and the Company expects to make aggregate payments for this liability of $5,998 over the next five years . 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 December 31, 2015 and 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 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 connection with the acquisition of the Chalmette refinery, the Company obtained $3,936 in financial assurance (in the form of surety bond) to cover estimated potential site remediation costs associated with an agreed to Administrative Order of Consent with the EPA. The estimated cost assumes remedial activities will continue for a minimum of thirty years. Further, in connection with the acquisition of the Chalmette refinery, the Company purchased a ten year, $100,000 environmental insurance policy to insure against unknown environmental liabilities at the refinery. 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 final standards were issued on November 30, 2015. The standards issued by the EPA include volume requirements in the annual standards which, while below the volumes originally set by Congress, increased renewable fuel use in the U.S. above historical levels and provide for steady growth over time. The EPA also increased the required volume of biomass-based diesel in 2015, 2016, and 2017 while maintaining the opportunity for growth in other advanced biofuels. The Company is currently evaluating the final standards and they may have a material impact on the Company's cost of compliance with RFS 2. 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. In addition, on December 1, 2015 the EPA finalized revisions to an existing air regulation concerning Maximum Achievable Control Technologies (“MACT”) for Petroleum Refineries. The regulation requires additional continuous monitoring systems for eligible process safety valves relieving to atmosphere, minimum flare gas heat (Btu) content, and delayed coke drum vent controls to be installed by January 30, 2019. In addition, a program for ambient fence line monitoring for benzene will need to be implemented by January 30, 2018. The Company is currently evaluating the final standards to evaluate the impact of this regulation, and at this time does not anticipate it will have 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 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 PBF Holding. In general, PBF Energy expects to obtain funding for these annual payments from PBF LLC, primarily through tax distributions, which PBF LLC makes on a pro-rata basis to its owners. Such owners include PBF Energy, which holds a 95.1% and 89.9% interest in PBF LLC as of December 31, 2015 and December 31, 2014 , respectively. 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.

EQUITY STRUCTURE

EQUITY STRUCTURE	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
EQUITY STRUCTURE	EQUITY STRUCTURE PBF Holding has no common stock outstanding. As of December 31, 2015 , 100% of the membership interests of PBF Holding were owned by PBF LLC, and PBF Finance had 100 shares of common stock outstanding, all of which were held by PBF Holding. The following sections represent the equity structure of the Company's indirect and direct parents, PBF Energy and PBF LLC, respectively. Class A Common Stock Holders of Class A common stock are entitled to receive dividends when and if declared by the Board of Directors of PBF Energy out of funds legally available therefore, subject to any statutory or contractual restrictions on the payment of dividends and to any restrictions on the payment of dividends imposed by the terms of any outstanding preferred stock. Upon PBF Energy's dissolution or liquidation or the sale of all or substantially all of the assets, after payment in full of all amounts required to be paid to creditors and to the holders of preferred stock having liquidation preferences, if any, the holders of shares of Class A common stock will be entitled to receive pro rata remaining assets available for distribution. Holders of shares of Class A common stock do not have preemptive, subscription, redemption or conversion rights. Class B Common Stock Holders of shares of Class B common stock are entitled, without regard to the number of shares of Class B common stock held by such holder, to one vote for each PBF LLC Series A Unit beneficially owned by such holder. Accordingly, the the members of PBF LLC other than PBF Energy collectively have a number of votes in PBF Energy that is equal to the aggregate number of PBF LLC Series A Units that they hold. Holders of shares of Class A common stock and Class B common stock vote together as a single class on all matters presented to stockholders for their vote or approval, except as otherwise required by applicable law. Holders of Class B common stock do not have any right to receive dividends or to receive a distribution upon a liquidation or winding up of PBF Energy. Preferred Stock Authorized preferred stock may be issued in one or more series, with designations, powers and preferences as shall be designated by the Board of Directors. PBF LLC Capital Structure PBF LLC Series A Units The allocation of profits and losses and distributions to PBF LLC Series A unit holders is governed by the Limited Liability Company Agreement of PBF LLC. These allocations are made on a pro rata basis with PBF LLC Series C Units. PBF LLC Series A unit holders do not have voting rights. PBF LLC Series B Units The PBF LLC Series B Units are intended to be “profit interests” within the meaning of Revenue Procedures 93-27 and 2001-43 of the Internal Revenue Service and have a stated value of zero at issuance. The PBF LLC Series B Units are held by certain of the Company’s officers, have no voting rights and are designed to increase in value only after the Company’s financial sponsors achieve certain levels of return on their investment in PBF LLC Series A Units. Accordingly, the amounts paid to the holders of PBF LLC Series B Units, if any, will reduce only the amounts otherwise payable to the PBF LLC Series A Units held by the Company’s financial sponsors, and will not reduce or otherwise impact any amounts payable to PBF Energy (the holder of PBF LLC Series C Units), the holders of PBF Energy's Class A common stock or any other holder of PBF LLC Series A Units. The maximum number of PBF LLC Series B Units authorized to be issued is 1,000,000 . PBF LLC Series C Units The PBF LLC Series C Units rank on a parity with the PBF LLC Series A Units as to distribution rights, voting rights and rights upon liquidation, winding up or dissolution. PBF LLC Series C Units are held solely by PBF Energy. Noncontrolling Interest Subsequent to the Chlamette Acquisition, PBF Holding recorded noncontrolling interest in two subsidiaries of Chalmette refinery. PBF Holding, through Chalmette Refining, owns an 80% ownership interest in both Collins Pipeline Company and T&M Terminal Company. The Company recorded earnings related to the noncontrolling interest in these subsidiaries of $274 for the year ended December 31, 2015 .

STOCK-BASED COMPENSATION

STOCK-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
STOCK-BASED COMPENSATION	STOCK-BASED COMPENSATION Stock-based compensation expense included in general and administrative expenses consisted of the following: Years Ended December 31, 2015 2014 2013 PBF LLC Series A Unit compensatory warrants and options $ — $ 522 $ 779 PBF LLC Series B Units — — 530 PBF Energy options 7,528 4,343 2,051 PBF Energy restricted shares 1,690 1,230 393 $ 9,218 $ 6,095 $ 3,753 PBF LLC Series A warrants and options PBF LLC granted compensatory warrants to employees of the Company in connection with their purchase of Series A units in PBF LLC. The warrants grant the holder the right to purchase PBF LLC Series A Units. One-quarter of the PBF LLC Series A compensatory warrants were exercisable at the date of grant and the remaining three-quarters become exercisable over equal annual installments on each of the first three anniversaries of the grant date subject to acceleration in certain circumstances. They are exercisable for ten years from the date of grant. The remaining warrants became fully exercisable in connection with the initial public offering of PBF Energy in December 2012. In addition, options to purchase PBF LLC Series A units were granted to certain employees, management and directors. Options vest over equal annual installments on each of the first three anniversaries of the grant date subject to acceleration in certain circumstances. The options are exercisable for ten years from the date of grant. The Company did not issue PBF LLC Series A Units compensatory warrants or options in 2015 , 2014 or 2013 . The following table summarizes activity for PBF LLC Series A compensatory warrants and options for the years ended December 31, 2015 , 2014 and 2013 : Number of PBF LLC Series A Compensatory Warrants and Options Weighted Average Exercise Price Weighted Average Remaining Contractual Life (in years) Stock Based Compensation, Outstanding at January 1, 2013 1,184,726 $ 10.44 8.23 Exercised (301,979 ) 10.11 — Forfeited (41,668 ) 11.27 — Outstanding at December 31, 2013 841,079 $ 10.52 7.40 Exercised (32,934 ) 10.00 — Forfeited (6,666 ) 11.59 — Outstanding at December 31, 2014 801,479 $ 10.53 6.41 Exercised (160,700 ) 10.28 — Outstanding at December 31, 2015 640,779 $ 10.59 5.46 Exercisable and vested at December 31, 2015 640,779 $ 10.59 5.46 Exercisable and vested at December 31, 2014 753,985 $ 10.41 6.34 Exercisable and vested at December 31, 2013 545,247 $ 10.24 7.23 Expected to vest at December 31, 2015 640,779 $ 10.59 5.46 The total intrinsic value of stock options outstanding and exercisable at December 31, 2015 , was $16,797 , respectively. The total intrinsic value of stock options exercised during the years ended December 31, 2015 , 2014 , and 2013 was $3,452 , $618 , and $4,298 , respectively. There was no unrecognized compensation expense related to PBF LLC Series A warrants and options at December 31, 2015 . Unrecognized compensation expense related to PBF LLC Series A warrants and options at December 31, 2014 was $140 , which was recognized in 2015. Prior to 2014 , members of management of the Company had also purchased an aggregate of 2,740,718 non-compensatory Series A warrants in PBF LLC with an exercise price of $10.00 per unit, all of which were immediately exercisable. During the year ended December 31, 2015 and 2014 , 24,000 and 11,700 non-compensatory warrants were exercised, respectively. At December 31, 2015 and 2014 , there were 32,719 and 56,719 non-compensatory warrants outstanding, respectively. PBF LLC Series B Units PBF LLC Series B Units were issued and allocated to certain members of management during the years ended December 31, 2011 and 2010. One-quarter of the PBF LLC Series B Units vested at the time of grant and the remaining three-quarters vested in equal annual installments on each of the first three anniversaries of the grant date, subject to accelerated vesting upon certain events. The Series B Units fully vested during the year ended December 31, 2013. The following table summarizes activity for PBF LLC Series B Units for the year ended December 31, 2013 : Number of Weighted Non-vested units at January 1, 2013 250,000 $ 5.11 Allocated — — Vested (250,000 ) 5.11 Forfeited — — Non-vested units at December 31, 2013 — $ — PBF Energy options and restricted stock PBF Energy grants awards of its Class A common stock under the 2012 Equity Incentive Plan which authorizes the granting of various stock and stock-related awards to employees, prospective employees and non-employees. Awards include options to purchase shares of Class A common stock and restricted Class A common stock that vest over a period determined by the plan. A total of 1,899,500 and 1,135,000 options to purchase shares of PBF Energy Class A common stock were granted to certain employees and management of the Company in the years ended December 31, 2015 and 2014 , respectively. A total of 247,720 and 30,348 restricted Class A common stock were granted to certain directors, employees and management of the Company as of December 31, 2015 and 2014 , respectively. The PBF Energy options and restricted Class A common stock vest in equal annual installments on each of the first four anniversaries of the grant date subject to acceleration in certain circumstances. The options are exercisable for ten years from the date of grant. The estimated fair value of PBF Energy options granted during the years ended December 31, 2015 , 2014 and 2013 was determined using the Black-Scholes pricing model with the following weighted average assumptions: December 31, 2015 December 31, 2014 December 31, 2013 Expected life (in years) 6.25 6.25 6.25 Expected volatility 38.4 % 52.0 % 52.1 % Dividend yield 3.96 % 4.82 % 4.43 % Risk-free rate of return 1.58 % 1.80 % 1.53 % Exercise price $ 30.28 $ 24.78 $ 27.79 The following table summarizes activity for PBF Energy options for the years ended December 31, 2015 , 2014 and 2013 . Number of Weighted Weighted Stock-based awards, outstanding at January 1, 2013 682,500 $ 26.00 9.95 Granted 697,500 27.79 10.00 Exercised — — — Forfeited (60,000 ) 25.36 — Outstanding at December 31, 2013 1,320,000 $ 26.97 9.33 Granted 1,135,000 24.78 10.00 Exercised — — — Forfeited (53,125 ) 25.44 — Outstanding at December 31, 2014 2,401,875 $ 25.97 8.67 Granted 1,899,500 30.28 10.00 Exercised (30,000 ) 25.79 — Forfeited (15,000 ) 26.38 — Outstanding at December 31, 2015 4,256,375 $ 27.89 8.32 Exercisable and vested at December 31, 2015 1,136,250 $ 26.22 7.61 Exercisable and vested at December 31, 2014 485,000 $ 26.66 8.21 Exercisable and vested at December 31, 2013 158,125 $ 26.00 8.95 Expected to vest at December 31, 2015 4,256,375 $ 27.89 8.23 The total estimated fair value of PBF Energy options granted in 2015 and 2014 was $14,512 and $9,068 and the weighted average per unit fair value was $7.64 and $7.99 . The total intrinsic value of stock options outstanding and exercisable at December 31, 2015 , was $38,167 and $12,139 , respectively. The total intrinsic value of stock options exercised during the year ended December 31, 2015 was $133 . Unrecognized compensation expense related to PBF Energy options at December 31, 2015 was $21,556 , which will be recognized from 2016 through 2019.

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Compensation and Retirement Disclosure [Abstract]
EMPLOYEE BENEFIT PLANS	EMPLOYEE BENEFIT PLANS In August 2016 the Company amended the PBF Energy Pension Plan and the Post Retirement Medical Plan to, among other things, incorporate into the plan all employees who became employed at the Company's California locations on July 1, 2016, in connection with the Torrance Acquisition. The amendments to the plan were effective as of July 1, 2016. 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 2016 2015 2016 2015 Components of net periodic benefit cost: Service cost $ 10,064 $ 5,790 $ 24,743 $ 17,369 Interest cost 772 710 2,323 2,126 Expected return on plan assets (1,234 ) (830 ) (3,447 ) (2,489 ) Amortization of prior service costs 13 13 39 39 Amortization of loss 328 311 716 933 Net periodic benefit cost $ 9,943 $ 5,994 $ 24,374 $ 17,978 Three Months Ended Nine Months Ended Post Retirement Medical Plan 2016 2015 2016 2015 Components of net periodic benefit cost: Service cost $ 304 $ 243 $ 743 $ 731 Interest cost 131 134 398 403 Amortization of prior service costs 161 76 379 228 Amortization of loss — — — — Net periodic benefit cost $ 596 $ 453 $ 1,520 $ 1,362	EMPLOYEE BENEFIT PLANS Defined Contribution Plan The Company’s defined contribution plan covers all employees. Employees are eligible to participate as of the first day of the month following 30 days of service. Participants can make basic contributions up to 50 percent of their annual salary subject to Internal Revenue Service limits. The Company matches participants’ contributions at the rate of 200 percent of the first 3 percent of each participant’s total basic contribution based on the participant’s total annual salary. The Company’s contribution to the qualified defined contribution plans was $12,753 , $11,364 and $10,450 for the years ended December 31, 2015 , 2014 and 2013 , respectively. Defined Benefit and Post-Retirement Medical Plans The Company sponsors a noncontributory defined benefit pension plan (the “Qualified Plan”) with a policy to fund pension liabilities in accordance with the limits imposed by the Employee Retirement Income Security Act of 1974 (“ERISA”) and Federal income tax laws. In addition, the Company sponsors a supplemental pension plan covering certain employees, which provides incremental payments that would have been payable from the Company’s principal pension plan, were it not for limitations imposed by income tax regulations (the “Supplemental Plan”). The funded status is measured as the difference between plan assets at fair value and the projected benefit obligation which is to be recognized in the balance sheet. The plan assets and benefit obligations are measured as of the balance sheet date. The non-union Delaware City employees and all Paulsboro, Toledo and Chalmette employees became eligible to participate in the Company’s defined benefit plans as of the respective acquisition dates. The union Delaware City employees became eligible to participate in the Company’s defined benefit plans upon commencement of normal operations. The Company did not assume any of the employees’ pension liability accrued prior to the respective acquisitions. The Company formed the Post-Retirement Medical Plan on December 31, 2010 to provide health care coverage continuation from date of retirement to age 65 for qualifying employees associated with the Paulsboro acquisition. The Company credited the qualifying employees with their prior service under Valero which resulted in the recognition of a liability for the projected benefit obligation. The Post-Retirement Medical Plan was amended during 2013 to include all corporate employees, amended in 2014 to include Delaware City and Toledo employees and amended in 2015 to include Chalmette employees. The changes in the benefit obligation, the changes in fair value of plan assets, and the funded status of the Company’s Pension and Post-Retirement Medical Plans as of and for the years ended December 31, 2015 and 2014 were as follows: Pension Plans Post-Retirement Medical Plan 2015 2014 2015 2014 Change in benefit obligation: Benefit obligation at beginning of year $ 81,098 $ 53,350 $ 14,740 $ 8,225 Service cost 24,298 19,407 967 1,099 Interest cost 2,974 2,404 558 520 Plan amendments — 529 1,533 3,911 Benefit payments (2,231 ) (2,634 ) (381 ) (215 ) Actuarial loss (gain) (6,128 ) 8,042 312 1,200 Projected benefit obligation at end of year $ 100,011 $ 81,098 $ 17,729 $ 14,740 Change in plan assets: Fair value of plan assets at beginning of year $ 40,956 $ 25,050 $ — $ — Actual return on plan assets (13 ) 1,822 — — Benefits paid (2,231 ) (2,634 ) (381 ) (215 ) Employer contributions 18,790 16,718 381 215 Fair value of plan assets at end of year $ 57,502 $ 40,956 $ — $ — Reconciliation of funded status: Fair value of plan assets at end of year $ 57,502 $ 40,956 $ — $ — Less: benefit obligations at end of year 100,011 81,098 17,729 14,740 Funded status at end of year $ (42,509 ) $ (40,142 ) $ (17,729 ) $ (14,740 ) The accumulated benefit obligations for the Company’s Pension Plans exceed the fair value of the assets of those plans at December 31, 2015 and 2014 . The accumulated benefit obligation for the defined benefit plans approximated $80,897 and $66,576 at December 31, 2015 and 2014 , respectively. Benefit payments, which reflect expected future services, that the Company expects to pay are as follows for the years ended December 31: Pension Benefits Post-Retirement Medical Plan 2016 $ 11,125 $ 843 2017 8,271 1,141 2018 9,403 1,296 2019 10,694 1,580 2020 13,429 1,788 Years 2021-2025 88,044 8,835 The Company’s funding policy for its defined benefit plans is to contribute amounts sufficient to meet legal funding requirements, plus any additional amounts that may be appropriate considering the funded status of the plans, tax consequences, the cash flow generated by the Company and other factors. The Company plans to contribute approximately $16,700 to the Company’s Pension Plans during 2016 . The components of net periodic benefit cost were as follows for the years ended December 31, 2015 , 2014 and 2013 : Pension Benefits Post-Retirement Medical Plan 2015 2014 2013 2015 2014 2013 Components of net period benefit cost: Service cost $ 24,298 $ 19,407 $ 14,794 $ 967 $ 1,099 $ 726 Interest cost 2,974 2,404 992 558 520 334 Expected return on plan assets (3,422 ) (2,156 ) (550 ) — — — Amortization of prior service cost 53 39 11 326 258 — Amortization of actuarial loss (gain) 1,228 1,033 421 — (4 ) — Net periodic benefit cost $ 25,131 $ 20,727 $ 15,668 $ 1,851 $ 1,873 $ 1,060 The pre-tax amounts recognized in other comprehensive income (loss) for the years ended December 31, 2015 , 2014 and 2013 were as follows: Pension Benefits Post-Retirement Medical Plan 2015 2014 2013 2015 2014 2013 Prior service costs (credits) $ — $ 529 $ — $ 1,533 $ 3,911 $ (860 ) Net actuarial loss (gain) (2,220 ) 8,151 8,235 312 1,201 (1,654 ) Amortization of losses and prior service cost (1,281 ) (1,072 ) (432 ) (326 ) (255 ) — Total changes in other comprehensive loss (income) $ (3,501 ) $ 7,608 $ 7,803 $ 1,519 $ 4,857 $ (2,514 ) The pre-tax amounts in accumulated other comprehensive loss as of December 31, 2015 and 2014 that have not yet been recognized as components of net periodic costs were as follows: Pension Benefits Post-Retirement Medical Plan 2015 2014 2015 2014 Prior service (costs) credits $ (529 ) $ (582 ) $ (3,999 ) $ (2,793 ) Net actuarial (loss) gain (19,841 ) (23,762 ) (391 ) (78 ) Total $ (20,370 ) $ (24,344 ) $ (4,390 ) $ (2,871 ) The following pre-tax amounts included in accumulated other comprehensive loss as of December 31, 2015 are expected to be recognized as components of net period benefit cost during the year ended December 31, 2016 : Pension Benefits Post-Retirement Medical Plan Amortization of prior service costs (credits) $ (53 ) $ (436 ) Amortization of net actuarial loss (gain) (775 ) — Total $ (828 ) $ (436 ) Effective December 31, 2015, we changed the method we use to estimate the service and interest components of net periodic benefit cost for the Qualified Plan, the Supplemental Plan and the Post-Retirement Medical Plan. Historically, we estimated these service and interest cost components utilizing a single weighted-average discount rate derived from the yield curve used to measure the benefit obligation for each of these plans at the beginning of the period. Additionally, we historically combined the disclosures of assumptions for the Qualified Plan and the Supplemental Plan in one category we called “Pension Benefits”. We have elected to utilize a full yield curve approach in the estimation of these components by applying the specific spot rates along the yield curve used in the determination of the benefit obligation to the relevant projected cash flows for each plan separately. We have made this change to provide a more precise measurement of service and interest costs by improving the correlation between projected benefit cash flows to the corresponding spot yield curve rates. This change does not affect the measurement of our total benefit obligations or our annual net periodic benefit cost as the change in the service and interest costs is completely offset in the actuarial (gain) loss reported. We have accounted for this change as a change in accounting estimate that is inseparable from a change in accounting principle and accordingly have accounted for it prospectively. The weighted average assumptions used to determine the benefit obligations as of December 31, 2015 and 2014 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2015 2014 2015 2014 2015 2014 Discount rate - Benefit obligations 4.17 % 3.70 % 4.22 % 3.70 % 3.76 % 3.70 % Rate of compensation increase 4.81 % 4.96 % 5.50 % 4.96 % — % — % The weighted average assumptions used to determine the net periodic benefit costs for the years ended December 31, 2015 , 2014 and 2013 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2015 2014 2013 2015 2014 2013 2015 2014 2013 Discount rate: Service Cost 4.25 % 4.55 % 3.45 % 4.30 % 4.55 % 3.45 % 4.32 % 4.55 % 3.45 % Effective rate for interest cost 3.31 % 4.55 % 3.45 % 3.16 % 4.55 % 3.45 % 3.09 % 4.55 % 3.45 % Effective rate for interest on service cost 3.51 % 4.55 % 3.45 % 3.37 % 4.55 % 3.45 % 4.04 % 4.55 % 3.45 % Expected long-term rate of return on plan assets 7.00 % 6.70 % 3.50 % — % — % — % — % — % — % Rate of compensation increase 4.81 % 4.64 % 4.00 % 5.50 % 4.64 % 4.00 % — % — % — % The assumed health care cost trend rates as of December 31, 2015 and 2014 were as follows: Post-Retirement Medical Plan 2015 2014 Health care cost trend rate assumed for next year 6.1 % 6.7 % Rate to which the cost trend rate was assumed to decline (the ultimate trend rate) 4.5 % 4.5 % Year that the rate reached the ultimate trend rate 2038 2027 Assumed health care costs trend rates have a significant effect on the amounts reported for retiree health care plans. A one percentage-point change in assumed health care costs trend rates would have the following effects on the medical post-retirement benefits: 1% Increase 1% Decrease Effect on total of service and interest cost components $ 21 $ (20 ) Effect on accumulated post-retirement benefit obligation 413 (388 ) The tables below present the fair values of the assets of the Company’s Qualified Plan as of December 31, 2015 and 2014 by level of fair value hierarchy. Assets categorized in Level 1 of the hierarchy are measured at fair value using a market approach based on published net asset values of mutual funds. As noted above, the Company’s post retirement medical plan is funded on a pay-as-you-go basis and has no assets. Fair Value Measurements Using Quoted Prices in Active Markets (Level 1) December 31, 2015 2014 Equities: Domestic equities $ 17,660 $ 12,682 Developed international equities 8,320 5,600 Emerging market equities 4,017 2,629 Global low volatility equities 4,930 3,478 Fixed-income 22,495 16,517 Cash and cash equivalents 80 50 Total $ 57,502 $ 40,956 The Company’s investment strategy for its Qualified Plan is to achieve a reasonable return on assets that supports the plan’s interest credit rating, subject to a moderate level of portfolio risk that provides liquidity. Consistent with these financial objectives as of December 31, 2015 , the plan's target allocations for plan assets are 60% invested in equity securities and 40% fixed income investments. Equity securities include international stocks and a blend of U.S. growth and value stocks of various sizes of capitalization. Fixed income securities include bonds and notes issued by the U.S. government and its agencies, corporate bonds, and mortgage-backed securities. The aggregate asset allocation is reviewed on an annual basis. The overall expected long-term rate of return on plan assets for the Qualified Plan is based on the Company’s view of long-term expectations and asset mix.

REVENUES

REVENUES	12 Months Ended
	Dec. 31, 2015
Oil and Gas Revenue [Abstract]
REVENUES	REVENUES The following table provides information relating to the Company’s revenues from external customers for each product or group of similar products for the periods: Year Ended December 31, 2015 2014 2013 Gasoline and distillates $ 11,553,716 $ 17,050,096 $ 16,973,239 Chemicals 452,304 739,096 746,396 Asphalt and blackoils 536,496 706,494 690,305 Lubricants 266,371 410,466 468,315 Feedstocks and other 315,042 922,003 273,200 $ 13,123,929 $ 19,828,155 $ 19,151,455

INCOME TAXES

INCOME TAXES	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 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 generally no benefit or provision for federal or state income tax in the PBF Holding financial statements apart from the income tax attributable to two subsidiaries acquired in connection with the acquisition of Chalmette Refining in the fourth quarter of 2015 and its wholly-owned Canadian subsidiary, PBF Energy Limited ("PBF Ltd."). The two subsidiaries acquired in connection with the Chalmette Acquisition are treated as C-Corporations for income tax purposes. The two acquired subsidiaries incurred $348 and $1,512 of current income tax expense for the three and nine months ended September 30, 2016 , respectively. For the three months ended September 30, 2016 , PBF Holding incurred a current tax expense and deferred tax expense in its income statement of $41 and $1,902 , respectively, attributable to PBF Ltd. For the nine months ended September 30, 2016 , PBF Holding incurred a current tax benefit and deferred tax expense in its income statement of $38 and $27,813 , respectively, attributable to PBF Ltd. During the preparation of the financial statements for the first quarter of 2016, management determined that the deferred income tax liabilities for PBF Ltd. were understated for prior periods. As of and for the three months ended March 31, 2016, the Company incurred $30,602 of deferred tax expense and $121 of current tax expense relating to a correction of prior periods which increased the recorded deferred and current tax liabilities by $30,602 and $121 , respectively. This correction of prior periods did not impact the results for the third quarter of 2016.	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 apart from the income tax attributable to two subsidiaries of Chalmette Refining that are treated as C-Corporations for income tax purposes. These two subsidiaries incurred $648 of income taxes for the period from their acquisition on November 1, 2015 through December 31, 2015.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 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, 2016 and December 31, 2015 . 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, 2016 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 $ 307,508 $ — $ — $ 307,508 N/A $ 307,508 Commodity contracts 24,086 10,440 382 34,908 (30,065 ) 4,843 Derivatives included with inventory intermediation agreement obligations — 6,194 — 6,194 — 6,194 Liabilities: Commodity contracts 26,618 3,447 — 30,065 (30,065 ) — Catalyst lease obligations — 44,286 — 44,286 — 44,286 As of December 31, 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 $ 631,280 $ — $ — $ 631,280 N/A $ 631,280 Commodity contracts 63,810 31,256 3,543 98,609 (52,482 ) 46,127 Derivatives included with inventory intermediation agreement obligations — 35,511 — 35,511 — 35,511 Liabilities: Commodity contracts 49,960 2,522 — 52,482 (52,482 ) — Catalyst lease obligations — 31,802 — 31,802 — 31,802 The valuation methods used to measure financial instruments at fair value are as follows: • Money market funds categorized in Level 1 of the fair value hierarchy are measured at fair value based on quoted market prices and included within Cash and cash equivalents. • The commodity contracts categorized in Level 1 of the fair value hierarchy are measured at fair value based on quoted prices in an active market. The commodity contracts categorized in Level 2 of the fair value hierarchy are measured at fair value using a market approach based upon future commodity prices for similar instruments quoted in active markets. • The 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. Non-qualified pension plan assets are measured at fair value using a market approach based on published net asset values of mutual funds as a practical expedient. As of September 30, 2016 and December 31, 2015 , $9,773 and $9,325 , respectively, were included within Deferred charges and other assets, net for these non-qualified pension plan assets. The table below summarizes the changes in fair value measurements categorized in Level 3 of the fair value hierarchy: Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Balance at beginning of period $ 493 $ 1,905 $ 3,543 $ 1,521 Purchases — — — — Settlements (90 ) (1,238 ) (1,093 ) (12,549 ) Unrealized (loss) gain included in earnings (21 ) (852 ) (2,068 ) 10,843 Transfers into Level 3 — — — — Transfers out of Level 3 — — — — Balance at end of period $ 382 $ (185 ) $ 382 $ (185 ) There were no transfers between levels during the three and nine months ended September 30, 2016 and 2015 , respectively. Fair value of debt The table below summarizes the fair value and carrying value of debt as of September 30, 2016 and December 31, 2015 . September 30, 2016 December 31, 2015 Carrying value Fair value Carrying value Fair value Senior Secured Notes due 2020 (a) $ 670,551 $ 697,649 $ 669,644 $ 706,246 Revolving Loan (b) 550,000 550,000 — — Senior Secured Notes due 2023 (a) 500,000 475,031 500,000 492,452 Rail Facility (b) 56,035 56,035 67,491 67,491 Catalyst leases (c) 44,286 44,286 31,802 31,802 1,820,872 1,823,001 1,268,937 1,297,991 Less - Current maturities — — — — Less - Unamortized deferred financing costs 26,505 n/a 32,217 n/a Long-term debt $ 1,794,367 $ 1,823,001 $ 1,236,720 $ 1,297,991 (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.	FAIR VALUE MEASUREMENTS The tables below present information about the Company's financial assets and liabilities measured and recorded at fair value on a recurring basis and indicate the fair value hierarchy of the inputs utilized to determine the fair values as of December 31, 2015 and 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 December 31, 2015 Fair Value Hierarchy Level 1 Level 2 Level 3 Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Assets: Money market funds $ 631,280 $ — $ — $ 631,280 N/A $ 631,280 Non-qualified pension plan assets 9,325 — — 9,325 N/A 9,325 Commodity contracts 63,810 31,256 3,543 98,609 (52,482 ) 46,127 Derivatives included with inventory supply arrangement obligations — 35,511 — 35,511 — 35,511 Liabilities: Commodity contracts 49,960 2,522 — 52,482 (52,482 ) — Catalyst lease obligations — 31,802 — 31,802 — 31,802 As of December 31, 2014 Level 1 Level 2 Level 3 Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Assets: Money market funds $ 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 arrangement — 94,834 — 94,834 — 94,834 Derivatives included with inventory supply arrangement obligations — 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 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 price used to value these swaps was 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 of commodity contracts categorized in Level 3 of the fair value hierarchy: Year Ended December 31, 2015 2014 Balance at beginning of period $ 1,521 $ (23,365 ) Purchases — — Settlements (15,222 ) (22,055 ) Unrealized loss included in earnings 17,244 46,941 Transfers into Level 3 — — Transfers out of Level 3 — — Balance at end of period $ 3,543 $ 1,521 There were no transfers between levels during the years ended December 31, 2015 and 2014 , respectively. Fair value of debt The table below summarizes the fair value and carrying value as of December 31, 2015 and 2014 . December 31, 2015 December 31, 2014 Carrying value Fair value Carrying value Fair value Senior Secured Notes due 2020 (a) $ 669,644 $ 706,246 $ 668,520 $ 675,580 Senior Secured Notes due 2023 (a) 500,000 492,452 — — Revolving Loan (b) — — — — Rail Facility (b) 67,491 67,491 37,270 37,270 Catalyst leases (c) 31,802 31,802 36,559 36,559 1,268,937 1,297,991 742,349 749,409 Less - Current maturities — — — — Less - Unamortized deferred financing costs $ 32,217 n/a $ 30,128 n/a Long-term debt $ 1,236,720 $ 1,297,991 $ 712,221 $ 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	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVES	DERIVATIVES The Company uses derivative instruments to mitigate certain exposures to commodity price risk. Prior to December 31, 2015, the Company’s crude supply agreement contained 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, 2016 , there were no barrels of crude oil and feedstocks ( no barrels at December 31, 2015 ) outstanding under these derivative instruments designated as fair value hedges and no barrels ( no barrels at December 31, 2015 ) outstanding under these derivative instruments not designated as hedges. As of September 30, 2016 , there were 3,284,395 barrels of intermediates and refined products ( 3,776,011 barrels at December 31, 2015 ) outstanding under these derivative instruments designated as fair value hedges and no barrels ( no barrels at December 31, 2015 ) 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, 2016 , there were 22,482,500 barrels of crude oil and 8,927,000 barrels of refined products ( 39,577,000 and 4,599,136 , respectively, as of December 31, 2015 ), 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, 2016 and December 31, 2015 and the line items in the condensed 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, 2016: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 6,194 December 31, 2015: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 35,511 Derivatives not designated as hedging instruments: September 30, 2016: Commodity contracts Accounts receivable $ 4,843 December 31, 2015: Commodity contracts Accounts receivable $ 46,127 The following table provides information about the gain or loss recognized in income on these derivative instruments and the line items in the condensed 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, 2016: Derivatives included with the inventory intermediation agreement obligations Cost of sales $ (3,145 ) For the three months ended September 30, 2015: Derivatives included with inventory supply arrangement obligations Cost of sales $ 1,409 Derivatives included with the inventory intermediation agreement obligations Cost of sales $ 34,424 For the nine months ended September 30, 2016: Derivatives included with the inventory intermediation agreement obligations Cost of sales $ (29,317 ) For the nine months ended September 30, 2015: Derivatives included with inventory supply arrangement obligations Cost of sales $ (3,220 ) Derivatives included with the inventory intermediation agreement obligations Cost of sales $ (50,150 ) Derivatives not designated as hedging instruments: For the three months ended September 30, 2016: Commodity contracts Cost of sales $ (15,559 ) For the three months ended September 30, 2015: Commodity contracts Cost of sales $ 31,017 For the nine months ended September 30, 2016: Commodity contracts Cost of sales $ (54,646 ) For the nine months ended September 30, 2015: Commodity contracts Cost of sales $ (14,080 ) Hedged items designated in fair value hedges: For the three months ended September 30, 2016: Intermediate and refined product inventory Cost of sales $ 3,145 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 nine months ended September 30, 2016: Intermediate and refined product inventory Cost of sales $ 29,317 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 The Company had no ineffectiveness related to the Company's fair value hedges for the three and nine months ended September 30, 2016 and 2015 .	DERIVATIVES The Company uses derivative instruments to mitigate certain exposures to commodity price risk. The Company’s crude supply agreements contained purchase obligations for certain volumes of crude oil and other feedstocks. In addition, the Company entered into Inventory Intermediation Agreements 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 December 31, 2015 , there were no 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 December 31, 2015 , there were 3,776,011 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 December 31, 2015 , there were 39,577,000 barrels of crude oil and 4,599,136 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 December 31, 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: December 31, 2015: Derivatives included with inventory supply arrangement obligations Accrued expenses $ — Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 35,511 December 31, 2014: Derivatives included with inventory supply arrangement obligations Accrued expenses $ 4,251 Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 94,834 Derivatives not designated as hedging instruments: December 31, 2015: Commodity contracts Accounts receivable $ 46,127 December 31, 2014: Commodity contracts Accounts receivable $ 31,155 The following tables provide information about the gains or losses 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 year ended December 31, 2015: Derivatives included with inventory supply arrangement obligations Cost of sales $ (4,251 ) Derivatives included with the inventory intermediation agreement obligations Cost of sales $ (59,323 ) For the year ended December 31, 2014: Derivatives included with inventory supply arrangement obligations Cost of sales $ 4,428 Derivatives included with the inventory intermediation agreement obligations Cost of sales $ 88,818 For the year ended December 31, 2013 Derivatives included with inventory supply arrangement obligations Cost of sales $ (5,773 ) Derivatives included with the inventory intermediation agreement obligations Cost of sales $ 6,016 Derivatives not designated as hedging instruments: For the year ended December 31, 2015: Commodity contracts Cost of sales $ 32,416 For the year ended December 31, 2014: Commodity contracts Cost of sales $ 146,016 For the year ended December 31, 2013 Commodity contracts Cost of sales $ (88,962 ) Hedged items designated in fair value hedges: For the year ended December 31, 2015: Crude oil and feedstock inventory Cost of sales $ 4,251 Intermediate and refined product inventory Cost of sales $ 59,323 For the year ended December 31, 2014: Crude oil and feedstock inventory Cost of sales $ (4,428 ) Intermediate and refined product inventory Cost of sales $ (88,818 ) For the year ended December 31, 2013 Crude oil and feedstock inventory Cost of sales $ (1,491 ) Intermediate and refined product inventory Cost of sales $ (6,016 ) The Company had no ineffectiveness related to the fair value hedges as of December 31, 2015 and 2014 . Ineffectiveness related to the Company's fair value hedges resulted in a loss of $7,264 for the year ended December 31 2013 , recorded in cost of sales. Gains and losses due to ineffectiveness, resulting from the difference in the forward and spot rates of the underlying crude inventory related to the derivatives included with inventory supply arrangement obligations, were excluded from the assessment of hedge effectiveness.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS Catalyst Leases On October 18, 2016, the Company entered into two precious metals leases covering the platinum and palladium catalyst used at its Delaware City refinery. Each lease has a term of three years and will replace two existing precious metals leases that expired on October 21, 2016. The platinum catalyst lease has a fixed interest rate of 1.95% per annum (360 day basis) and annual lease payments of $ 210 . The palladium catalyst lease has a fixed interest rate of 2.05% % per annum (360 day basis) and annual lease payments of $ 30 . On November 4, 2016, the Company entered into a new precious metals lease covering the platinum catalyst used at its Chalmette refinery. The Chalmette catalyst lease has a term of three years, a fixed interest rate of 2.20% per annum (360 day basis), and quarterly lease payments of $43 . Distributions On October 28, 2016, 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 22, 2016 to PBF Energy Class A common stockholders of record at the close of business on November 8, 2016. PBF Holding intends to make a distribution of approximately $30,839 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 stockholders of PBF Energy.	SUBSEQUENT EVENTS Dividend Declared On February 11, 2016, PBF Energy, PBF Holding's indirect parent, announced a dividend of $0.30 per share on outstanding Class A common stock. The dividend was paid on March 8, 2016 to Class A common stockholders of record at the close of business on February 22, 2016. PBF Holding made a distribution of $30,829 to PBF LLC, which in turn made pro-rata distributions to its members, including PBF Energy. PBF Energy then used this distribution to fund the dividend payments to shareholders of PBF Energy.

CONSOLIDATING FINANCIAL STATEME

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Condensed Financial Information of Subsidiary Disclosure [Abstract]
CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS	CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING As of September 30, 2016 , PBF Services Company, Delaware City Refining Company LLC, PBF Power Marketing LLC, Paulsboro Refining Company LLC, Paulsboro Natural Gas Pipeline Company LLC, Toledo Refining Company LLC, Chalmette Refining, L.L.C., PBF Western Region LLC, Torrance Refining Company LLC, Torrance Logistics Company LLC and PBF Investments 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 indentures dated February 9, 2012 and November 24, 2015, among PBF Holding, PBF Finance, the guarantors party thereto and Wilmington Trust, National Association, governs subsidiaries designated as "Guarantor Subsidiaries." PBF Energy Limited, PBF Transportation Company LLC, PBF Rail Logistics Company LLC, MOEM Pipeline LLC, Collins Pipeline Company, T&M Terminal Company, TVPC Holding Company LLC ("TVP Holding"), Torrance Basin Pipeline Company LLC and Torrance Pipeline Company LLC are consolidated subsidiaries of the Company that are not guarantors of the Senior Secured Notes. Additionally, our 50% equity investment in Torrance Valley Pipeline Company, held by TVP Holding is included in our Non-Guarantor financial position and results of operations and cash flows as TVP Holding is not a guarantor 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 the 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 and the Guarantor subsidiaries' investments in their subsidiaries are accounted for under the equity method of accounting. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) September 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 456,179 $ 20,531 $ 44,534 $ (1,869 ) $ 519,375 Accounts receivable 636,625 7,362 5,670 — 649,657 Accounts receivable - affiliate 21 — 3,020 — 3,041 Inventories 1,640,072 — 205,523 — 1,845,595 Prepaid expense and other current assets 30,573 22,026 2,491 — 55,090 Due from related parties 23,111,940 21,567,312 4,215,051 (48,894,303 ) — Total current assets 25,875,410 21,617,231 4,476,289 (48,896,172 ) 3,072,758 Property, plant and equipment, net 34,647 2,303,359 321,377 — 2,659,383 Investment in subsidiaries 1,072,153 605,169 — (1,677,322 ) — Investment in equity method investee — — 176,267 — 176,267 Deferred charges and other assets, net 31,696 416,062 1,513 — 449,271 Total assets $ 27,013,906 $ 24,941,821 $ 4,975,446 $ (50,573,494 ) $ 6,357,679 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 234,062 $ 133,195 $ 2,441 $ (1,869 ) $ 367,829 Accounts payable - affiliate 31,746 — — — 31,746 Accrued expenses 1,240,409 160,036 121,043 — 1,521,488 Deferred tax liabilities — — 27,989 — 27,989 Deferred revenue 10,602 — 1,470 — 12,072 Due to related parties 21,414,670 23,247,282 4,232,351 (48,894,303 ) — Total current liabilities 22,931,489 23,540,513 4,385,294 (48,896,172 ) 1,961,124 Delaware Economic Development Authority loan — 4,000 — — 4,000 Long-term debt 1,694,390 44,219 55,758 — 1,794,367 Affiliate notes payable 470,165 — — — 470,165 Deferred tax liabilities — — 25,721 — 25,721 Other long-term liabilities 29,195 176,821 7,619 — 213,635 Total liabilities 25,125,239 23,765,553 4,474,392 (48,896,172 ) 4,469,012 Commitments and contingencies Equity: Member's equity 1,494,477 1,733,830 433,421 (2,167,251 ) 1,494,477 Retained earnings (accumulated deficit) 404,777 (562,045 ) 67,633 494,412 404,777 Accumulated other comprehensive (loss) income (23,307 ) (8,237 ) — 8,237 (23,307 ) Total PBF Holding Company LLC equity 1,875,947 1,163,548 501,054 (1,664,602 ) 1,875,947 Noncontrolling interest 12,720 12,720 — (12,720 ) 12,720 Total equity 1,888,667 1,176,268 501,054 (1,677,322 ) 1,888,667 Total liabilities and equity $ 27,013,906 $ 24,941,821 $ 4,975,446 $ (50,573,494 ) $ 6,357,679 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) December 31, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 882,820 $ 6,236 $ 28,968 $ (3,275 ) $ 914,749 Accounts receivable 430,809 11,057 12,893 — 454,759 Accounts receivable - affiliate 917 2,521 — — 3,438 Inventories 608,646 363,151 202,475 — 1,174,272 Prepaid expense and other current assets 24,243 9,074 384 — 33,701 Due from related parties 20,236,649 20,547,503 3,262,382 (44,046,534 ) — Total current assets 22,184,084 20,939,542 3,507,102 (44,049,809 ) 2,580,919 Property, plant and equipment, net 25,240 1,960,066 225,784 — 2,211,090 Investment in subsidiaries 1,740,111 143,349 — (1,883,460 ) — Investment in equity method investee — — — — — Deferred charges and other assets, net 23,973 265,240 1,500 — 290,713 Due from related party - long term — — 20,577 (20,577 ) — Total assets $ 23,973,408 $ 23,308,197 $ 3,754,963 $ (45,953,846 ) $ 5,082,722 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 196,988 $ 113,564 $ 7,566 $ (3,275 ) $ 314,843 Accounts Payable - affiliate 23,949 — — — 23,949 Accrued expenses 503,179 495,842 118,414 — 1,117,435 Deferred revenue 4,043 — — — 4,043 Due to related parties 19,787,807 21,026,310 3,232,417 (44,046,534 ) — Total current liabilities 20,515,966 21,635,716 3,358,397 (44,049,809 ) 1,460,270 Delaware Economic Development Authority loan — 4,000 — — 4,000 Long-term debt 1,137,980 31,717 67,023 — 1,236,720 Affiliate notes payable 470,047 — — — 470,047 Deferred tax liability — — 20,577 — 20,577 Other long-term liabilities 28,131 41,693 — — 69,824 Due to related party - long term — 20,577 — (20,577 ) — Total liabilities 22,152,124 21,733,703 3,445,997 (44,070,386 ) 3,261,438 Commitments and contingencies Equity: Member's equity 1,479,175 1,062,717 182,696 (1,245,413 ) 1,479,175 Retained earnings (accumulated deficit) 349,654 502,788 126,270 (629,058 ) 349,654 Accumulated other comprehensive (loss) income (24,770 ) (8,236 ) — 8,236 (24,770 ) Total PBF Holding Company LLC equity 1,804,059 1,557,269 308,966 (1,866,235 ) 1,804,059 Noncontrolling interest 17,225 17,225 — (17,225 ) 17,225 Total equity 1,821,284 1,574,494 308,966 (1,883,460 ) 1,821,284 Total liabilities and equity $ 23,973,408 $ 23,308,197 $ 3,754,963 $ (45,953,846 ) $ 5,082,722 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Three Months Ended September 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 4,488,925 $ 441,554 $ 345,215 $ (767,081 ) $ 4,508,613 Costs and expenses Cost of sales, excluding depreciation 3,914,018 428,587 328,734 (767,081 ) 3,904,258 Operating expenses, excluding depreciation 25 385,761 18,259 — 404,045 General and administrative expenses 34,820 4,312 780 — 39,912 Equity (income) loss in investee — — (1,621 ) — (1,621 ) Loss (gain) on sale of assets 2,418 73 5,668 — 8,159 Depreciation and amortization expense 1,341 47,472 3,865 — 52,678 3,952,622 866,205 355,685 (767,081 ) 4,407,431 Income (loss) from operations 536,303 (424,651 ) (10,470 ) — 101,182 Other income (expense) Equity in (loss) earnings of subsidiaries (438,249 ) — — 438,249 — Change in fair value of catalyst lease — 77 — — 77 Interest expense, net (32,982 ) (447 ) (467 ) — (33,896 ) Net income (loss) before income taxes 65,072 (425,021 ) (10,937 ) 438,249 67,363 Income tax (benefit) expense — — 2,291 — 2,291 Net income (loss) 65,072 (425,021 ) (13,228 ) 438,249 65,072 Less: net income (loss) attributable to noncontrolling interest 45 45 — (45 ) 45 Net income (loss) attributable to PBF Holding Company LLC $ 65,027 $ (425,066 ) $ (13,228 ) $ 438,294 $ 65,027 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 65,453 $ (425,066 ) $ (13,228 ) $ 438,294 $ 65,453 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Three Months Ended September 30, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 3,215,163 $ 132,000 $ 422,306 $ (551,829 ) $ 3,217,640 Costs and expenses Cost of sales, excluding depreciation 2,843,303 176,823 390,112 (551,829 ) 2,858,409 Operating expenses, excluding depreciation (95 ) 200,384 (275 ) — 200,014 General and administrative expenses 40,002 6,827 973 — 47,802 Equity (income) loss in investee — — — — — Gain on sale of assets (70 ) 1 (73 ) — (142 ) Depreciation and amortization expense 2,117 43,820 547 — 46,484 2,885,257 427,855 391,284 (551,829 ) 3,152,567 Income (loss) from operations 329,906 (295,855 ) 31,022 — 65,073 Other income (expense) Equity in (loss) earnings of subsidiaries (262,000 ) — — 262,000 — Change in fair value of catalyst lease — 4,994 — — 4,994 Interest expense, net (19,727 ) (1,277 ) (884 ) — (21,888 ) Net income (loss) before income taxes 48,179 (292,138 ) 30,138 262,000 48,179 Income taxes expense — — — — — Net income (loss) 48,179 (292,138 ) 30,138 262,000 48,179 Less: net income attributable to noncontrolling interest — — — — — Net income (loss) attributable to PBF Holding Company LLC $ 48,179 $ (292,138 ) $ 30,138 $ 262,000 $ 48,179 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 48,698 $ (292,138 ) $ 30,138 $ 262,000 $ 48,698 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Nine Months Ended September 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 11,119,301 $ 586,336 $ 1,005,656 $ (1,546,722 ) $ 11,164,571 Costs and expenses Cost of sales, excluding depreciation 9,653,945 532,040 995,726 (1,546,722 ) 9,634,989 Operating expenses, excluding depreciation (375 ) 948,403 24,195 — 972,223 General and administrative expenses 92,126 20,372 (1,226 ) — 111,272 Equity (income) loss in investee — — (1,621 ) — (1,621 ) Loss on sale of assets 2,418 97 8,866 — 11,381 Depreciation and amortization expense 4,417 143,994 7,479 — 155,890 9,752,531 1,644,906 1,033,419 (1,546,722 ) 10,884,134 Income (loss) from operations 1,366,770 (1,058,570 ) (27,763 ) — 280,437 Other income (expense) Equity in (loss) earnings of subsidiaries (1,123,054 ) — — 1,123,054 — Change in fair value of catalyst lease — (4,556 ) — — (4,556 ) Interest expense, net (95,568 ) (1,289 ) (1,589 ) — (98,446 ) Net income (loss) before income taxes 148,148 (1,064,415 ) (29,352 ) 1,123,054 177,435 Income taxes expense — — 29,287 — 29,287 Net income (loss) 148,148 (1,064,415 ) (58,639 ) 1,123,054 148,148 Less: net income attributable to noncontrolling interest 438 438 — (438 ) 438 Net income (loss) attributable to PBF Holding Company LLC $ 147,710 $ (1,064,853 ) $ (58,639 ) $ 1,123,492 $ 147,710 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 149,173 $ (1,064,853 ) $ (58,639 ) $ 1,123,492 $ 149,173 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Nine Months Ended September 30, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 9,737,169 $ 668,576 $ 1,250,957 $ (1,893,262 ) $ 9,763,440 Costs and expenses Cost of sales, excluding depreciation 8,370,720 749,706 1,187,259 (1,893,262 ) 8,414,423 Operating expenses, excluding depreciation (3,814 ) 629,846 (490 ) — 625,542 General and administrative expenses 98,330 15,987 1,798 — 116,115 Equity (income) loss in investee — — — — — Gain on sale of assets (251 ) (232 ) (650 ) — (1,133 ) Depreciation and amortization expense 7,664 130,496 1,597 — 139,757 8,472,649 1,525,803 1,189,514 (1,893,262 ) 9,294,704 Income (loss) from operations 1,264,520 (857,227 ) 61,443 — 468,736 Other income (expense) Equity in earnings (loss) of subsidiaries (793,606 ) — — 793,606 — Change in fair value of catalyst lease — 8,982 — — 8,982 Interest expense, net (59,111 ) (4,342 ) (2,462 ) — (65,915 ) Net income (loss) before income taxes 411,803 (852,587 ) 58,981 793,606 411,803 Income taxes expense — — — — — Net income (loss) 411,803 (852,587 ) 58,981 793,606 411,803 Less: net income attributable to noncontrolling interest — — — — — Net income (loss) attributable to PBF Holding Company LLC $ 411,803 $ (852,587 ) $ 58,981 $ 793,606 $ 411,803 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 413,118 $ (852,587 ) $ 58,981 $ 793,606 $ 413,118 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF CASH FLOW (UNAUDITED) Nine Months Ended September 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 148,148 $ (1,064,415 ) $ (58,639 ) $ 1,123,054 $ 148,148 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 10,828 144,011 7,726 — 162,565 Stock-based compensation — 12,658 — — 12,658 Change in fair value of catalyst lease obligations — 4,556 — — 4,556 Deferred income taxes — — 27,813 — 27,813 Change in non-cash lower of cost or market inventory adjustment (320,833 ) — — — (320,833 ) Non-cash change in inventory repurchase obligations 29,317 — — — 29,317 Pension and other post retirement benefit costs 5,249 20,645 — — 25,894 Loss (gain) on sale of assets 2,418 97 8,866 — 11,381 Equity in earnings of subsidiaries 1,123,054 — — (1,123,054 ) — Equity (income) loss in investee — — (1,621 ) — (1,621 ) Changes in current assets and current liabilities: Accounts receivable (205,816 ) 3,695 7,223 — (194,898 ) Due to/from affiliates (1,624,741 ) 1,588,690 44,245 — 8,194 Inventories 56,792 — (2,740 ) — 54,052 Prepaid expenses and other current assets (6,330 ) (11,768 ) (2,105 ) — (20,203 ) Accounts payable 37,074 16,943 (5,126 ) 1,406 50,297 Accrued expenses 661,974 (353,030 ) (897 ) — 308,047 Deferred revenue 6,559 — 1,470 — 8,029 Other assets and liabilities (7,573 ) (14,210 ) (97 ) — (21,880 ) Net cash (used in) provided by operating activities (83,880 ) 347,872 26,118 1,406 291,516 Cash flows from investing activities: Acquisition of Torrance refinery and related logistics assets (971,932 ) — — — (971,932 ) Expenditures for property, plant and equipment (16,244 ) (172,174 ) 675 — (187,743 ) Expenditures for deferred turnaround costs — (138,936 ) — — (138,936 ) Expenditures for other assets — (27,735 ) — — (27,735 ) Investment in subsidiaries 12,800 — — (12,800 ) — Chalmette Acquisition working capital settlement — (2,659 ) — — (2,659 ) Proceeds from sale of assets — — 13,030 — 13,030 Net cash provided by (used in) investing activities (975,376 ) (341,504 ) 13,705 (12,800 ) (1,315,975 ) Cash flows from financing activities: Proceeds from catalyst lease — 7,927 — — 7,927 Contributions from PBF LLC related to TVPC 175,000 — — — 175,000 Distribution to Parent — — (12,800 ) 12,800 — Distribution to members (92,503 ) — — — (92,503 ) Proceeds from affiliate notes payable 635 — — — 635 Repayments of affiliate notes payable (517 ) — — — (517 ) Proceeds from revolver borrowings 550,000 — — — 550,000 Repayments of Rail Facility revolver borrowings — — (11,457 ) — (11,457 ) Net cash provided by (used in) financing activities 632,615 7,927 (24,257 ) 12,800 629,085 Net increase in cash and cash equivalents (426,641 ) 14,295 15,566 1,406 (395,374 ) Cash and cash equivalents, beginning of period 882,820 6,236 28,968 (3,275 ) 914,749 Cash and cash equivalents, end of period $ 456,179 $ 20,531 $ 44,534 $ (1,869 ) $ 519,375 14. 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 from 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 ) Non-cash change in inventory repurchase obligations — 53,370 — — 53,370 Change in non-cash lower of cost of market inventory adjustment (2,091 ) 83,238 — — 81,147 Pension and other post retirement benefit costs 5,769 13,571 — — 19,340 Equity income in investee — — — — — Gain on sale of assets (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 refinery turnarounds 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 provided by (used in) 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 ) — Distributions to Parent — — (10,000 ) 10,000 — Proceeds from affiliate notes payable 29,773 — — — 29,773 Proceeds from Rail Facility revolver borrowings — — 102,075 — 102,075 Repayments of Rail Facility revolver borrowing — — (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 cash equivalents, beginning of period 185,381 704 34,334 (2,016 ) 218,403 Cash and cash equivalents, end of period $ 361,037 $ 3 $ 10,231 $ (1,850 ) $ 369,421	CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING PBF Services Company, Delaware City Refining Company LLC, PBF Power Marketing LLC, Paulsboro Refining Company LLC, Paulsboro Natural Gas Pipeline Company LLC, Toledo Refining Company LLC, Chalmette Refining, L.L.C. and PBF Investments 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 indentures dated February 9, 2012 and November 24, 2015, among PBF Holding, PBF Finance, the guarantors party thereto and Wilmington Trust, National Association, governs subsidiaries designated as “Guarantor Subsidiaries”. PBF Energy Limited, PBF Transportation Company LLC, PBF Rail Logistics Company LLC, MOEM Pipeline LLC, Collins Pipeline Company and T&M Terminal Company 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 consolidating financial information reflects the Issuer’s separate accounts, the combined accounts of the 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 investments in its subsidiaries and the Guarantor Subsidiaries’ investments in its subsidiaries are accounted for under the equity method of accounting. . CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING BALANCE SHEET December 31, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 882,820 $ 6,236 $ 28,968 $ (3,275 ) $ 914,749 Accounts receivable 430,809 11,057 12,893 — 454,759 Accounts receivable - affiliate 917 2,521 — — 3,438 Inventories 608,646 363,151 202,475 — 1,174,272 Prepaid expense and other current assets 24,243 9,074 384 — 33,701 Due from related parties 20,236,649 20,547,503 3,262,382 (44,046,534 ) — Total current assets 22,184,084 20,939,542 3,507,102 (44,049,809 ) 2,580,919 Property, plant and equipment, net 25,240 1,960,066 225,784 — 2,211,090 Investment in subsidiaries 1,740,111 143,349 — (1,883,460 ) — Deferred charges and other assets, net 23,973 265,240 1,500 — 290,713 Due from related party - long term — — 20,577 (20,577 ) — Total assets $ 23,973,408 $ 23,308,197 $ 3,754,963 $ (45,953,846 ) $ 5,082,722 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 196,988 $ 113,564 $ 7,566 $ (3,275 ) $ 314,843 Accounts payable - affiliate 23,949 — — — 23,949 Accrued expenses 503,179 495,842 118,414 — 1,117,435 Current portion of long-term debt — — — — — Deferred revenue 4,043 — — — 4,043 Due to related parties 19,787,807 21,026,310 3,232,417 (44,046,534 ) — Total current liabilities 20,515,966 21,635,716 3,358,397 (44,049,809 ) 1,460,270 Delaware Economic Development Authority loan — 4,000 — — 4,000 Long-term debt 1,137,980 31,717 67,023 — 1,236,720 Intercompany notes payable 470,047 — — — 470,047 Deferred tax liability — — 20,577 — 20,577 Other long-term liabilities 28,131 41,693 — — 69,824 Due to related party - long term — 20,577 — (20,577 ) — Total liabilities 22,152,124 21,733,703 3,445,997 (44,070,386 ) 3,261,438 Commitments and contingencies Equity: Member's equity 1,479,175 1,062,717 182,696 (1,245,413 ) 1,479,175 Retained earnings 349,654 502,788 126,270 (629,058 ) 349,654 Accumulated other comprehensive loss (24,770 ) (8,236 ) — 8,236 (24,770 ) Total PBF Holding Company LLC equity 1,804,059 1,557,269 308,966 (1,866,235 ) 1,804,059 Noncontrolling interest 17,225 17,225 — (17,225 ) $ 17,225 Total equity 1,821,284 1,574,494 308,966 (1,883,460 ) 1,821,284 Total liabilities and equity $ 23,973,408 $ 23,308,197 $ 3,754,963 $ (45,953,846 ) $ 5,082,722 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING BALANCE SHEET 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 5,899 292,990 1,500 — 300,389 Total assets $ 20,075,456 $ 21,252,546 $ 1,860,183 $ (39,174,423 ) $ 4,013,762 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 Current portion of long-term debt — — — — — 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 639,579 36,451 36,191 — 712,221 Intercompany notes payable 122,264 — — — 122,264 Other long-term liabilities 22,206 40,546 — — 62,752 Total liabilities 18,444,940 18,779,962 1,763,131 (36,604,787 ) 2,383,246 Commitments and contingencies Equity: Member's equity 1,144,100 749,278 44,346 (793,624 ) 1,144,100 Retained earnings 513,292 1,731,694 52,706 (1,784,400 ) 513,292 Accumulated other comprehensive loss (26,876 ) (8,388 ) — 8,388 (26,876 ) Total PBF Holding Company LLC equity 1,630,516 2,472,584 97,052 (2,569,636 ) 1,630,516 Noncontrolling interest — — — — — Total equity 1,630,516 2,472,584 97,052 (2,569,636 ) 1,630,516 Total liabilities and equity $ 20,075,456 $ 21,252,546 $ 1,860,183 $ (39,174,423 ) $ 4,013,762 CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Year Ended December 31, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 13,085,122 $ 884,930 $ 1,633,818 $ (2,479,941 ) $ 13,123,929 Costs and expenses: Cost of sales, excluding depreciation 11,514,115 1,026,846 1,550,579 (2,479,941 ) 11,611,599 Operating expenses, excluding depreciation (3,683 ) 891,534 1,517 — 889,368 General and administrative expenses 143,580 21,016 2,308 — 166,904 Gain on sale of asset (249 ) (105 ) (650 ) — (1,004 ) Depreciation and amortization expense 9,687 178,578 2,845 — 191,110 11,663,450 2,117,869 1,556,599 (2,479,941 ) 12,857,977 Income (loss) from operations 1,421,672 (1,232,939 ) 77,219 — 265,952 Other income (expense): Equity in earnings of subsidiaries (1,154,420 ) — — 1,154,420 — Change in fair value of catalyst lease — 10,184 — — 10,184 Interest expense, net (79,310 ) (5,876 ) (3,008 ) — (88,194 ) Income (loss) before income taxes 187,942 (1,228,631 ) 74,211 1,154,420 187,942 Income tax expense (benefit) — — 648 — 648 Net income (loss) 187,942 (1,228,631 ) 73,563 1,154,420 187,294 Less net income attributable to noncontrolling interests 274 274 — (274 ) 274 Net income (loss) attributable to PBF Holding Company LLC $ 187,668 $ (1,228,905 ) $ 73,563 $ 1,154,694 $ 187,020 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 189,774 $ (1,228,905 ) $ 73,563 $ 1,154,694 $ 189,126 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Year Ended December 31, 2014 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 19,847,045 $ 1,402,253 $ 1,007,407 $ (2,428,550 ) $ 19,828,155 Costs and expenses: Cost of sales, excluding depreciation 18,467,533 1,522,901 952,170 (2,428,550 ) 18,514,054 Operating expenses, excluding depreciation 218 880,339 144 — 880,701 General and administrative expenses 123,692 16,259 199 — 140,150 (Gain) loss on sale of asset (277 ) — (618 ) — (895 ) Depreciation and amortization expense 13,583 164,525 888 — 178,996 18,604,749 2,584,024 952,783 (2,428,550 ) 19,713,006 Income (loss) from operations 1,242,296 (1,181,771 ) 54,624 — 115,149 Other income (expense): Equity in earnings (loss) of subsidiaries (1,131,321 ) — — 1,131,321 — Change in fair value of catalyst lease — 3,969 — — 3,969 Interest expense, net (89,858 ) (6,225 ) (1,918 ) — (98,001 ) Income (loss) before income taxes 21,117 (1,184,027 ) 52,706 1,131,321 21,117 Income tax expense (benefit) — — — — — Net income (loss) 21,117 (1,184,027 ) 52,706 1,131,321 21,117 Less net income attributable to noncontrolling interests — — — — — Net income (loss) attributable to PBF Holding Company LLC $ 21,117 $ (1,184,027 ) $ 52,706 $ 1,131,321 $ 21,117 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 8,779 $ (1,194,031 ) $ 52,706 $ 1,141,325 $ 8,779 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Year Ended December 31, 2013 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 16,190,178 $ 7,641,498 $ — $ (4,680,221 ) $ 19,151,455 Costs and expenses: Cost of sales, excluding depreciation 16,486,851 5,996,684 — (4,680,221 ) 17,803,314 Operating expenses, excluding depreciation (482 ) 813,134 — — 812,652 General and administrative expenses 82,284 13,510 — — 95,794 Gain on sale of assets (388 ) 205 — — (183 ) Depreciation and amortization expense 12,856 98,623 — — 111,479 16,581,121 6,922,156 — (4,680,221 ) 18,823,056 (Loss) income from operations (390,943 ) 719,342 — — 328,399 Other income (expense): Equity in earnings (loss) of subsidiaries 722,673 — — (722,673 ) — Change in fair value of contingent consideration — — — — — Change in fair value of catalyst lease — 4,691 — — 4,691 Interest expense, net (92,854 ) (1,360 ) — — (94,214 ) Income (loss) before income taxes 238,876 722,673 — (722,673 ) 238,876 Income tax expense (benefit) — — — — — Net income (loss) 238,876 722,673 — (722,673 ) 238,876 Less net income attributable to noncontrolling interests — — — — — Net income (loss) attributable to PBF Holding Company LLC $ 238,876 $ 722,673 $ — $ (722,673 ) $ 238,876 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 233,279 $ 724,930 $ — $ (724,930 ) $ 233,279 CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF CASH FLOW Year Ended December 31, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 187,942 $ (1,228,631 ) $ 73,563 $ 1,154,420 $ 187,294 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 17,063 178,601 3,719 — 199,383 Stock-based compensation — 9,218 — — 9,218 Change in fair value of catalyst lease obligation — (10,184 ) — — (10,184 ) Non-cash change in inventory repurchase obligations — 63,389 — — 63,389 Non-cash lower of cost or market inventory adjustment 279,785 147,441 — — 427,226 Pension and other post retirement benefit costs 7,576 19,406 — — 26,982 Gain on disposition of property, plant and equipment (249 ) (105 ) (650 ) — (1,004 ) Equity in earnings of subsidiaries 1,154,420 — — (1,154,420 ) — Changes in current assets and current liabilities: Accounts receivable 87,689 16,124 (6,177 ) — 97,636 Amounts due to/from related parties (1,018,176 ) 1,133,364 (103,084 ) — 12,104 Inventories (108,751 ) (116,074 ) (47,067 ) — (271,892 ) Other current assets 2,721 (2,999 ) (353 ) — (631 ) Accounts payable (38,609 ) 15,710 (857 ) (1,259 ) (25,015 ) Accrued expenses 27,925 8,172 (73,834 ) — (37,737 ) Deferred revenue 2,816 — — — 2,816 Other assets and liabilities (423 ) (26,769 ) 10 — (27,182 ) Net cash provided by (used in) operating activities 601,729 206,663 (154,730 ) (1,259 ) 652,403 Cash flows from investing activities: Acquisition of Chalemtte refinery, net of cash received from sale of assets (601,311 ) 19,042 16,965 — (565,304 ) Expenditures for property, plant and equipment (193,898 ) (158,361 ) (106 ) — (352,365 ) Expenditures for refinery turnarounds costs — (53,576 ) — — (53,576 ) Expenditures for other assets — (8,236 ) — — (8,236 ) Investment in subsidiaries 10,000 — — (10,000 ) — Capital contributions to subsidiaries (5,000 ) — — 5,000 — Proceeds from sale of assets 60,902 — 107,368 — 168,270 Net cash (used in) provided by investing activities (729,307 ) (201,131 ) 124,227 (5,000 ) (811,211 ) 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF CASH FLOW (Continued) Cash flows from financing activities: Proceeds from member's capital contributions 345,000 — 5,000 (5,000 ) 345,000 Distribution to parent — — (10,000 ) 10,000 — Distributions to members (350,658 ) — — — (350,658 ) Proceeds from intercompany notes payable 347,783 — — — 347,783 Proceeds from revolver borrowings 170,000 — — — 170,000 Repayments of revolver borrowings (170,000 ) — — — (170,000 ) Proceeds from Rail Facility revolver borrowings — — 102,075 — 102,075 Repayments of Rail Facility revolver borrowings — — (71,938 ) — (71,938 ) Proceeds form Senior Secured Notes 500,000 — — — 500,000 Deferred financing costs and other (17,108 ) — — — (17,108 ) Net cash provided by financing activities 825,017 — 25,137 5,000 855,154 Net increase (decrease) in cash and cash equivalents 697,439 5,532 (5,366 ) (1,259 ) 696,346 Cash and equivalents, beginning of period 185,381 704 34,334 (2,016 ) 218,403 Cash and equivalents, end of period $ 882,820 $ 6,236 $ 28,968 $ (3,275 ) $ 914,749 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF CASH FLOW Year Ended December 31, 2014 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 21,117 $ (1,184,027 ) $ 52,706 $ 1,131,321 $ 21,117 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 20,334 164,550 1,528 — 186,412 Stock-based compensation — 6,095 — — 6,095 Change in fair value of catalyst lease obligation — (3,969 ) — — (3,969 ) Non-cash change in inventory repurchase obligations — (93,246 ) — — (93,246 ) Non-cash lower of cost or market inventory adjustment 566,412 123,698 — — 690,110 Gain on disposition of property, plant and equipment (277 ) — (618 ) — (895 ) Pension and other post retirement benefit cost 6,426 16,174 — — 22,600 Equity in earnings of subsidiaries 1,131,321 — — (1,131,321 ) — Changes in current assets and current liabilities: Accounts receivable 69,887 (17,976 ) (6,533 ) — 45,378 Amounts due to/from related parties (1,227,851 ) 1,328,439 (92,181 ) — 8,407 Inventories (259,352 ) 20,711 (155,390 ) — (394,031 ) Other current assets 22,287 1,399 — — 23,686 Accounts payable (71,821 ) (1,697 ) 8,423 (2,016 ) (67,111 ) Accrued expenses (131,903 ) 471 191,331 — 59,899 Deferred revenue (6,539 ) — — — (6,539 ) Other assets and liabilities (1,966 ) (258 ) (1 ) — (2,225 ) Net cash provided by (used in) operating activities 138,075 360,364 (735 ) (2,016 ) 495,688 Cash flows from investing activities: Expenditures for property, plant and equipment (152,814 ) (205,508 ) (112,138 ) — (470,460 ) Expenditures for refinery turnarounds costs — (137,688 ) — — (137,688 ) Expenditures for other assets — (17,255 ) — — (17,255 ) Investment in subsidiaries (44,346 ) — — 44,346 — Proceeds from sale of assets 133,845 — 68,809 — 202,654 Net cash (used in) provided by investing activities (63,315 ) (360,451 ) (43,329 ) 44,346 (422,749 ) Cash flows from financing activities: Proceeds from member's capital contributions 328,664 — 44,346 (44,346 ) 328,664 Distributions to members (361,352 ) — — — (361,352 ) Proceeds from intercompany notes payable 90,631 — — — 90,631 Proceeds from revolver borrowings 395,000 — — — 395,000 Repayments of revolver borrowings (410,000 ) — — — (410,000 ) Proceeds from Rail Facility revolver borrowings — — 83,095 — 83,095 Repayments of Rail Facility revolver borrowings — — (45,825 ) — (45,825 ) Deferred financing costs and other (8,501 ) — (3,218 ) — (11,719 ) Net cash provided by (used in) financing activities 34,442 — 78,398 (44,346 ) 68,494 Net increase (decrease) in cash and cash equivalents 109,202 (87 ) 34,334 (2,016 ) 141,433 Cash and equivalents, beginning of period 76,179 791 — — 76,970 Cash and equivalents, end of period $ 185,381 $ 704 $ 34,334 $ (2,016 ) $ 218,403 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF CASH FLOW Year Ended December 31, 2013 Issuer Guarantors Subsidiaries Non-Guarantors Subsidiaries Combining and Consolidated Adjustments Total Cash flows from operating activities: Net income $ 238,876 $ 722,673 $ — $ (722,673 ) $ 238,876 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 19,296 98,705 — — 118,001 Stock-based compensation — 3,753 — — 3,753 Change in fair value of catalyst lease obligation — (4,691 ) — — (4,691 ) Non-cash change in inventory repurchase obligations — (20,492 ) — — (20,492 ) Pension and other post retirement benefit costs 4,575 12,153 — — 16,728 Gain on disposition of property, plant and equipment (388 ) 205 — — (183 ) Equity in earnings of subsidiaries (722,673 ) — — 722,673 — Changes in operating assets and liabilities: Accounts receivable (281,386 ) 188,535 — — (92,851 ) Amounts due to/from related parties 626,623 (611,902 ) — — 14,721 Inventories (153,782 ) 199,773 — — 45,991 Other current assets (40,416 ) (2,039 ) — — (42,455 ) Accounts payable 109,988 (67,752 ) — — 42,236 Accrued expenses 222,194 (7,377 ) — — 214,817 Deferred revenue 7,766 (210,543 ) — — (202,777 ) Other assets and liabilities (1,140 ) (19,263 ) — — (20,403 ) Net cash provided by operating activities 29,533 281,738 — — 311,271 Cash flows from investing activities: Expenditures for property, plant and equipment (127,653 ) (190,741 ) — — (318,394 ) Expenditures for refinery turnarounds costs — (64,616 ) — — (64,616 ) Expenditures for other assets — (32,692 ) — — (32,692 ) Proceeds from sale of assets 102,428 — — — 102,428 Net cash used in investing activities (25,225 ) (288,049 ) — — (313,274 ) Cash flows from financing activities: Proceeds from revolver borrowings 1,450,000 — — — 1,450,000 Proceeds from intercompany notes payable 31,835 — — — 31,835 Proceeds from member's capital contributions — 1,757 — — 1,757 Proceeds from catalyst lease — 14,337 — — 14,337 Distributions to members (215,846 ) — — — (215,846 ) Repayments of revolver borrowings (1,435,000 ) — — — (1,435,000 ) Payment of contingent consideration related to acquisition of Toledo Refinery — (21,357 ) — — (21,357 ) Deferred financing costs and other (1,044 ) — — — (1,044 ) Net cash used in financing activities (170,055 ) (5,263 ) — — (175,318 ) Net increase (decrease) in cash and cash equivalents (165,747 ) (11,574 ) — — (177,321 ) Cash and equivalents, beginning of period 241,926 12,365 — — 254,291 Cash and equivalents, end of period $ 76,179 $ 791 $ — $ — $ 76,970

SUMMARY OF SIGNIFICANT ACCOUN31

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Accounting Policies [Abstract]
Principles of Consolidation and Presentation		Principles of Consolidation and Presentation These consolidated financial statements include the accounts of PBF Holding and its consolidated subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation.
Reclassification		Reclassification Certain amounts previously reported in the Company's consolidated financial statements for prior periods have been reclassified to conform to the 2015 presentation. These reclassifications include presentation of deferred financing costs and debt due to the adoption of a recently adopted accounting pronouncement (as discussed below).
Use of Estimates		Use of Estimates The preparation of the financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures. Actual results could differ from those estimates.
Business Combinations		Business Combinations We use the acquisition method of accounting for the recognition of assets acquired and liabilities assumed in business combinations at their estimated fair values as of the date of acquisition. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired is recorded as goodwill. Significant judgment is required in estimating the fair value of assets acquired. As a result, in the case of significant acquisitions, we obtain the assistance of third-party valuation specialists in estimating fair values of tangible and intangible assets based on available historical information and on expectations and assumptions about the future, considering the perspective of marketplace participants. While management believes those expectations and assumptions are reasonable, they are inherently uncertain. Unanticipated market or macroeconomic events and circumstances may occur, which could affect the accuracy or validity of the estimates and assumptions.
Cash and Cash Equivalents		Cash and Cash Equivalents The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents. The carrying amount of the cash equivalents approximates fair value due to the short-term maturity of those instruments.
Concentration of Credit Risk		Concentrations of Credit Risk For the year ended December 31, 2015 no single customer amounted to greater than or equal to 10% of the Company's revenue. Only one customer, ExxonMobil Oil Corporation (“ExxonMobil”), accounted for 10% or more of our total trade accounts receivables as of December 31, 2015 . Following the Chalmette Acquisition on November 1, 2015, ExxonMobil and its affiliates represented approximately 18% of our total trade accounts receivable as of December 31, 2015 . For the year ended December 31, 2014 , no single customer amounted to greater than or equal to 10% of the Company's revenues. No single customer accounted for 10% or more of our total trade accounts receivable as of December 31, 2014 . For the year ended December 31, 2013 , Morgan Stanley Capital Group, Inc. (“MSCG”) and Sunoco, Inc. (R&M) (“Sunoco”) accounted for 29% and 10% of the Company’s revenues, respectively.
Revenue, Deferred Revenue and Accounts Receivable		Revenue, Deferred Revenue and Accounts Receivable The Company sells various refined products primarily through its refinery subsidiaries and recognizes revenue related to the sale of products when there is persuasive evidence of an agreement, the sales prices are fixed or determinable, collectability is reasonably assured and when products are shipped or delivered in accordance with their respective agreements. Revenue for services is recorded when the services have been provided. Certain of the Company's refineries have products offtake agreements with third-parties under which these third parties purchase a portion of the refineries' daily gasoline production. The refineries also sell their products through short-term contracts or on the spot market. Prior to July 1, 2013, the Company’s Paulsboro and Delaware City refineries sold light finished products, certain intermediates and lube base oils to MSCG under products offtake agreements with each refinery (the “Offtake Agreements”). On a daily basis, MSCG purchased and paid for the refineries’ production of light finished products as they were produced, delivered to the refineries’ storage tanks, and legal title passed to MSCG. Revenue on these product sales was deferred until they shipped out of the storage facility by MSCG. Under the Offtake Agreements, the Company’s Paulsboro and Delaware City refineries also entered into purchase and sale transactions of certain intermediates and lube base oils whereby MSCG purchased and paid for the refineries’ production of certain intermediates and lube products as they were produced and legal title passed to MSCG. The intermediate products were held in the refineries’ storage tanks until they were needed for further use in the refining process. The intermediates may also have been sold to third parties. The refineries had the right to repurchase lube products and did so to supply other third parties with that product. When the refineries needed intermediates or lube products, the products were drawn out of the storage tanks, title passed back to the refineries and MSCG was paid for those products. These transactions occurred at the daily market price for the related products. These transactions were considered to be made in contemplation of each other and, accordingly, did not result in the recognition of a sale when title passed from the refineries to MSCG. Inventory remained at cost and the net cash receipts resulted in a liability that was recorded at market price for the volumes held in storage with any change in the market price being recorded in costs of sales. The liability represented the amount the Company expected to pay to repurchase the volumes held in storage. While MSCG had legal title, it had the right to encumber and/or sell these products and any such sales by MSCG resulted in sales being recognized by the refineries when products were shipped out of the storage facility. As the exclusive vendor of intermediate products to the refineries, MSCG had the obligation to provide the intermediate products to the refineries as they were needed. Accordingly, sales by MSCG to others were limited and only made with the Company or its subsidiaries’ approval. As of July 1, 2013, the Company terminated the Offtake Agreements for the Company’s Paulsboro and Delaware City refineries. The Company entered into two separate inventory intermediation agreements (“Inventory Intermediation Agreements”) with J. Aron & Company (“J. Aron”) on June 26, 2013 which commenced upon the termination of the Offtake Agreements with MSCG. On May 29, 2015, PBF Holding entered into amended and restated inventory intermediation agreements (the “A&R Intermediation Agreements”) with J. Aron pursuant to which certain terms of the existing inventory intermediation agreements were amended, including, among other things, pricing and an extension of the term for a period of two years from the original expiry date of July 1, 2015, subject to certain early termination rights. In addition, the A&R Intermediation Agreements include one-year renewal clauses by mutual consent of both parties. Pursuant to each A&R Intermediation Agreement, J. Aron will continue to purchase and hold title to certain of the intermediate and finished products (the “Products”) produced by the Paulsboro and Delaware City refineries (the “Refineries”), respectively, and delivered into tanks at the Refineries. Furthermore, J. Aron agrees to sell the Products back to Paulsboro refinery and Delaware City refinery as the Products are discharged out of the Refineries' tanks. J. Aron has the right to store the Products purchased in tanks under the A&R Intermediation Agreements and will retain these storage rights for the term of the agreements. PBF Holding will continue to market and sell the Products independently to third parties. Until December 31, 2015, the Company's Delaware City refinery sold and purchased feedstocks under a supply agreement with Statoil (the “Crude Supply Agreement”). This Crude Supply Agreement expired on December 31, 2015. Statoil purchased the refineries' production of certain feedstocks or purchased feedstocks from third parties on the refineries' behalf. Legal title to the feedstocks were held by Statoil and the feedstocks were held in the refineries' storage tanks until they were needed for further use in the refining process. At that time, the products were drawn out of the storage tanks and purchased by the refinery. These purchases and sales were settled monthly at the daily market prices related to those products. These transactions were considered to be made in contemplation of each other and, accordingly, did not result in the recognition of a sale when title passed from the refineries to Statoil. Inventory remained at cost and the net cash receipts resulted in a liability which is discussed further in the Inventory note below. The Company terminated its supply agreement with Statoil for its Paulsboro refinery in March 2013, at which time the Company began to purchase from Statoil the feedstocks owned by them at that date that had been purchased on its behalf. Subsequent to the expiration of the Delaware City Crude Supply Agreement, the Company began to purchase all of its crude and feedstock needs independently from a variety of suppliers on the spot market or through term agreements. Accounts receivable are carried at invoiced amounts. An allowance for doubtful accounts is established, if required, to report such amounts at their estimated net realizable value. In estimating probable losses, management reviews accounts that are past due and determines if there are any known disputes. There was no allowance for doubtful accounts at December 31, 2015 and 2014 . Excise taxes on sales of refined products that are collected from customers and remitted to various governmental agencies are reported on a net basis.
Inventory		Inventory Inventories are carried at the lower of cost or market. The cost of crude oil, feedstocks, blendstocks and refined products are determined under the last-in first-out (“LIFO”) method using the dollar value LIFO method with increments valued based on average purchase prices during the year. The cost of supplies and other inventories is determined principally on the weighted average cost method. The Company had the obligation to purchase and sell feedstocks under a supply agreement with Statoil for its Delaware City refinery. This Crude Supply Agreement expired on December 31, 2015. The Company's Paulsboro refinery also had a crude supply agreement with Statoil that was terminated in March 2013. Prior to the expiration or termination of these agreements, Statoil purchased the refineries' production of certain feedstocks or purchased feedstocks from third parties on the refineries' behalf. The Company took title to the crude oil as it was delivered to the processing units, in accordance with the Crude Supply Agreement; however, the Company was obligated to purchase all the crude oil held by Statoil on the Company’s behalf upon termination of the agreement at the then market price. The Paulsboro crude supply agreement also included an obligation to purchase a fixed volume of feedstocks from Statoil on the later of maturity or when the arrangement is terminated based on a forward market price of West Texas Intermediate crude oil. As a result of the purchase obligations, the Company recorded the inventory of crude oil and feedstocks in the refineries’ storage facilities. The Company determined the purchase obligations were contracts that contain derivatives that changed in value based on changes in commodity prices. Such changes in the fair value of these derivatives were included in cost of sales. Prior to July 31, 2014, the Company’s Toledo refinery acquired substantially all of its crude oil from MSCG under a crude oil acquisition agreement (the “Toledo Crude Oil Acquisition Agreement”). Under the Toledo Crude Oil Acquisition Agreement, the Company took title to crude oil at various pipeline locations for delivery to the refinery or sale to third parties. The Company recorded the crude oil inventory when it received title. Payment for the crude oil was due to MSCG under the Toledo Crude Oil Acquisition Agreement three days after the crude oil was delivered to the Toledo refinery processing units or upon sale to a third party. The Company terminated the Toledo Crude Oil Acquisition Agreement effective July 31, 2014 and began to source its crude oil needs independently.
Property, Plant and Equipment		Property, Plant and Equipment Property, plant and equipment additions are recorded at cost. The Company capitalizes costs associated with the preliminary, pre-acquisition and development/construction stages of a major construction project. The Company capitalizes the interest cost associated with major construction projects based on the effective interest rate of total borrowings. The Company also capitalizes costs incurred in the acquisition and development of software for internal use, including the costs of software, materials, consultants and payroll-related costs for employees incurred in the application development stage. Depreciation is computed using the straight-line method over the following estimated useful lives: Process units and equipment 5-25 years Pipeline and equipment 5-25 years Buildings 25 years Computers, furniture and fixtures 3-7 years Leasehold improvements 20 years Railcars 50 years Maintenance and repairs are charged to operating expenses as they are incurred. Improvements and betterments, which extend the lives of the assets, are capitalized.
Deferred Charges and Other Assets, Net		Deferred Charges and Other Assets, Net Deferred charges and other assets include refinery turnaround costs, catalyst, precious metals catalyst, linefill, deferred financing costs and intangible assets. Refinery turnaround costs, which are incurred in connection with planned major maintenance activities, are capitalized when incurred and amortized on a straight-line basis over the period of time estimated to lapse until the next turnaround occurs (generally 3 to 5 years ). Precious metals catalyst and linefill are considered indefinite-lived assets as they are not expected to deteriorate in their prescribed functions. Such assets are assessed for impairment in connection with the Company’s review of its long-lived assets as indicators of impairment develop. Deferred financing costs are capitalized when incurred and amortized over the life of the loan (generally 1 to 8 years ). Intangible assets with finite lives primarily consist of catalyst, emission credits and permits and are amortized over their estimated useful lives (generally 1 to 10 years ).
Long-Lived Assets and Definite-Lived Intangibles		Long-Lived Assets and Definite-Lived Intangibles The Company reviews its long-lived assets for impairment whenever events or changes in circumstances indicate the carrying value may not be recoverable. Impairment is evaluated by comparing the carrying value of the long-lived assets to the estimated undiscounted future cash flows expected to result from use of the assets and their ultimate disposition. If such analysis indicates that the carrying value of the long-lived assets is not considered to be recoverable, the carrying value is reduced to the fair value. Impairment assessments inherently involve judgment as to assumptions about expected future cash flows and the impact of market conditions on those assumptions. Although management would utilize assumptions that it believes are reasonable, future events and changing market conditions may impact management’s assumptions, which could produce different results.
Asset Retirement Obligations		Asset Retirement Obligations The Company records an asset retirement obligation at fair value for the estimated cost to retire a tangible long-lived asset at the time the Company incurs that liability, which is generally when the asset is purchased, constructed, or leased. The Company records the liability when it has a legal or contractual obligation to incur costs to retire the asset and when a reasonable estimate of the fair value of the liability can be made. If a reasonable estimate cannot be made at the time the liability is incurred, the Company will record the liability when sufficient information is available to estimate the liability’s fair value. Certain of the Company’s asset retirement obligations are based on its legal obligation to perform remedial activity at its refinery sites when it permanently ceases operations of the long-lived assets. The Company therefore considers the settlement date of these obligations to be indeterminable. Accordingly, the Company cannot calculate an associated asset retirement liability for these obligations at this time. The Company will measure and recognize the fair value of these asset retirement obligations when the settlement date is determinable.
Environmental Matters		Environmental Matters Liabilities for future remediation costs are recorded when environmental assessments and/or remedial efforts are probable and the costs can be reasonably estimated. Other than for assessments, the timing and magnitude of these accruals generally are based on the completion of investigations or other studies or a commitment to a formal plan of action. Environmental liabilities are based on best estimates of probable future costs using currently available technology and applying current regulations, as well as the Company’s own internal environmental policies. The measurement of environmental remediation liabilities may be discounted to reflect the time value of money if the aggregate amount and timing of cash payments of the liabilities are fixed or reliably determinable. The actual settlement of the Company’s liability for environmental matters could materially differ from its estimates due to a number of uncertainties such as the extent of contamination, changes in environmental laws and regulations, potential improvements in remediation technologies and the participation of other responsible parties.
Stock-Based Compensation		Stock-Based Compensation Stock-based compensation includes the accounting effect of options to purchase PBF Energy Class A common stock granted by PBF Energy to certain PBF Holding employees, Series A warrants issued or granted by PBF LLC to employees in connection with their acquisition of PBF LLC Series A units, options to acquire Series A units of PBF LLC granted by PBF LLC to certain employees, Series B units of PBF LLC that were granted to certain members of management and restricted PBF LLC Series A Units and restricted PBF Energy Class A common stock granted to certain directors and officers. The estimated fair value of the options to purchase PBF Energy Class A common stock and the PBF LLC Series A warrants and options, is based on the Black-Scholes option pricing model and the fair value of the PBF LLC Series B units is estimated based on a Monte Carlo simulation model. The estimated fair value is amortized as stock-based compensation expense on a straight-line method over the vesting period and included in general and administration expense.
Income Taxes		Income Taxes As PBF Holding is a limited liability company treated as a “flow-through” entity for income tax purposes, there is no benefit or provision for federal or state income tax in the accompanying financial statements apart from the income taxes attributable to two subsidiaries acquired in connection with the acquisition of Chalmette Refining that are treated as C-corporations for tax purposes. The Federal and state tax returns for all years since 2012 are subject to examination by the respective tax authorities.
Pension and Other Post-Retirement Benefits		Pension and Other Post-Retirement Benefits The Company recognizes an asset for the overfunded status or a liability for the underfunded status of its pension and post-retirement benefit plans. The funded status is recorded within other long-term liabilities or assets. Changes in the plans’ funded status are recognized in other comprehensive income in the period the change occurs.
Fair Value Measurement		Fair Value Measurement A fair value hierarchy (Level 1, Level 2, or Level 3) is used to categorize fair value amounts based on the quality of inputs used to measure fair value. Accordingly, fair values derived from Level 1 inputs utilize quoted prices in active markets for identical assets or liabilities. Fair values derived from Level 2 inputs are based on quoted prices for similar assets and liabilities in active markets, and inputs other than quoted prices that are either directly or indirectly observable for the asset or liability. Level 3 inputs are unobservable inputs for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability. The Company uses appropriate valuation techniques based on the available inputs to measure the fair values of its applicable assets and liabilities. When available, the Company measures fair value using Level 1 inputs because they generally provide the most reliable evidence of fair value. In some valuations, the inputs may fall into different levels in the hierarchy. In these cases, the asset or liability level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurements.
Financial Instruments		Financial Instruments The estimated fair value of financial instruments has been determined based on the Company’s assessment of available market information and appropriate valuation methodologies. The Company’s non-derivative financial instruments that are included in current assets and current liabilities are recorded at cost in the consolidated balance sheets. The estimated fair value of these financial instruments approximates their carrying value due to their short-term nature. Derivative instruments are recorded at fair value in the consolidated balance sheets. The Company’s commodity contracts are measured and recorded at fair value using Level 1 inputs based on quoted prices in an active market, Level 2 inputs based on quoted market prices for similar instruments, or Level 3 inputs based on third party sources and other available market based data. The Company’s catalyst lease obligation and derivatives related to the Company’s crude oil and feedstocks and refined product purchase obligations are measured and recorded at fair value using Level 2 inputs on a recurring basis, based on observable market prices for similar instruments.
Derivative Instruments		Derivative Instruments The Company is exposed to market risk, primarily related to changes in commodity prices for the crude oil and feedstocks used in the refining process as well as the prices of the refined products sold. The accounting treatment for commodity contracts depends on the intended use of the particular contract and on whether or not the contract meets the definition of a derivative. All derivative instruments, not designated as normal purchases or sales, are recorded in the balance sheet as either assets or liabilities measured at their fair values. Changes in the fair value of derivative instruments that either are not designated or do not qualify for hedge accounting treatment or normal purchase or normal sale accounting are recognized currently in earnings. Contracts qualifying for the normal purchase and sales exemption are accounted for upon settlement. Cash flows related to derivative instruments that are not designated or do not qualify for hedge accounting treatment are included in operating activities. The Company designates certain derivative instruments as fair value hedges of a particular risk associated with a recognized asset or liability. At the inception of the hedge designation, the Company documents the relationship between the hedging instrument and the hedged item, as well as its risk management objective and strategy for undertaking various hedge transactions. Derivative gains and losses related to these fair value hedges, including hedge ineffectiveness, are recorded in cost of sales along with the change in fair value of the hedged asset or liability attributable to the hedged risk. Cash flows related to derivative instruments that are designated as fair value hedges are included in operating activities. Economic hedges are hedges not designated as fair value or cash flow hedges for accounting purposes that are used to (i) manage price volatility in certain refinery feedstock and refined product inventories, and (ii) manage price volatility in certain forecasted refinery feedstock purchases and refined product sales. These instruments are recorded at fair value and changes in the fair value of the derivative instruments are recognized currently in cost of sales. Derivative accounting is complex and requires management judgment in the following respects: identification of derivatives and embedded derivatives, determination of the fair value of derivatives, documentation of hedge relationships, assessment and measurement of hedge ineffectiveness and election and designation of the normal purchases and sales exception. All of these judgments, depending upon their timing and effect, can have a significant impact on the Company’s earnings.
Recently Issued Accounting Pronouncements	DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION Description of the Business PBF Holding Company LLC ("PBF Holding" or the "Company"), 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 95.2% of the outstanding economic interest in, PBF LLC as of September 30, 2016 . 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 Refining"), Paulsboro Natural Gas Pipeline Company LLC, Toledo Refining Company LLC ("Toledo Refining" or "TRC"), Chalmette Refining, L.L.C. (“Chalmette Refining”) and PBF Western Region LLC (“PBF Western Region”) are PBF LLC’s principal operating subsidiaries and are all wholly-owned subsidiaries of PBF Holding. PBF Western Region owns Torrance Refining Company LLC and Torrance Logistics Company LLC, which collectively own the operating assets of the Torrance refinery and related logistics assets. In addition, PBF LLC, through Chalmette Refining, holds a 100% interest in MOEM Pipeline LLC and an 80% interest in and consolidates Collins Pipeline Company and T&M Terminal Company. 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. Subsequent to the PBFX Offering, PBF Holding and PBF LLC entered into a series of drop-down transactions with PBFX. During 2014, PBF Holding distributed to PBF LLC all of the equity interests of certain of its wholly-owned subsidiaries, whose assets consist of a heavy crude oil rail unloading facility (also, capable of unloading light crude oil) at the Delaware City refinery (the "DCR West Rack") and a tank farm and related facilities located at our Toledo refinery, including a propane storage and loading facility (the "Toledo Storage Facility"), which were subsequently acquired by PBFX. In addition, on May 14, 2015, PBF Holding distributed to PBF LLC, which subsequently contributed to PBFX, all of the issued and outstanding limited liability company interests of Delaware Pipeline Company LLC and Delaware City Logistics Company LLC, whose assets consist of a product pipeline, truck rack and related facilities located at our Delaware City refinery (collectively referred to as the “Delaware City Products Pipeline and Truck Rack”). On August 31, 2016, PBFX entered into a contribution agreement (the "TVPC Contribution Agreement") between PBFX and PBF LLC. Pursuant to the TVPC Contribution Agreement, PBFX acquired from PBF LLC 50% of the issued and outstanding limited liability company interests of Torrance Valley Pipeline Company LLC (“TVPC”), whose assets consist of the San Joaquin Valley Pipeline system (which was acquired as a part of the Torrance Acquisition as defined in "Note 2 - Acquisitions"), including the M55, M1 and M70 pipelines including pipeline stations with tankage and truck unloading capability (collectively, the “Torrance Valley Pipeline"). The total consideration paid to PBF LLC was $ 175,000 in cash, which was subsequently contributed to PBF Holding. Refer to "Note 8 - Related Party Transactions" of our Notes to Condensed Consolidated Financial Statements for further information on agreements entered into with PBFX. On August 31, 2016, in connection with the TVPC Contribution Agreement, PBF Holding contributed 50% of the issued and outstanding limited liability company interests of TVPC to PBF LLC. Substantially all of the Company’s operations are in the United States. As of September 30, 2016 , the Company’s oil refineries are all engaged in the refining of crude oil and other feedstocks into petroleum products, and have been aggregated to form one reportable segment. 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 accounting principles generally accepted in the United States of America ("GAAP") for interim financial information. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. These interim condensed consolidated financial statements should be read in conjunction with the financial statements included in the Annual Report on Form 10-K for the year ended December 31, 2015 of PBF Holding Company LLC and PBF Finance Corporation. The results of operations for the three and nine months ended September 30, 2016 are not necessarily indicative of the results to be expected for the full year. Noncontrolling Interest Subsequent to the Chalmette Acquisition (as defined in "Note 2 - Acquisitions"), PBF Holding recorded noncontrolling interest in two subsidiaries of Chalmette Refining. PBF Holding, through Chalmette Refining, owns an 80% ownership interest in both Collins Pipeline Company and T&M Terminal Company. The Company recorded aggregate earnings related to the noncontrolling interest in these subsidiaries of $45 and $438 for the three and nine months ended September 30, 2016 , respectively. Investment in Equity Method Investee Subsequent to the closing of the TVPC Contribution Agreement, the Company accounts for its 50% equity ownership of TVPC as an investment in an equity method investee. Investee companies that are not consolidated, but over which the Company exercises significant influence, are accounted for under the equity method of accounting. Whether or not the Company exercises significant influence with respect to an investee depends on an evaluation of several factors including, among others, representation on the investee company's board of directors and ownership level, which is generally a 20% to 50% interest in the voting securities of the investee company. Under the equity method of accounting, an investee company's accounts are not reported in the Company's consolidated balance sheets and statements of operations; however, the Company's share of the earnings or losses of the investee company is reflected in the caption ''Equity income (loss) in investee" in the consolidated statements of operations. The Company's carrying value in an equity method investee company is reported in the caption ''Investment in equity method investee'' in the Company's consolidated balance sheets. When the Company's carrying value in an equity method investee company is reduced to zero, no further losses are recorded in the Company's consolidated financial statements unless the Company guaranteed obligations of the investee company or has committed additional funding. When the investee company subsequently reports income, the Company will not record its share of such income until it equals or exceeds the amount of its share of losses not previously recognized. Prior Period Correction During the quarter ended March 31, 2016, the Company recorded an out-of-period adjustment increasing deferred income tax liabilities and income tax expense by $30,481 as described in "Note 6 - Income Taxes" of our Notes to Condensed Consolidated Financial Statements. The Company has considered existing guidance in evaluating whether a restatement of prior financial statements is required as a result of these misstatements. The Company has quantitatively and qualitatively assessed the materiality of the errors and concluded that this correction did not have a material impact on the financial statements as of and for the three months ended March 31, 2016 nor as of and for the nine months ended September 30, 2016 and the errors were not material to the prior period financial statements, and accordingly, the Company has not restated any prior period amounts. Recently Adopted Accounting Guidance Effective January 1, 2016, the Company adopted Accounting Standard Update ("ASU") No. 2015-02, "Consolidation (Topic 810): Amendments to the Consolidation Analysis" ("ASU 2015-02"), which changed existing consolidation requirements associated with the analysis a reporting entity must perform to determine whether it should consolidate certain types of legal entities, including limited partnerships and variable interest entities. The Company’s adoption of this guidance did not impact our consolidated financial statements. Effective January 1, 2016, the Company adopted 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. The adoption of this guidance did not materially affect any of the Company's financial statements or related disclosures. Recent Accounting Pronouncements In August 2015, the Financial Accounting Standards Board ("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 No. 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”) for all entities by one year. Additional ASUs have been issued in 2016 that provide certain implementation guidance related to ASU 2014-09 (collectively, the Company refers to ASU 2014-09 and these additional ASUs as the "Updated Revenue Recognition Guidance"). The Updated Revenue Recognition Guidance 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 is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In November 2015, the FASB issued ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes” (“ASU 2015-17”), which requires deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. Under ASU 2015-17, this guidance becomes effective for annual periods beginning after December 15, 2016 and interim periods within annual periods beginning after December 15, 2016 and interim periods within those years with early adoption permitted as of the beginning of an annual or interim period after the issuance of the ASU. The Company expects that the impact of adopting this new standard will be to reclassify all of its current deferred tax assets and deferred tax liabilities to a net noncurrent asset or liability on its balance sheet. In January 2016, the FASB issued ASU No. 2016-01, “Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” (“ASU 2016-01”), which amends how entities measure equity investments that do not result in consolidation and are not accounted for under the equity method and how they present changes in the fair value of financial liabilities measured under the fair value option that are attributable to their own credit. ASU 2016-01 also changes certain disclosure requirements and other aspects of current GAAP but does not change the guidance for classifying and measuring investments in debt securities and loans. Under ASU 2016-01, this guidance becomes effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted in certain circumstances. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842)” (“ASU 2016-02”), to increase the transparency and comparability about leases among entities. The new guidance requires lessees to recognize a lease liability and a corresponding lease asset for virtually all lease contracts. It also requires additional disclosures about leasing arrangements. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In March 2016, the FASB issued ASU No. 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments No. 2016-06 March 2016 a consensus of the FASB Emerging Issues Task Force” (“ASU 2016-06”), to increase consistency in practice in applying guidance on determining if an embedded derivative is clearly and closely related to the economic characteristics of the host contract, specifically for assessing whether call (put) options that can accelerate the repayment of principal on a debt instrument meet the clearly and closely related criterion. The guidance in ASU 2016-06 applies to all entities that are issuers of or investors in debt instruments (or hybrid financial instruments that are determined to have a debt host) with embedded call (put) options. ASU 2016-06 is effective for interim and annual periods beginning after December 15, 2016, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In March 2016, the FASB issued ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”) which is intended to simplify certain aspects of the accounting for share-based payments to employees. The guidance in ASU 2016-09 requires all income tax effects of awards to be recognized in the income statement when the awards vest or are settled rather than recording excess tax benefits or deficiencies in additional paid-in capital. The guidance in ASU 2016-09 also allows an employer to repurchase more of an employee’s shares than it can today for tax withholding purposes without triggering liability accounting and to make a policy election to account for forfeitures as they occur. ASU 2016-09 also contains additional guidance for nonpublic entities that do not apply to the Company. ASU 2016-09 is effective for interim and annual periods beginning after December 15, 2016, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In June 2016, the FASB issued ASU No. 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments” (“ASU 2016-13”) which requires credit losses on available-for-sale debt securities to be presented as an allowance rather than as a write-down. ASU 2016-13 is effective for interim and annual periods beginning after December 15, 2019, and requires a modified retrospective approach to adoption. Early adoption is permitted for interim and annual periods beginning after December 15, 2018. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In August 2016, the FASB issued ASU No. 2016-15, "Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments" ("ASU 2016-15"), which reduces the existing diversity in practice in how certain cash receipts and cash payments are presented and classified in the statement of cash flows under Topic 230. ASU 2016-15 is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted, including adoption in an interim period. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In October 2016, the FASB issued ASU No. 2016-16, "Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory" ("ASU 2016-16"), which reduces the existing diversity in practice in how income tax consequences of an intra-entity transfer of an asset other than inventory should be recognized. The amendments in ASU 2016-16 require an entity to recognize such income tax consequences when the intra-entity transfer occurs rather than waiting until such time as the asset has been sold to an outside party. The amendments do not contain any new disclosure requirements but point out that certain existing income tax disclosures might be applicable in the period an intra-entity transfer of an asset other than inventory occurs. ASU 2016-16 is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted as of the beginning of an annual reporting period for which interim or annual statements have not been issued. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In October 2016, the FASB issued ASU No. 2016-17, "Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control" ("ASU 2016-2017"), which amends the consolidation guidance on how a reporting entity that is the single decision maker of a variable interest entity (“VIE”) should treat indirect interests in the entity held through related parties that are under common control with the reporting entity when determining whether it is the primary beneficiary of that VIE. The amendments in this ASU do not change the characteristics of a primary beneficiary in current GAAP. The amendments in this ASU require that reporting entity, in determining whether it satisfies the second characteristic of a primary beneficiary, to include all of its direct variable interests in a VIE and, on a proportionate basis, its indirect variable interests in a VIE held through related parties, including related parties that are under common control with the reporting entity. ASU 2016-2017 is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption is permitted, including adoption in an interim period. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.	Recently Issued Accounting Pronouncements In February 2015, the FASB issued ASU No. 2015-02, “Consolidations (Topic 810): Amendments to the Consolidation Analysis” (“ASU 2015-02”), which amends current consolidation guidance including changes to both the variable and voting interest models used by companies to evaluate whether an entity should be consolidated. The requirements from ASU 2015-02 are 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 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 early adopted the new standard in its consolidated financial statements and related disclosures, which resulted in a reclassification of $32,217 and $30,128 of deferred financing costs from other assets to long-term debt as of December 31, 2015 and December 31, 2014 , respectively. 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 and expects to early adopt this guidance for periods beginning after December 31, 2015. In November 2015, the FASB issued ASU 2015-17 (Topic 740), “Balance Sheet Classification of Deferred Taxes” (“ASU 2015-17”) which is intended to simplify the presentation of deferred taxes in a classified balance sheet. This guidance states that deferred tax assets and deferred tax liabilities should be presented as noncurrent in a classified statement of financial position. Under ASU 2015-17, this guidance becomes effective for annual periods beginning after December 15, 2016 and interim periods within those annual periods with early adoption permitted as of the beginning of an annual or interim period after issuance of the ASU. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures and expects to early adopt this guidance for periods beginning after December 31, 2015. In January 2016, the FASB issued ASU No. 2016-01, “Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” (“ASU 2016-01”), which amends how entities measure equity investments that do not result in consolidation and are not accounted for under the equity method and how they present changes in the fair value of financial liabilities measured under the fair value option that are attributable to their own credit. ASU 2016-01 also changes certain disclosure requirements and other aspects of current GAAP but does not change the guidance for classifying and measuring investments in debt securities and loans. Under ASU 2016-01, this guidance becomes effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted in certain circumstances. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842)” (“ASU 2016-02”), to increase the transparency and comparability about leases among entities. The new guidance requires lessees to recognize a lease liability and a corresponding lease asset for virtually all lease contracts. It also requires additional disclosures about leasing arrangements. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.

SUMMARY OF SIGNIFICANT ACCOUN32

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Useful lives of property, plant and equipment	Depreciation is computed using the straight-line method over the following estimated useful lives: Process units and equipment 5-25 years Pipeline and equipment 5-25 years Buildings 25 years Computers, furniture and fixtures 3-7 years Leasehold improvements 20 years Railcars 50 years Property, plant and equipment consisted of the following: December 31, December 31, Land $ 91,256 $ 59,575 Process units, pipelines and equipment 2,209,712 1,843,157 Buildings and leasehold improvements 34,265 28,397 Computers, furniture and fixtures 72,642 68,431 Construction in progress 150,388 69,413 2,558,263 2,068,973 Less—Accumulated depreciation (347,173 ) (262,913 ) $ 2,211,090 $ 1,806,060

ACQUISITIONS (Tables)

ACQUISITIONS (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Business Combinations [Abstract]
Schedule of Business Acquisitions, by Acquisition	The total purchase consideration and the fair values of the assets and liabilities at the acquisition date, which may be subject to adjustment as noted above, were as follows: Purchase Price Gross purchase price $ 537,500 Working capital 450,582 Post close purchase price adjustments (16,150 ) Total consideration $ 971,932 The total purchase consideration and the fair values of the assets and liabilities at the acquisition date were as follows: Purchase Price Net cash $ 587,005 Cash acquired (19,042 ) Total consideration $ 567,963
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table summarizes the final amounts recognized for assets acquired and liabilities assumed as of the acquisition date: Fair Value Allocation Accounts receivable $ 1,126 Inventories 271,434 Prepaid expenses and other current assets 913 Property, plant and equipment 356,961 Deferred charges and other assets 8,312 Accounts payable (4,870 ) Accrued expenses (28,371 ) Deferred tax liability (25,721 ) Noncontrolling interests (11,821 ) Fair value of net assets acquired $ 567,963 The following table summarizes the preliminary amounts recognized for assets acquired and liabilities assumed as of the acquisition date: Fair Value Allocation Inventories $ 404,542 Prepaid expenses and other current assets 1,186 Property, plant and equipment 701,617 Deferred charges and other assets, net 68,053 Accounts payable (2,688 ) Accrued expenses (62,311 ) Other long-term liabilities (138,467 ) Fair value of net assets acquired $ 971,932	The total purchase consideration and the estimated fair values of the assets and liabilities at the acquisition date were as follows: Purchase Price Net cash $ 565,083 Preliminary estimate of payable to Seller for working capital adjustments 19,263 Cash acquired (19,042 ) Total estimated consideration $ 565,304 Fair Value Allocation Accounts receivable $ 1,126 Inventories 268,751 Prepaid expenses and other current assets 913 Property, plant and equipment 356,961 Deferred charges and other assets 8,312 Accounts payable (4,870 ) Accrued expenses (28,347 ) Deferred tax liability (20,577 ) Noncontrolling interest (16,965 ) Estimated fair value of net assets acquired $ 565,304
Business Acquisition, Pro Forma Information	The unaudited pro forma financial information includes the depreciation and amortization expense related to the acquisition and interest expense associated with the financing of the Chalmette Acquisition. Nine Months Ended September 30, 2015 Pro forma revenues $ 13,151,698 Pro forma net income attributable to PBF Holding Company LLC $ 682,671 The unaudited amount of revenues and net income above have been calculated after conforming accounting policies of the Torrance refinery and related logistics assets to those of the Company and certain one-time adjustments. Nine Months Ended September 30, 2016 Nine Months Ended September 30, 2015 Pro forma revenues $ 12,243,582 $ 12,195,070 Pro forma net income (loss) attributable to PBF Holding LLC $ (60,908 ) $ 115,236	The unaudited pro forma financial information includes the depreciation and amortization expense related to the acquisition and interest expense associated with the Chalmette acquisition financing. Years ended December 31, (Unaudited) 2015 2014 Revenues $ 16,811,922 $ 26,685,661 Net income attributable to PBF Holdings LLC 397,108 47,030

INVENTORIES (Tables)

INVENTORIES (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventories consisted of the following: September 30, 2016 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 1,218,399 $ — $ 1,218,399 Refined products and blendstocks 976,556 359,297 1,335,853 Warehouse stock and other 87,846 — 87,846 $ 2,282,801 $ 359,297 $ 2,642,098 Lower of cost or market reserve (677,448 ) (119,055 ) (796,503 ) Total inventories $ 1,605,353 $ 240,242 $ 1,845,595 December 31, 2015 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 1,137,605 $ — $ 1,137,605 Refined products and blendstocks 687,389 411,357 1,098,746 Warehouse stock and other 55,257 — 55,257 $ 1,880,251 $ 411,357 $ 2,291,608 Lower of cost or market reserve (966,564 ) (150,772 ) (1,117,336 ) Total inventories $ 913,687 $ 260,585 $ 1,174,272 Inventories consisted of the following: September 30, 2016 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 1,218,399 $ — $ 1,218,399 Refined products and blendstocks 976,556 359,297 1,335,853 Warehouse stock and other 87,846 — 87,846 $ 2,282,801 $ 359,297 $ 2,642,098 Lower of cost or market reserve (677,448 ) (119,055 ) (796,503 ) Total inventories $ 1,605,353 $ 240,242 $ 1,845,595 December 31, 2015 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 1,137,605 $ — $ 1,137,605 Refined products and blendstocks 687,389 411,357 1,098,746 Warehouse stock and other 55,257 — 55,257 $ 1,880,251 $ 411,357 $ 2,291,608 Lower of cost or market reserve (966,564 ) (150,772 ) (1,117,336 ) Total inventories $ 913,687 $ 260,585 $ 1,174,272	Inventories consisted of the following: December 31, 2015 Titled Inventory Inventory Supply and Offtake Arrangements Total Crude oil and feedstocks $ 1,137,605 $ — $ 1,137,605 Refined products and blendstocks 687,389 411,357 1,098,746 Warehouse stock and other 55,257 — 55,257 $ 1,880,251 $ 411,357 $ 2,291,608 Lower of cost or market adjustment (966,564 ) (150,772 ) (1,117,336 ) Total inventories $ 913,687 $ 260,585 $ 1,174,272 December 31, 2014 Titled Inventory Inventory Supply and Offtake 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 adjustment (609,774 ) (80,336 ) (690,110 ) Total inventories $ 866,016 $ 236,245 $ 1,102,261

PROPERTY, PLANT AND EQUIPMENT35

PROPERTY, PLANT AND EQUIPMENT, NET (Tables)	12 Months Ended
	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Summary of property, plant and equipment	Depreciation is computed using the straight-line method over the following estimated useful lives: Process units and equipment 5-25 years Pipeline and equipment 5-25 years Buildings 25 years Computers, furniture and fixtures 3-7 years Leasehold improvements 20 years Railcars 50 years Property, plant and equipment consisted of the following: December 31, December 31, Land $ 91,256 $ 59,575 Process units, pipelines and equipment 2,209,712 1,843,157 Buildings and leasehold improvements 34,265 28,397 Computers, furniture and fixtures 72,642 68,431 Construction in progress 150,388 69,413 2,558,263 2,068,973 Less—Accumulated depreciation (347,173 ) (262,913 ) $ 2,211,090 $ 1,806,060

DEFERRED CHARGES AND OTHER AS36

DEFERRED CHARGES AND OTHER ASSETS, NET (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 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 $ 253,823 $ 177,236 Catalyst, net 106,311 77,725 Linefill 19,485 13,504 Restricted cash 1,500 1,500 Environmental credits 37,811 — Intangible assets, net 598 219 Other 29,743 20,529 Total deferred charges and other assets, net $ 449,271 $ 290,713	Deferred charges and other assets, net consisted of the following: December 31, December 31, 2014 Deferred turnaround costs, net $ 177,236 $ 204,987 Catalyst 77,725 77,322 Linefill 13,504 10,230 Restricted cash 1,500 1,521 Intangible assets, net 219 357 Other 20,529 5,972 $ 290,713 $ 300,389
Intangible assets, net		Intangible assets, net was comprised of permits and emission credits as follows: December 31, December 31, 2014 Gross amount $ 3,597 $ 3,599 Accumulated amortization (3,378 ) (3,242 ) Net amount $ 219 $ 357

ACCRUED EXPENSES (Tables)

ACCRUED EXPENSES (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Payables and Accruals [Abstract]
Schedule of accrued expenses	Accrued expenses consisted of the following: September 30, December 31, Inventory-related accruals $ 845,772 $ 548,800 Inventory supply and intermediation arrangements 245,983 252,380 Renewable energy credit and emissions obligations 106,366 19,472 Accrued transportation costs 96,479 91,546 Excise and sales tax payable 70,871 34,129 Accrued utilities 39,390 25,192 Accrued interest 31,838 22,313 Accrued salaries and benefits 14,434 61,011 Accrued construction in progress 14,203 7,400 Customer deposits 12,871 20,395 Environmental liabilities 9,525 — Other 33,756 34,797 Total accrued expenses $ 1,521,488 $ 1,117,435	Accrued expenses consisted of the following: December 31, December 31, 2014 Inventory-related accruals $ 548,800 $ 588,297 Inventory supply and intermediation arrangements 252,380 253,549 Accrued transportation costs 91,546 59,959 Accrued salaries and benefits 61,011 55,993 Excise and sales tax payable 34,129 40,444 Accrued construction in progress 7,400 31,452 Customer deposits 20,395 24,659 Accrued interest 22,313 22,946 Accrued utilities 25,192 22,337 Renewable energy credit obligations 19,472 286 Other 34,797 30,048 $ 1,117,435 $ 1,129,970

CREDIT FACILITY AND LONG-TERM38

CREDIT FACILITY AND LONG-TERM DEBT (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Summary of long-term debt outstanding	Long-term debt outstanding consisted of the following: December 31, 2015 December 31, 2014 2020 Senior Secured Notes $ 669,644 $ 668,520 2023 Senior Secured Notes 500,000 — Revolving Loan — — Rail Facility 67,491 37,270 Catalyst leases 31,802 36,559 Unamortized deferred financing costs (32,217 ) (30,128 ) 1,236,720 712,221 Less—Current maturities — — Long-term debt $ 1,236,720 $ 712,221 Details on the catalyst leases at each of our refineries as of December 31, 2015 are included in the following table: Annual lease fee Annual interest rate Expiration date Paulsboro catalyst lease $ 180 1.95 % December 2016 * Delaware City catalyst lease $ 322 1.96 % October 2016 * Toledo catalyst lease $ 326 1.99 % June 2017 Chalmette catalyst lease $ 185 3.85 % November 2018
Schedule of debt maturing in the next five years and thereafter	Debt maturing in the next five years and thereafter is as follows: Year Ending December 31, 2016 $ 17,252 2017 77,164 2018 4,877 2019 — 2020 669,644 Thereafter 500,000 $ 1,268,937

OTHER LONG-TERM LIABILITIES (Ta

OTHER LONG-TERM LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2015
Other Liabilities Disclosure [Abstract]
Schedule of other long-term liabilities	Other long-term liabilities consisted of the following: December 31, December 31, 2014 Defined benefit pension plan liabilities $ 42,509 $ 40,142 Post retiree medical plan 17,729 14,740 Environmental liabilities 8,189 7,870 Other 1,397 — $ 69,824 $ 62,752

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	9 Months Ended
	Sep. 30, 2016
Related Party Transactions [Abstract]
Summary of revenue and expense transactions with affiliates	A summary of revenue and expense transactions with our affiliates is as follows: Three Months Ended Nine Months Ended 2016 2015 2016 2015 Revenues under affiliate agreements: Omnibus Agreement $ 1,201 $ 1,471 $ 3,460 $ 3,941 Services Agreement 1,280 1,122 3,523 3,412 Total expenses under commercial agreements 43,842 37,082 118,356 104,796

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Future minimum rental payments for operating leases	The fixed and determinable amounts of the obligations under these agreements and total minimum future annual rentals, exclusive of related costs, are approximately: Year Ending December 31, 2016 $ 138,890 2017 131,057 2018 122,286 2019 95,397 2020 94,666 Thereafter 237,435 $ 819,731

STOCK-BASED COMPENSATION (Table

STOCK-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of stock-based compensation expense	Stock-based compensation expense included in general and administrative expenses consisted of the following: Years Ended December 31, 2015 2014 2013 PBF LLC Series A Unit compensatory warrants and options $ — $ 522 $ 779 PBF LLC Series B Units — — 530 PBF Energy options 7,528 4,343 2,051 PBF Energy restricted shares 1,690 1,230 393 $ 9,218 $ 6,095 $ 3,753
Summary of Share-based compensation activity	The following table summarizes activity for PBF LLC Series A compensatory warrants and options for the years ended December 31, 2015 , 2014 and 2013 : Number of PBF LLC Series A Compensatory Warrants and Options Weighted Average Exercise Price Weighted Average Remaining Contractual Life (in years) Stock Based Compensation, Outstanding at January 1, 2013 1,184,726 $ 10.44 8.23 Exercised (301,979 ) 10.11 — Forfeited (41,668 ) 11.27 — Outstanding at December 31, 2013 841,079 $ 10.52 7.40 Exercised (32,934 ) 10.00 — Forfeited (6,666 ) 11.59 — Outstanding at December 31, 2014 801,479 $ 10.53 6.41 Exercised (160,700 ) 10.28 — Outstanding at December 31, 2015 640,779 $ 10.59 5.46 Exercisable and vested at December 31, 2015 640,779 $ 10.59 5.46 Exercisable and vested at December 31, 2014 753,985 $ 10.41 6.34 Exercisable and vested at December 31, 2013 545,247 $ 10.24 7.23 Expected to vest at December 31, 2015 640,779 $ 10.59 5.46 Number of Weighted Weighted Stock-based awards, outstanding at January 1, 2013 682,500 $ 26.00 9.95 Granted 697,500 27.79 10.00 Exercised — — — Forfeited (60,000 ) 25.36 — Outstanding at December 31, 2013 1,320,000 $ 26.97 9.33 Granted 1,135,000 24.78 10.00 Exercised — — — Forfeited (53,125 ) 25.44 — Outstanding at December 31, 2014 2,401,875 $ 25.97 8.67 Granted 1,899,500 30.28 10.00 Exercised (30,000 ) 25.79 — Forfeited (15,000 ) 26.38 — Outstanding at December 31, 2015 4,256,375 $ 27.89 8.32 Exercisable and vested at December 31, 2015 1,136,250 $ 26.22 7.61 Exercisable and vested at December 31, 2014 485,000 $ 26.66 8.21 Exercisable and vested at December 31, 2013 158,125 $ 26.00 8.95 Expected to vest at December 31, 2015 4,256,375 $ 27.89 8.23
Summary of activity for PBF LLC Series B Units	The following table summarizes activity for PBF LLC Series B Units for the year ended December 31, 2013 : Number of Weighted Non-vested units at January 1, 2013 250,000 $ 5.11 Allocated — — Vested (250,000 ) 5.11 Forfeited — — Non-vested units at December 31, 2013 — $ —
Weighted average assumptions	The estimated fair value of PBF Energy options granted during the years ended December 31, 2015 , 2014 and 2013 was determined using the Black-Scholes pricing model with the following weighted average assumptions: December 31, 2015 December 31, 2014 December 31, 2013 Expected life (in years) 6.25 6.25 6.25 Expected volatility 38.4 % 52.0 % 52.1 % Dividend yield 3.96 % 4.82 % 4.43 % Risk-free rate of return 1.58 % 1.80 % 1.53 % Exercise price $ 30.28 $ 24.78 $ 27.79

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Schedule of changes in benefit obligations, fair value of plan assets, and funded status of plan		The changes in the benefit obligation, the changes in fair value of plan assets, and the funded status of the Company’s Pension and Post-Retirement Medical Plans as of and for the years ended December 31, 2015 and 2014 were as follows: Pension Plans Post-Retirement Medical Plan 2015 2014 2015 2014 Change in benefit obligation: Benefit obligation at beginning of year $ 81,098 $ 53,350 $ 14,740 $ 8,225 Service cost 24,298 19,407 967 1,099 Interest cost 2,974 2,404 558 520 Plan amendments — 529 1,533 3,911 Benefit payments (2,231 ) (2,634 ) (381 ) (215 ) Actuarial loss (gain) (6,128 ) 8,042 312 1,200 Projected benefit obligation at end of year $ 100,011 $ 81,098 $ 17,729 $ 14,740 Change in plan assets: Fair value of plan assets at beginning of year $ 40,956 $ 25,050 $ — $ — Actual return on plan assets (13 ) 1,822 — — Benefits paid (2,231 ) (2,634 ) (381 ) (215 ) Employer contributions 18,790 16,718 381 215 Fair value of plan assets at end of year $ 57,502 $ 40,956 $ — $ — Reconciliation of funded status: Fair value of plan assets at end of year $ 57,502 $ 40,956 $ — $ — Less: benefit obligations at end of year 100,011 81,098 17,729 14,740 Funded status at end of year $ (42,509 ) $ (40,142 ) $ (17,729 ) $ (14,740 )
Schedule of expected benefit payments		Benefit payments, which reflect expected future services, that the Company expects to pay are as follows for the years ended December 31: Pension Benefits Post-Retirement Medical Plan 2016 $ 11,125 $ 843 2017 8,271 1,141 2018 9,403 1,296 2019 10,694 1,580 2020 13,429 1,788 Years 2021-2025 88,044 8,835
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 2016 2015 2016 2015 Components of net periodic benefit cost: Service cost $ 10,064 $ 5,790 $ 24,743 $ 17,369 Interest cost 772 710 2,323 2,126 Expected return on plan assets (1,234 ) (830 ) (3,447 ) (2,489 ) Amortization of prior service costs 13 13 39 39 Amortization of loss 328 311 716 933 Net periodic benefit cost $ 9,943 $ 5,994 $ 24,374 $ 17,978 Three Months Ended Nine Months Ended Post Retirement Medical Plan 2016 2015 2016 2015 Components of net periodic benefit cost: Service cost $ 304 $ 243 $ 743 $ 731 Interest cost 131 134 398 403 Amortization of prior service costs 161 76 379 228 Amortization of loss — — — — Net periodic benefit cost $ 596 $ 453 $ 1,520 $ 1,362	The components of net periodic benefit cost were as follows for the years ended December 31, 2015 , 2014 and 2013 : Pension Benefits Post-Retirement Medical Plan 2015 2014 2013 2015 2014 2013 Components of net period benefit cost: Service cost $ 24,298 $ 19,407 $ 14,794 $ 967 $ 1,099 $ 726 Interest cost 2,974 2,404 992 558 520 334 Expected return on plan assets (3,422 ) (2,156 ) (550 ) — — — Amortization of prior service cost 53 39 11 326 258 — Amortization of actuarial loss (gain) 1,228 1,033 421 — (4 ) — Net periodic benefit cost $ 25,131 $ 20,727 $ 15,668 $ 1,851 $ 1,873 $ 1,060
Schedule of pre-tax amounts recognized in other comprehensive income (loss)		The pre-tax amounts recognized in other comprehensive income (loss) for the years ended December 31, 2015 , 2014 and 2013 were as follows: Pension Benefits Post-Retirement Medical Plan 2015 2014 2013 2015 2014 2013 Prior service costs (credits) $ — $ 529 $ — $ 1,533 $ 3,911 $ (860 ) Net actuarial loss (gain) (2,220 ) 8,151 8,235 312 1,201 (1,654 ) Amortization of losses and prior service cost (1,281 ) (1,072 ) (432 ) (326 ) (255 ) — Total changes in other comprehensive loss (income) $ (3,501 ) $ 7,608 $ 7,803 $ 1,519 $ 4,857 $ (2,514 )
Schedule of pre-tax amounts in accumulated other comprehensive loss not yet recognized as components of net periodic costs		The pre-tax amounts in accumulated other comprehensive loss as of December 31, 2015 and 2014 that have not yet been recognized as components of net periodic costs were as follows: Pension Benefits Post-Retirement Medical Plan 2015 2014 2015 2014 Prior service (costs) credits $ (529 ) $ (582 ) $ (3,999 ) $ (2,793 ) Net actuarial (loss) gain (19,841 ) (23,762 ) (391 ) (78 ) Total $ (20,370 ) $ (24,344 ) $ (4,390 ) $ (2,871 )
Schedule of pre-tax amounts in accumulated other comprehensive loss to be recognized over next fiscal year		The following pre-tax amounts included in accumulated other comprehensive loss as of December 31, 2015 are expected to be recognized as components of net period benefit cost during the year ended December 31, 2016 : Pension Benefits Post-Retirement Medical Plan Amortization of prior service costs (credits) $ (53 ) $ (436 ) Amortization of net actuarial loss (gain) (775 ) — Total $ (828 ) $ (436 )
Schedule of assumptions used		The weighted average assumptions used to determine the net periodic benefit costs for the years ended December 31, 2015 , 2014 and 2013 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2015 2014 2013 2015 2014 2013 2015 2014 2013 Discount rate: Service Cost 4.25 % 4.55 % 3.45 % 4.30 % 4.55 % 3.45 % 4.32 % 4.55 % 3.45 % Effective rate for interest cost 3.31 % 4.55 % 3.45 % 3.16 % 4.55 % 3.45 % 3.09 % 4.55 % 3.45 % Effective rate for interest on service cost 3.51 % 4.55 % 3.45 % 3.37 % 4.55 % 3.45 % 4.04 % 4.55 % 3.45 % Expected long-term rate of return on plan assets 7.00 % 6.70 % 3.50 % — % — % — % — % — % — % Rate of compensation increase 4.81 % 4.64 % 4.00 % 5.50 % 4.64 % 4.00 % — % — % — % The weighted average assumptions used to determine the benefit obligations as of December 31, 2015 and 2014 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2015 2014 2015 2014 2015 2014 Discount rate - Benefit obligations 4.17 % 3.70 % 4.22 % 3.70 % 3.76 % 3.70 % Rate of compensation increase 4.81 % 4.96 % 5.50 % 4.96 % — % — %
Schedule of assumed health care cost trend rates		The assumed health care cost trend rates as of December 31, 2015 and 2014 were as follows: Post-Retirement Medical Plan 2015 2014 Health care cost trend rate assumed for next year 6.1 % 6.7 % Rate to which the cost trend rate was assumed to decline (the ultimate trend rate) 4.5 % 4.5 % Year that the rate reached the ultimate trend rate 2038 2027
Schedule of effect of one-percentage-point change in assumed health care cost trend rates		Assumed health care costs trend rates have a significant effect on the amounts reported for retiree health care plans. A one percentage-point change in assumed health care costs trend rates would have the following effects on the medical post-retirement benefits: 1% Increase 1% Decrease Effect on total of service and interest cost components $ 21 $ (20 ) Effect on accumulated post-retirement benefit obligation 413 (388 )
Schedule of fair value of assets of the Company's Qualified Plan		The tables below present the fair values of the assets of the Company’s Qualified Plan as of December 31, 2015 and 2014 by level of fair value hierarchy. Assets categorized in Level 1 of the hierarchy are measured at fair value using a market approach based on published net asset values of mutual funds. As noted above, the Company’s post retirement medical plan is funded on a pay-as-you-go basis and has no assets. Fair Value Measurements Using Quoted Prices in Active Markets (Level 1) December 31, 2015 2014 Equities: Domestic equities $ 17,660 $ 12,682 Developed international equities 8,320 5,600 Emerging market equities 4,017 2,629 Global low volatility equities 4,930 3,478 Fixed-income 22,495 16,517 Cash and cash equivalents 80 50 Total $ 57,502 $ 40,956

REVENUES (Tables)

REVENUES (Tables)	12 Months Ended
	Dec. 31, 2015
Oil and Gas Revenue [Abstract]
Revenues from external customers for each product or group of similar products	The following table provides information relating to the Company’s revenues from external customers for each product or group of similar products for the periods: Year Ended December 31, 2015 2014 2013 Gasoline and distillates $ 11,553,716 $ 17,050,096 $ 16,973,239 Chemicals 452,304 739,096 746,396 Asphalt and blackoils 536,496 706,494 690,305 Lubricants 266,371 410,466 468,315 Feedstocks and other 315,042 922,003 273,200 $ 13,123,929 $ 19,828,155 $ 19,151,455

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	As of September 30, 2016 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 $ 307,508 $ — $ — $ 307,508 N/A $ 307,508 Commodity contracts 24,086 10,440 382 34,908 (30,065 ) 4,843 Derivatives included with inventory intermediation agreement obligations — 6,194 — 6,194 — 6,194 Liabilities: Commodity contracts 26,618 3,447 — 30,065 (30,065 ) — Catalyst lease obligations — 44,286 — 44,286 — 44,286 As of December 31, 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 $ 631,280 $ — $ — $ 631,280 N/A $ 631,280 Commodity contracts 63,810 31,256 3,543 98,609 (52,482 ) 46,127 Derivatives included with inventory intermediation agreement obligations — 35,511 — 35,511 — 35,511 Liabilities: Commodity contracts 49,960 2,522 — 52,482 (52,482 ) — Catalyst lease obligations — 31,802 — 31,802 — 31,802	The tables below present information about the Company's financial assets and liabilities measured and recorded at fair value on a recurring basis and indicate the fair value hierarchy of the inputs utilized to determine the fair values as of December 31, 2015 and 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 December 31, 2015 Fair Value Hierarchy Level 1 Level 2 Level 3 Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Assets: Money market funds $ 631,280 $ — $ — $ 631,280 N/A $ 631,280 Non-qualified pension plan assets 9,325 — — 9,325 N/A 9,325 Commodity contracts 63,810 31,256 3,543 98,609 (52,482 ) 46,127 Derivatives included with inventory supply arrangement obligations — 35,511 — 35,511 — 35,511 Liabilities: Commodity contracts 49,960 2,522 — 52,482 (52,482 ) — Catalyst lease obligations — 31,802 — 31,802 — 31,802 As of December 31, 2014 Level 1 Level 2 Level 3 Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet Assets: Money market funds $ 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 arrangement — 94,834 — 94,834 — 94,834 Derivatives included with inventory supply arrangement obligations — 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, 2016 2015 2016 2015 Balance at beginning of period $ 493 $ 1,905 $ 3,543 $ 1,521 Purchases — — — — Settlements (90 ) (1,238 ) (1,093 ) (12,549 ) Unrealized (loss) gain included in earnings (21 ) (852 ) (2,068 ) 10,843 Transfers into Level 3 — — — — Transfers out of Level 3 — — — — Balance at end of period $ 382 $ (185 ) $ 382 $ (185 )	The table below summarizes the changes in fair value measurements of commodity contracts categorized in Level 3 of the fair value hierarchy: Year Ended December 31, 2015 2014 Balance at beginning of period $ 1,521 $ (23,365 ) Purchases — — Settlements (15,222 ) (22,055 ) Unrealized loss included in earnings 17,244 46,941 Transfers into Level 3 — — Transfers out of Level 3 — — Balance at end of period $ 3,543 $ 1,521
Schedule of Fair value of Debt	The table below summarizes the fair value and carrying value of debt as of September 30, 2016 and December 31, 2015 . September 30, 2016 December 31, 2015 Carrying value Fair value Carrying value Fair value Senior Secured Notes due 2020 (a) $ 670,551 $ 697,649 $ 669,644 $ 706,246 Revolving Loan (b) 550,000 550,000 — — Senior Secured Notes due 2023 (a) 500,000 475,031 500,000 492,452 Rail Facility (b) 56,035 56,035 67,491 67,491 Catalyst leases (c) 44,286 44,286 31,802 31,802 1,820,872 1,823,001 1,268,937 1,297,991 Less - Current maturities — — — — Less - Unamortized deferred financing costs 26,505 n/a 32,217 n/a Long-term debt $ 1,794,367 $ 1,823,001 $ 1,236,720 $ 1,297,991	The table below summarizes the fair value and carrying value as of December 31, 2015 and 2014 . December 31, 2015 December 31, 2014 Carrying value Fair value Carrying value Fair value Senior Secured Notes due 2020 (a) $ 669,644 $ 706,246 $ 668,520 $ 675,580 Senior Secured Notes due 2023 (a) 500,000 492,452 — — Revolving Loan (b) — — — — Rail Facility (b) 67,491 67,491 37,270 37,270 Catalyst leases (c) 31,802 31,802 36,559 36,559 1,268,937 1,297,991 742,349 749,409 Less - Current maturities — — — — Less - Unamortized deferred financing costs $ 32,217 n/a $ 30,128 n/a Long-term debt $ 1,236,720 $ 1,297,991 $ 712,221 $ 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	12 Months Ended
	Sep. 30, 2016	Dec. 31, 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, 2016 and December 31, 2015 and the line items in the condensed 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, 2016: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 6,194 December 31, 2015: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 35,511 Derivatives not designated as hedging instruments: September 30, 2016: Commodity contracts Accounts receivable $ 4,843 December 31, 2015: Commodity contracts Accounts receivable $ 46,127	The following tables provide information about the fair values of these derivative instruments as of December 31, 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: December 31, 2015: Derivatives included with inventory supply arrangement obligations Accrued expenses $ — Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 35,511 December 31, 2014: Derivatives included with inventory supply arrangement obligations Accrued expenses $ 4,251 Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 94,834 Derivatives not designated as hedging instruments: December 31, 2015: Commodity contracts Accounts receivable $ 46,127 December 31, 2014: Commodity contracts Accounts receivable $ 31,155
Schedule of Derivative Instruments, Gain (Loss) Recognized in Income	The following table provides information about the gain or loss recognized in income on these derivative instruments and the line items in the condensed 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, 2016: Derivatives included with the inventory intermediation agreement obligations Cost of sales $ (3,145 ) For the three months ended September 30, 2015: Derivatives included with inventory supply arrangement obligations Cost of sales $ 1,409 Derivatives included with the inventory intermediation agreement obligations Cost of sales $ 34,424 For the nine months ended September 30, 2016: Derivatives included with the inventory intermediation agreement obligations Cost of sales $ (29,317 ) For the nine months ended September 30, 2015: Derivatives included with inventory supply arrangement obligations Cost of sales $ (3,220 ) Derivatives included with the inventory intermediation agreement obligations Cost of sales $ (50,150 ) Derivatives not designated as hedging instruments: For the three months ended September 30, 2016: Commodity contracts Cost of sales $ (15,559 ) For the three months ended September 30, 2015: Commodity contracts Cost of sales $ 31,017 For the nine months ended September 30, 2016: Commodity contracts Cost of sales $ (54,646 ) For the nine months ended September 30, 2015: Commodity contracts Cost of sales $ (14,080 ) Hedged items designated in fair value hedges: For the three months ended September 30, 2016: Intermediate and refined product inventory Cost of sales $ 3,145 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 nine months ended September 30, 2016: Intermediate and refined product inventory Cost of sales $ 29,317 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	The following tables provide information about the gains or losses 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 year ended December 31, 2015: Derivatives included with inventory supply arrangement obligations Cost of sales $ (4,251 ) Derivatives included with the inventory intermediation agreement obligations Cost of sales $ (59,323 ) For the year ended December 31, 2014: Derivatives included with inventory supply arrangement obligations Cost of sales $ 4,428 Derivatives included with the inventory intermediation agreement obligations Cost of sales $ 88,818 For the year ended December 31, 2013 Derivatives included with inventory supply arrangement obligations Cost of sales $ (5,773 ) Derivatives included with the inventory intermediation agreement obligations Cost of sales $ 6,016 Derivatives not designated as hedging instruments: For the year ended December 31, 2015: Commodity contracts Cost of sales $ 32,416 For the year ended December 31, 2014: Commodity contracts Cost of sales $ 146,016 For the year ended December 31, 2013 Commodity contracts Cost of sales $ (88,962 ) Hedged items designated in fair value hedges: For the year ended December 31, 2015: Crude oil and feedstock inventory Cost of sales $ 4,251 Intermediate and refined product inventory Cost of sales $ 59,323 For the year ended December 31, 2014: Crude oil and feedstock inventory Cost of sales $ (4,428 ) Intermediate and refined product inventory Cost of sales $ (88,818 ) For the year ended December 31, 2013 Crude oil and feedstock inventory Cost of sales $ (1,491 ) Intermediate and refined product inventory Cost of sales $ (6,016 )

CONSOLIDATING FINANCIAL STATE47

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Tables)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Condensed Financial Information of Subsidiary Disclosure [Abstract]
Condensed Consolidating Balance Sheet	CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) September 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 456,179 $ 20,531 $ 44,534 $ (1,869 ) $ 519,375 Accounts receivable 636,625 7,362 5,670 — 649,657 Accounts receivable - affiliate 21 — 3,020 — 3,041 Inventories 1,640,072 — 205,523 — 1,845,595 Prepaid expense and other current assets 30,573 22,026 2,491 — 55,090 Due from related parties 23,111,940 21,567,312 4,215,051 (48,894,303 ) — Total current assets 25,875,410 21,617,231 4,476,289 (48,896,172 ) 3,072,758 Property, plant and equipment, net 34,647 2,303,359 321,377 — 2,659,383 Investment in subsidiaries 1,072,153 605,169 — (1,677,322 ) — Investment in equity method investee — — 176,267 — 176,267 Deferred charges and other assets, net 31,696 416,062 1,513 — 449,271 Total assets $ 27,013,906 $ 24,941,821 $ 4,975,446 $ (50,573,494 ) $ 6,357,679 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 234,062 $ 133,195 $ 2,441 $ (1,869 ) $ 367,829 Accounts payable - affiliate 31,746 — — — 31,746 Accrued expenses 1,240,409 160,036 121,043 — 1,521,488 Deferred tax liabilities — — 27,989 — 27,989 Deferred revenue 10,602 — 1,470 — 12,072 Due to related parties 21,414,670 23,247,282 4,232,351 (48,894,303 ) — Total current liabilities 22,931,489 23,540,513 4,385,294 (48,896,172 ) 1,961,124 Delaware Economic Development Authority loan — 4,000 — — 4,000 Long-term debt 1,694,390 44,219 55,758 — 1,794,367 Affiliate notes payable 470,165 — — — 470,165 Deferred tax liabilities — — 25,721 — 25,721 Other long-term liabilities 29,195 176,821 7,619 — 213,635 Total liabilities 25,125,239 23,765,553 4,474,392 (48,896,172 ) 4,469,012 Commitments and contingencies Equity: Member's equity 1,494,477 1,733,830 433,421 (2,167,251 ) 1,494,477 Retained earnings (accumulated deficit) 404,777 (562,045 ) 67,633 494,412 404,777 Accumulated other comprehensive (loss) income (23,307 ) (8,237 ) — 8,237 (23,307 ) Total PBF Holding Company LLC equity 1,875,947 1,163,548 501,054 (1,664,602 ) 1,875,947 Noncontrolling interest 12,720 12,720 — (12,720 ) 12,720 Total equity 1,888,667 1,176,268 501,054 (1,677,322 ) 1,888,667 Total liabilities and equity $ 27,013,906 $ 24,941,821 $ 4,975,446 $ (50,573,494 ) $ 6,357,679 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) December 31, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 882,820 $ 6,236 $ 28,968 $ (3,275 ) $ 914,749 Accounts receivable 430,809 11,057 12,893 — 454,759 Accounts receivable - affiliate 917 2,521 — — 3,438 Inventories 608,646 363,151 202,475 — 1,174,272 Prepaid expense and other current assets 24,243 9,074 384 — 33,701 Due from related parties 20,236,649 20,547,503 3,262,382 (44,046,534 ) — Total current assets 22,184,084 20,939,542 3,507,102 (44,049,809 ) 2,580,919 Property, plant and equipment, net 25,240 1,960,066 225,784 — 2,211,090 Investment in subsidiaries 1,740,111 143,349 — (1,883,460 ) — Investment in equity method investee — — — — — Deferred charges and other assets, net 23,973 265,240 1,500 — 290,713 Due from related party - long term — — 20,577 (20,577 ) — Total assets $ 23,973,408 $ 23,308,197 $ 3,754,963 $ (45,953,846 ) $ 5,082,722 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 196,988 $ 113,564 $ 7,566 $ (3,275 ) $ 314,843 Accounts Payable - affiliate 23,949 — — — 23,949 Accrued expenses 503,179 495,842 118,414 — 1,117,435 Deferred revenue 4,043 — — — 4,043 Due to related parties 19,787,807 21,026,310 3,232,417 (44,046,534 ) — Total current liabilities 20,515,966 21,635,716 3,358,397 (44,049,809 ) 1,460,270 Delaware Economic Development Authority loan — 4,000 — — 4,000 Long-term debt 1,137,980 31,717 67,023 — 1,236,720 Affiliate notes payable 470,047 — — — 470,047 Deferred tax liability — — 20,577 — 20,577 Other long-term liabilities 28,131 41,693 — — 69,824 Due to related party - long term — 20,577 — (20,577 ) — Total liabilities 22,152,124 21,733,703 3,445,997 (44,070,386 ) 3,261,438 Commitments and contingencies Equity: Member's equity 1,479,175 1,062,717 182,696 (1,245,413 ) 1,479,175 Retained earnings (accumulated deficit) 349,654 502,788 126,270 (629,058 ) 349,654 Accumulated other comprehensive (loss) income (24,770 ) (8,236 ) — 8,236 (24,770 ) Total PBF Holding Company LLC equity 1,804,059 1,557,269 308,966 (1,866,235 ) 1,804,059 Noncontrolling interest 17,225 17,225 — (17,225 ) 17,225 Total equity 1,821,284 1,574,494 308,966 (1,883,460 ) 1,821,284 Total liabilities and equity $ 23,973,408 $ 23,308,197 $ 3,754,963 $ (45,953,846 ) $ 5,082,722	December 31, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 882,820 $ 6,236 $ 28,968 $ (3,275 ) $ 914,749 Accounts receivable 430,809 11,057 12,893 — 454,759 Accounts receivable - affiliate 917 2,521 — — 3,438 Inventories 608,646 363,151 202,475 — 1,174,272 Prepaid expense and other current assets 24,243 9,074 384 — 33,701 Due from related parties 20,236,649 20,547,503 3,262,382 (44,046,534 ) — Total current assets 22,184,084 20,939,542 3,507,102 (44,049,809 ) 2,580,919 Property, plant and equipment, net 25,240 1,960,066 225,784 — 2,211,090 Investment in subsidiaries 1,740,111 143,349 — (1,883,460 ) — Deferred charges and other assets, net 23,973 265,240 1,500 — 290,713 Due from related party - long term — — 20,577 (20,577 ) — Total assets $ 23,973,408 $ 23,308,197 $ 3,754,963 $ (45,953,846 ) $ 5,082,722 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 196,988 $ 113,564 $ 7,566 $ (3,275 ) $ 314,843 Accounts payable - affiliate 23,949 — — — 23,949 Accrued expenses 503,179 495,842 118,414 — 1,117,435 Current portion of long-term debt — — — — — Deferred revenue 4,043 — — — 4,043 Due to related parties 19,787,807 21,026,310 3,232,417 (44,046,534 ) — Total current liabilities 20,515,966 21,635,716 3,358,397 (44,049,809 ) 1,460,270 Delaware Economic Development Authority loan — 4,000 — — 4,000 Long-term debt 1,137,980 31,717 67,023 — 1,236,720 Intercompany notes payable 470,047 — — — 470,047 Deferred tax liability — — 20,577 — 20,577 Other long-term liabilities 28,131 41,693 — — 69,824 Due to related party - long term — 20,577 — (20,577 ) — Total liabilities 22,152,124 21,733,703 3,445,997 (44,070,386 ) 3,261,438 Commitments and contingencies Equity: Member's equity 1,479,175 1,062,717 182,696 (1,245,413 ) 1,479,175 Retained earnings 349,654 502,788 126,270 (629,058 ) 349,654 Accumulated other comprehensive loss (24,770 ) (8,236 ) — 8,236 (24,770 ) Total PBF Holding Company LLC equity 1,804,059 1,557,269 308,966 (1,866,235 ) 1,804,059 Noncontrolling interest 17,225 17,225 — (17,225 ) $ 17,225 Total equity 1,821,284 1,574,494 308,966 (1,883,460 ) 1,821,284 Total liabilities and equity $ 23,973,408 $ 23,308,197 $ 3,754,963 $ (45,953,846 ) $ 5,082,722 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING BALANCE SHEET 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 5,899 292,990 1,500 — 300,389 Total assets $ 20,075,456 $ 21,252,546 $ 1,860,183 $ (39,174,423 ) $ 4,013,762 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 Current portion of long-term debt — — — — — 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 639,579 36,451 36,191 — 712,221 Intercompany notes payable 122,264 — — — 122,264 Other long-term liabilities 22,206 40,546 — — 62,752 Total liabilities 18,444,940 18,779,962 1,763,131 (36,604,787 ) 2,383,246 Commitments and contingencies Equity: Member's equity 1,144,100 749,278 44,346 (793,624 ) 1,144,100 Retained earnings 513,292 1,731,694 52,706 (1,784,400 ) 513,292 Accumulated other comprehensive loss (26,876 ) (8,388 ) — 8,388 (26,876 ) Total PBF Holding Company LLC equity 1,630,516 2,472,584 97,052 (2,569,636 ) 1,630,516 Noncontrolling interest — — — — — Total equity 1,630,516 2,472,584 97,052 (2,569,636 ) 1,630,516 Total liabilities and equity $ 20,075,456 $ 21,252,546 $ 1,860,183 $ (39,174,423 ) $ 4,013,762
Condensed Consolidating Statement of Operations and Comprehensive Income (Loss)	CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Three Months Ended September 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 4,488,925 $ 441,554 $ 345,215 $ (767,081 ) $ 4,508,613 Costs and expenses Cost of sales, excluding depreciation 3,914,018 428,587 328,734 (767,081 ) 3,904,258 Operating expenses, excluding depreciation 25 385,761 18,259 — 404,045 General and administrative expenses 34,820 4,312 780 — 39,912 Equity (income) loss in investee — — (1,621 ) — (1,621 ) Loss (gain) on sale of assets 2,418 73 5,668 — 8,159 Depreciation and amortization expense 1,341 47,472 3,865 — 52,678 3,952,622 866,205 355,685 (767,081 ) 4,407,431 Income (loss) from operations 536,303 (424,651 ) (10,470 ) — 101,182 Other income (expense) Equity in (loss) earnings of subsidiaries (438,249 ) — — 438,249 — Change in fair value of catalyst lease — 77 — — 77 Interest expense, net (32,982 ) (447 ) (467 ) — (33,896 ) Net income (loss) before income taxes 65,072 (425,021 ) (10,937 ) 438,249 67,363 Income tax (benefit) expense — — 2,291 — 2,291 Net income (loss) 65,072 (425,021 ) (13,228 ) 438,249 65,072 Less: net income (loss) attributable to noncontrolling interest 45 45 — (45 ) 45 Net income (loss) attributable to PBF Holding Company LLC $ 65,027 $ (425,066 ) $ (13,228 ) $ 438,294 $ 65,027 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 65,453 $ (425,066 ) $ (13,228 ) $ 438,294 $ 65,453 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Three Months Ended September 30, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 3,215,163 $ 132,000 $ 422,306 $ (551,829 ) $ 3,217,640 Costs and expenses Cost of sales, excluding depreciation 2,843,303 176,823 390,112 (551,829 ) 2,858,409 Operating expenses, excluding depreciation (95 ) 200,384 (275 ) — 200,014 General and administrative expenses 40,002 6,827 973 — 47,802 Equity (income) loss in investee — — — — — Gain on sale of assets (70 ) 1 (73 ) — (142 ) Depreciation and amortization expense 2,117 43,820 547 — 46,484 2,885,257 427,855 391,284 (551,829 ) 3,152,567 Income (loss) from operations 329,906 (295,855 ) 31,022 — 65,073 Other income (expense) Equity in (loss) earnings of subsidiaries (262,000 ) — — 262,000 — Change in fair value of catalyst lease — 4,994 — — 4,994 Interest expense, net (19,727 ) (1,277 ) (884 ) — (21,888 ) Net income (loss) before income taxes 48,179 (292,138 ) 30,138 262,000 48,179 Income taxes expense — — — — — Net income (loss) 48,179 (292,138 ) 30,138 262,000 48,179 Less: net income attributable to noncontrolling interest — — — — — Net income (loss) attributable to PBF Holding Company LLC $ 48,179 $ (292,138 ) $ 30,138 $ 262,000 $ 48,179 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 48,698 $ (292,138 ) $ 30,138 $ 262,000 $ 48,698 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Nine Months Ended September 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 11,119,301 $ 586,336 $ 1,005,656 $ (1,546,722 ) $ 11,164,571 Costs and expenses Cost of sales, excluding depreciation 9,653,945 532,040 995,726 (1,546,722 ) 9,634,989 Operating expenses, excluding depreciation (375 ) 948,403 24,195 — 972,223 General and administrative expenses 92,126 20,372 (1,226 ) — 111,272 Equity (income) loss in investee — — (1,621 ) — (1,621 ) Loss on sale of assets 2,418 97 8,866 — 11,381 Depreciation and amortization expense 4,417 143,994 7,479 — 155,890 9,752,531 1,644,906 1,033,419 (1,546,722 ) 10,884,134 Income (loss) from operations 1,366,770 (1,058,570 ) (27,763 ) — 280,437 Other income (expense) Equity in (loss) earnings of subsidiaries (1,123,054 ) — — 1,123,054 — Change in fair value of catalyst lease — (4,556 ) — — (4,556 ) Interest expense, net (95,568 ) (1,289 ) (1,589 ) — (98,446 ) Net income (loss) before income taxes 148,148 (1,064,415 ) (29,352 ) 1,123,054 177,435 Income taxes expense — — 29,287 — 29,287 Net income (loss) 148,148 (1,064,415 ) (58,639 ) 1,123,054 148,148 Less: net income attributable to noncontrolling interest 438 438 — (438 ) 438 Net income (loss) attributable to PBF Holding Company LLC $ 147,710 $ (1,064,853 ) $ (58,639 ) $ 1,123,492 $ 147,710 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 149,173 $ (1,064,853 ) $ (58,639 ) $ 1,123,492 $ 149,173 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Nine Months Ended September 30, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 9,737,169 $ 668,576 $ 1,250,957 $ (1,893,262 ) $ 9,763,440 Costs and expenses Cost of sales, excluding depreciation 8,370,720 749,706 1,187,259 (1,893,262 ) 8,414,423 Operating expenses, excluding depreciation (3,814 ) 629,846 (490 ) — 625,542 General and administrative expenses 98,330 15,987 1,798 — 116,115 Equity (income) loss in investee — — — — — Gain on sale of assets (251 ) (232 ) (650 ) — (1,133 ) Depreciation and amortization expense 7,664 130,496 1,597 — 139,757 8,472,649 1,525,803 1,189,514 (1,893,262 ) 9,294,704 Income (loss) from operations 1,264,520 (857,227 ) 61,443 — 468,736 Other income (expense) Equity in earnings (loss) of subsidiaries (793,606 ) — — 793,606 — Change in fair value of catalyst lease — 8,982 — — 8,982 Interest expense, net (59,111 ) (4,342 ) (2,462 ) — (65,915 ) Net income (loss) before income taxes 411,803 (852,587 ) 58,981 793,606 411,803 Income taxes expense — — — — — Net income (loss) 411,803 (852,587 ) 58,981 793,606 411,803 Less: net income attributable to noncontrolling interest — — — — — Net income (loss) attributable to PBF Holding Company LLC $ 411,803 $ (852,587 ) $ 58,981 $ 793,606 $ 411,803 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 413,118 $ (852,587 ) $ 58,981 $ 793,606 $ 413,118	Year Ended December 31, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 13,085,122 $ 884,930 $ 1,633,818 $ (2,479,941 ) $ 13,123,929 Costs and expenses: Cost of sales, excluding depreciation 11,514,115 1,026,846 1,550,579 (2,479,941 ) 11,611,599 Operating expenses, excluding depreciation (3,683 ) 891,534 1,517 — 889,368 General and administrative expenses 143,580 21,016 2,308 — 166,904 Gain on sale of asset (249 ) (105 ) (650 ) — (1,004 ) Depreciation and amortization expense 9,687 178,578 2,845 — 191,110 11,663,450 2,117,869 1,556,599 (2,479,941 ) 12,857,977 Income (loss) from operations 1,421,672 (1,232,939 ) 77,219 — 265,952 Other income (expense): Equity in earnings of subsidiaries (1,154,420 ) — — 1,154,420 — Change in fair value of catalyst lease — 10,184 — — 10,184 Interest expense, net (79,310 ) (5,876 ) (3,008 ) — (88,194 ) Income (loss) before income taxes 187,942 (1,228,631 ) 74,211 1,154,420 187,942 Income tax expense (benefit) — — 648 — 648 Net income (loss) 187,942 (1,228,631 ) 73,563 1,154,420 187,294 Less net income attributable to noncontrolling interests 274 274 — (274 ) 274 Net income (loss) attributable to PBF Holding Company LLC $ 187,668 $ (1,228,905 ) $ 73,563 $ 1,154,694 $ 187,020 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 189,774 $ (1,228,905 ) $ 73,563 $ 1,154,694 $ 189,126 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Year Ended December 31, 2014 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 19,847,045 $ 1,402,253 $ 1,007,407 $ (2,428,550 ) $ 19,828,155 Costs and expenses: Cost of sales, excluding depreciation 18,467,533 1,522,901 952,170 (2,428,550 ) 18,514,054 Operating expenses, excluding depreciation 218 880,339 144 — 880,701 General and administrative expenses 123,692 16,259 199 — 140,150 (Gain) loss on sale of asset (277 ) — (618 ) — (895 ) Depreciation and amortization expense 13,583 164,525 888 — 178,996 18,604,749 2,584,024 952,783 (2,428,550 ) 19,713,006 Income (loss) from operations 1,242,296 (1,181,771 ) 54,624 — 115,149 Other income (expense): Equity in earnings (loss) of subsidiaries (1,131,321 ) — — 1,131,321 — Change in fair value of catalyst lease — 3,969 — — 3,969 Interest expense, net (89,858 ) (6,225 ) (1,918 ) — (98,001 ) Income (loss) before income taxes 21,117 (1,184,027 ) 52,706 1,131,321 21,117 Income tax expense (benefit) — — — — — Net income (loss) 21,117 (1,184,027 ) 52,706 1,131,321 21,117 Less net income attributable to noncontrolling interests — — — — — Net income (loss) attributable to PBF Holding Company LLC $ 21,117 $ (1,184,027 ) $ 52,706 $ 1,131,321 $ 21,117 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 8,779 $ (1,194,031 ) $ 52,706 $ 1,141,325 $ 8,779 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Year Ended December 31, 2013 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 16,190,178 $ 7,641,498 $ — $ (4,680,221 ) $ 19,151,455 Costs and expenses: Cost of sales, excluding depreciation 16,486,851 5,996,684 — (4,680,221 ) 17,803,314 Operating expenses, excluding depreciation (482 ) 813,134 — — 812,652 General and administrative expenses 82,284 13,510 — — 95,794 Gain on sale of assets (388 ) 205 — — (183 ) Depreciation and amortization expense 12,856 98,623 — — 111,479 16,581,121 6,922,156 — (4,680,221 ) 18,823,056 (Loss) income from operations (390,943 ) 719,342 — — 328,399 Other income (expense): Equity in earnings (loss) of subsidiaries 722,673 — — (722,673 ) — Change in fair value of contingent consideration — — — — — Change in fair value of catalyst lease — 4,691 — — 4,691 Interest expense, net (92,854 ) (1,360 ) — — (94,214 ) Income (loss) before income taxes 238,876 722,673 — (722,673 ) 238,876 Income tax expense (benefit) — — — — — Net income (loss) 238,876 722,673 — (722,673 ) 238,876 Less net income attributable to noncontrolling interests — — — — — Net income (loss) attributable to PBF Holding Company LLC $ 238,876 $ 722,673 $ — $ (722,673 ) $ 238,876 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 233,279 $ 724,930 $ — $ (724,930 ) $ 233,279
Condensed Consolidating Statement of Cash Flow	CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF CASH FLOW (UNAUDITED) Nine Months Ended September 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 148,148 $ (1,064,415 ) $ (58,639 ) $ 1,123,054 $ 148,148 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 10,828 144,011 7,726 — 162,565 Stock-based compensation — 12,658 — — 12,658 Change in fair value of catalyst lease obligations — 4,556 — — 4,556 Deferred income taxes — — 27,813 — 27,813 Change in non-cash lower of cost or market inventory adjustment (320,833 ) — — — (320,833 ) Non-cash change in inventory repurchase obligations 29,317 — — — 29,317 Pension and other post retirement benefit costs 5,249 20,645 — — 25,894 Loss (gain) on sale of assets 2,418 97 8,866 — 11,381 Equity in earnings of subsidiaries 1,123,054 — — (1,123,054 ) — Equity (income) loss in investee — — (1,621 ) — (1,621 ) Changes in current assets and current liabilities: Accounts receivable (205,816 ) 3,695 7,223 — (194,898 ) Due to/from affiliates (1,624,741 ) 1,588,690 44,245 — 8,194 Inventories 56,792 — (2,740 ) — 54,052 Prepaid expenses and other current assets (6,330 ) (11,768 ) (2,105 ) — (20,203 ) Accounts payable 37,074 16,943 (5,126 ) 1,406 50,297 Accrued expenses 661,974 (353,030 ) (897 ) — 308,047 Deferred revenue 6,559 — 1,470 — 8,029 Other assets and liabilities (7,573 ) (14,210 ) (97 ) — (21,880 ) Net cash (used in) provided by operating activities (83,880 ) 347,872 26,118 1,406 291,516 Cash flows from investing activities: Acquisition of Torrance refinery and related logistics assets (971,932 ) — — — (971,932 ) Expenditures for property, plant and equipment (16,244 ) (172,174 ) 675 — (187,743 ) Expenditures for deferred turnaround costs — (138,936 ) — — (138,936 ) Expenditures for other assets — (27,735 ) — — (27,735 ) Investment in subsidiaries 12,800 — — (12,800 ) — Chalmette Acquisition working capital settlement — (2,659 ) — — (2,659 ) Proceeds from sale of assets — — 13,030 — 13,030 Net cash provided by (used in) investing activities (975,376 ) (341,504 ) 13,705 (12,800 ) (1,315,975 ) Cash flows from financing activities: Proceeds from catalyst lease — 7,927 — — 7,927 Contributions from PBF LLC related to TVPC 175,000 — — — 175,000 Distribution to Parent — — (12,800 ) 12,800 — Distribution to members (92,503 ) — — — (92,503 ) Proceeds from affiliate notes payable 635 — — — 635 Repayments of affiliate notes payable (517 ) — — — (517 ) Proceeds from revolver borrowings 550,000 — — — 550,000 Repayments of Rail Facility revolver borrowings — — (11,457 ) — (11,457 ) Net cash provided by (used in) financing activities 632,615 7,927 (24,257 ) 12,800 629,085 Net increase in cash and cash equivalents (426,641 ) 14,295 15,566 1,406 (395,374 ) Cash and cash equivalents, beginning of period 882,820 6,236 28,968 (3,275 ) 914,749 Cash and cash equivalents, end of period $ 456,179 $ 20,531 $ 44,534 $ (1,869 ) $ 519,375 14. 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 from 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 ) Non-cash change in inventory repurchase obligations — 53,370 — — 53,370 Change in non-cash lower of cost of market inventory adjustment (2,091 ) 83,238 — — 81,147 Pension and other post retirement benefit costs 5,769 13,571 — — 19,340 Equity income in investee — — — — — Gain on sale of assets (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 refinery turnarounds 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 provided by (used in) 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 ) — Distributions to Parent — — (10,000 ) 10,000 — Proceeds from affiliate notes payable 29,773 — — — 29,773 Proceeds from Rail Facility revolver borrowings — — 102,075 — 102,075 Repayments of Rail Facility revolver borrowing — — (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 cash equivalents, beginning of period 185,381 704 34,334 (2,016 ) 218,403 Cash and cash equivalents, end of period $ 361,037 $ 3 $ 10,231 $ (1,850 ) $ 369,421	Year Ended December 31, 2015 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 187,942 $ (1,228,631 ) $ 73,563 $ 1,154,420 $ 187,294 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 17,063 178,601 3,719 — 199,383 Stock-based compensation — 9,218 — — 9,218 Change in fair value of catalyst lease obligation — (10,184 ) — — (10,184 ) Non-cash change in inventory repurchase obligations — 63,389 — — 63,389 Non-cash lower of cost or market inventory adjustment 279,785 147,441 — — 427,226 Pension and other post retirement benefit costs 7,576 19,406 — — 26,982 Gain on disposition of property, plant and equipment (249 ) (105 ) (650 ) — (1,004 ) Equity in earnings of subsidiaries 1,154,420 — — (1,154,420 ) — Changes in current assets and current liabilities: Accounts receivable 87,689 16,124 (6,177 ) — 97,636 Amounts due to/from related parties (1,018,176 ) 1,133,364 (103,084 ) — 12,104 Inventories (108,751 ) (116,074 ) (47,067 ) — (271,892 ) Other current assets 2,721 (2,999 ) (353 ) — (631 ) Accounts payable (38,609 ) 15,710 (857 ) (1,259 ) (25,015 ) Accrued expenses 27,925 8,172 (73,834 ) — (37,737 ) Deferred revenue 2,816 — — — 2,816 Other assets and liabilities (423 ) (26,769 ) 10 — (27,182 ) Net cash provided by (used in) operating activities 601,729 206,663 (154,730 ) (1,259 ) 652,403 Cash flows from investing activities: Acquisition of Chalemtte refinery, net of cash received from sale of assets (601,311 ) 19,042 16,965 — (565,304 ) Expenditures for property, plant and equipment (193,898 ) (158,361 ) (106 ) — (352,365 ) Expenditures for refinery turnarounds costs — (53,576 ) — — (53,576 ) Expenditures for other assets — (8,236 ) — — (8,236 ) Investment in subsidiaries 10,000 — — (10,000 ) — Capital contributions to subsidiaries (5,000 ) — — 5,000 — Proceeds from sale of assets 60,902 — 107,368 — 168,270 Net cash (used in) provided by investing activities (729,307 ) (201,131 ) 124,227 (5,000 ) (811,211 ) 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF CASH FLOW (Continued) Cash flows from financing activities: Proceeds from member's capital contributions 345,000 — 5,000 (5,000 ) 345,000 Distribution to parent — — (10,000 ) 10,000 — Distributions to members (350,658 ) — — — (350,658 ) Proceeds from intercompany notes payable 347,783 — — — 347,783 Proceeds from revolver borrowings 170,000 — — — 170,000 Repayments of revolver borrowings (170,000 ) — — — (170,000 ) Proceeds from Rail Facility revolver borrowings — — 102,075 — 102,075 Repayments of Rail Facility revolver borrowings — — (71,938 ) — (71,938 ) Proceeds form Senior Secured Notes 500,000 — — — 500,000 Deferred financing costs and other (17,108 ) — — — (17,108 ) Net cash provided by financing activities 825,017 — 25,137 5,000 855,154 Net increase (decrease) in cash and cash equivalents 697,439 5,532 (5,366 ) (1,259 ) 696,346 Cash and equivalents, beginning of period 185,381 704 34,334 (2,016 ) 218,403 Cash and equivalents, end of period $ 882,820 $ 6,236 $ 28,968 $ (3,275 ) $ 914,749 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF CASH FLOW Year Ended December 31, 2014 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 21,117 $ (1,184,027 ) $ 52,706 $ 1,131,321 $ 21,117 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 20,334 164,550 1,528 — 186,412 Stock-based compensation — 6,095 — — 6,095 Change in fair value of catalyst lease obligation — (3,969 ) — — (3,969 ) Non-cash change in inventory repurchase obligations — (93,246 ) — — (93,246 ) Non-cash lower of cost or market inventory adjustment 566,412 123,698 — — 690,110 Gain on disposition of property, plant and equipment (277 ) — (618 ) — (895 ) Pension and other post retirement benefit cost 6,426 16,174 — — 22,600 Equity in earnings of subsidiaries 1,131,321 — — (1,131,321 ) — Changes in current assets and current liabilities: Accounts receivable 69,887 (17,976 ) (6,533 ) — 45,378 Amounts due to/from related parties (1,227,851 ) 1,328,439 (92,181 ) — 8,407 Inventories (259,352 ) 20,711 (155,390 ) — (394,031 ) Other current assets 22,287 1,399 — — 23,686 Accounts payable (71,821 ) (1,697 ) 8,423 (2,016 ) (67,111 ) Accrued expenses (131,903 ) 471 191,331 — 59,899 Deferred revenue (6,539 ) — — — (6,539 ) Other assets and liabilities (1,966 ) (258 ) (1 ) — (2,225 ) Net cash provided by (used in) operating activities 138,075 360,364 (735 ) (2,016 ) 495,688 Cash flows from investing activities: Expenditures for property, plant and equipment (152,814 ) (205,508 ) (112,138 ) — (470,460 ) Expenditures for refinery turnarounds costs — (137,688 ) — — (137,688 ) Expenditures for other assets — (17,255 ) — — (17,255 ) Investment in subsidiaries (44,346 ) — — 44,346 — Proceeds from sale of assets 133,845 — 68,809 — 202,654 Net cash (used in) provided by investing activities (63,315 ) (360,451 ) (43,329 ) 44,346 (422,749 ) Cash flows from financing activities: Proceeds from member's capital contributions 328,664 — 44,346 (44,346 ) 328,664 Distributions to members (361,352 ) — — — (361,352 ) Proceeds from intercompany notes payable 90,631 — — — 90,631 Proceeds from revolver borrowings 395,000 — — — 395,000 Repayments of revolver borrowings (410,000 ) — — — (410,000 ) Proceeds from Rail Facility revolver borrowings — — 83,095 — 83,095 Repayments of Rail Facility revolver borrowings — — (45,825 ) — (45,825 ) Deferred financing costs and other (8,501 ) — (3,218 ) — (11,719 ) Net cash provided by (used in) financing activities 34,442 — 78,398 (44,346 ) 68,494 Net increase (decrease) in cash and cash equivalents 109,202 (87 ) 34,334 (2,016 ) 141,433 Cash and equivalents, beginning of period 76,179 791 — — 76,970 Cash and equivalents, end of period $ 185,381 $ 704 $ 34,334 $ (2,016 ) $ 218,403 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF CASH FLOW Year Ended December 31, 2013 Issuer Guarantors Subsidiaries Non-Guarantors Subsidiaries Combining and Consolidated Adjustments Total Cash flows from operating activities: Net income $ 238,876 $ 722,673 $ — $ (722,673 ) $ 238,876 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 19,296 98,705 — — 118,001 Stock-based compensation — 3,753 — — 3,753 Change in fair value of catalyst lease obligation — (4,691 ) — — (4,691 ) Non-cash change in inventory repurchase obligations — (20,492 ) — — (20,492 ) Pension and other post retirement benefit costs 4,575 12,153 — — 16,728 Gain on disposition of property, plant and equipment (388 ) 205 — — (183 ) Equity in earnings of subsidiaries (722,673 ) — — 722,673 — Changes in operating assets and liabilities: Accounts receivable (281,386 ) 188,535 — — (92,851 ) Amounts due to/from related parties 626,623 (611,902 ) — — 14,721 Inventories (153,782 ) 199,773 — — 45,991 Other current assets (40,416 ) (2,039 ) — — (42,455 ) Accounts payable 109,988 (67,752 ) — — 42,236 Accrued expenses 222,194 (7,377 ) — — 214,817 Deferred revenue 7,766 (210,543 ) — — (202,777 ) Other assets and liabilities (1,140 ) (19,263 ) — — (20,403 ) Net cash provided by operating activities 29,533 281,738 — — 311,271 Cash flows from investing activities: Expenditures for property, plant and equipment (127,653 ) (190,741 ) — — (318,394 ) Expenditures for refinery turnarounds costs — (64,616 ) — — (64,616 ) Expenditures for other assets — (32,692 ) — — (32,692 ) Proceeds from sale of assets 102,428 — — — 102,428 Net cash used in investing activities (25,225 ) (288,049 ) — — (313,274 ) Cash flows from financing activities: Proceeds from revolver borrowings 1,450,000 — — — 1,450,000 Proceeds from intercompany notes payable 31,835 — — — 31,835 Proceeds from member's capital contributions — 1,757 — — 1,757 Proceeds from catalyst lease — 14,337 — — 14,337 Distributions to members (215,846 ) — — — (215,846 ) Repayments of revolver borrowings (1,435,000 ) — — — (1,435,000 ) Payment of contingent consideration related to acquisition of Toledo Refinery — (21,357 ) — — (21,357 ) Deferred financing costs and other (1,044 ) — — — (1,044 ) Net cash used in financing activities (170,055 ) (5,263 ) — — (175,318 ) Net increase (decrease) in cash and cash equivalents (165,747 ) (11,574 ) — — (177,321 ) Cash and equivalents, beginning of period 241,926 12,365 — — 254,291 Cash and equivalents, end of period $ 76,179 $ 791 $ — $ — $ 76,970

DESCRIPTION OF THE BUSINESS A48

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION (Details) - USD ($)	Sep. 01, 2016	Aug. 31, 2016	May 14, 2015	Dec. 11, 2014	Sep. 30, 2014	May 14, 2014	Sep. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Nov. 01, 2015	May 05, 2015
Business Acquisition, Contingent Consideration [Line Items]
Percentage of ownership in PBF LLC													100.00%
Payments to acquire businesses										$ 971,932,000	$ 0		$ 565,304,000	$ 0	$ 0
Less income attributable to noncontrolling interests							$ 45,000		$ 0	438,000	0		274,000	0	0
Income tax expense							$ 2,291,000		$ 0	$ 29,287,000	$ 0		$ 648,000	$ 0	$ 0
PBF Logistics LP [Member] | PBF LLC [Member] | Delaware City West Heavy Crude Unloading Rack [Member]
Business Acquisition, Contingent Consideration [Line Items]
Total purchase price					$ 150,000,000							$ 150,000,000
Payments to acquire businesses					135,000,000							135,000,000
Business acquisition, equity interest issued, value					$ 15,000,000							$ 15,000,000
Business acquisition, equity interest issued or issuable, number of shares					589,536
PBF Logistics LP [Member] | PBF LLC [Member] | Toledo Storage Facility [Member]
Business Acquisition, Contingent Consideration [Line Items]
Total purchase price				$ 150,000,000
Payments to acquire businesses				135,000,000
Business acquisition, equity interest issued, value				$ 15,000,000
Business acquisition, equity interest issued or issuable, number of shares				620,935
IPO [Member] | Common Units [Member]
Business Acquisition, Contingent Consideration [Line Items]
Partners' capital account, units, sold in public offering						15,812,500
PBF Energy [Member] | Class A Common Stock [Member]
Business Acquisition, Contingent Consideration [Line Items]
Percentage of ownership in PBF LLC							95.20%			95.20%			95.10%	89.90%
PBF Energy Inc. [Member] | Class A Common Stock [Member]
Business Acquisition, Contingent Consideration [Line Items]
Percentage of ownership in PBF LLC													95.10%
PBF Logistics LP [Member] | Partnership [Member]
Business Acquisition, Contingent Consideration [Line Items]
Noncontrolling Interest, ownership Percentage by Parent	50.00%
Total purchase price	$ 175,000,000	$ 175,000,000
Payments to acquire businesses	$ 20,000,000
PBF Logistics LP [Member] | Delaware City Products Pipeline and Truck Rack [Member] | Partnership [Member]
Business Acquisition, Contingent Consideration [Line Items]
Total purchase price			$ 143,000,000
Payments to acquire businesses			112,500,000
Business acquisition, equity interest issued, value			$ 30,500,000														$ 30,500,000
Business acquisition, equity interest issued or issuable, number of shares			1,288,420
PBF Logistics LP [Member] | IPO [Member] | Common Units [Member]
Business Acquisition, Contingent Consideration [Line Items]
Partners' capital account, units, sold in public offering						15,812,500
MOEM Pipeline [Member] | Chalmette Refining [Member]
Business Acquisition, Contingent Consideration [Line Items]
Noncontrolling Interest, ownership Percentage by Parent							100.00%			100.00%						100.00%
T&M Terminal Company [Member] | Chalmette Refining [Member]
Business Acquisition, Contingent Consideration [Line Items]
Noncontrolling Interest, ownership Percentage by Parent							80.00%			80.00%			80.00%
Collins Pipeline Company [Member] | Chalmette Refining [Member]
Business Acquisition, Contingent Consideration [Line Items]
Noncontrolling Interest, ownership Percentage by Parent							80.00%			80.00%			80.00%			80.00%
Torrance Valley Pipeline Company [Member]
Business Acquisition, Contingent Consideration [Line Items]
Noncontrolling Interest, ownership Percentage by Parent	50.00%						50.00%			50.00%
Collins Pipeline Company And T&M Terminal Company [Member]
Business Acquisition, Contingent Consideration [Line Items]
Less income attributable to noncontrolling interests							$ 45,000
Income tax expense							$ 348,000			$ 1,512,000
Collins Pipeline Company And T&M Terminal Company [Member] | Chalmette Refining [Member]
Business Acquisition, Contingent Consideration [Line Items]
Noncontrolling Interest, ownership Percentage by Parent							80.00%			80.00%
Restatement Adjustment [Member]
Business Acquisition, Contingent Consideration [Line Items]
Income tax expense								$ 30,481,000
Deferred Tax Liabilities, Net								$ 30,481,000

SUMMARY OF SIGNIFICANT ACCOUN49

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Concentration of Credit Risk) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Concentration Risk [Line Items]
Allowance for Doubtful Accounts Receivable	$ 0	$ 0
Customer Concentration Risk [Member] | Revenues [Member]
Concentration Risk [Line Items]
Concentration risk percentage	0.00%	0.00%
Customer Concentration Risk [Member] | Accounts Receivables [Member]
Concentration Risk [Line Items]
Concentration risk percentage		0.00%
Customer Concentration Risk [Member] | ExxonMobil Oil Corporation [Member] | Accounts Receivables [Member]
Concentration Risk [Line Items]
Concentration risk percentage	18.00%
Customer Concentration Risk [Member] | MSCG [Member] | Revenues [Member]
Concentration Risk [Line Items]
Concentration risk percentage			29.00%
Customer Concentration Risk [Member] | Sunoco, Inc. [Member] | Revenues [Member]
Concentration Risk [Line Items]
Concentration risk percentage			10.00%

SUMMARY OF SIGNIFICANT ACCOUN50

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Property, Plant, and Equipment) (Details)	12 Months Ended
	Dec. 31, 2015
Process Units and Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Process Units and Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Pipeline and Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Pipeline and Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Buildings [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Computers, Furniture and Fixtures [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	3 years
Computers, Furniture and Fixtures [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	7 years
Leasehold Improvements [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	20 years
Railcars [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	50 years

SUMMARY OF SIGNIFICANT ACCOUN51

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Deferred Charges and Other Assets, Net) (Details)	12 Months Ended
	Dec. 31, 2015
Minimum [Member]
Finite-Lived Intangible Assets [Line Items]
Refinery turnaround amortization period	3 years
Intangible assets estimated useful lives	1 year
Maximum [Member]
Finite-Lived Intangible Assets [Line Items]
Refinery turnaround amortization period	5 years
Intangible assets estimated useful lives	10 years
Revolving Credit Facility And Senior Secured Notes [Member] | Minimum [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization over life of loan	1 year
Revolving Credit Facility And Senior Secured Notes [Member] | Maximum [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization over life of loan	8 years

SUMMARY OF SIGNIFICANT ACCOUN52

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Recently Issued Accounting Pronouncements (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Deferred financing costs, net	$ 32,217	$ 30,128
New Accounting Pronouncement, Early Adoption, Effect [Member] | Other Assets [Member]
Deferred financing costs, net	$ (32,217)	$ (30,128)

ACQUISITIONS (Purchase Price) (

ACQUISITIONS (Purchase Price) (Details) - USD ($) $ in Thousands	Jul. 01, 2016	Nov. 01, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Business Acquisition [Line Items]
Net cash			$ 971,932	$ 0	$ 565,304	$ 0	$ 0
Cash acquired		$ 19,042
Preliminary estimate of payable to Seller for working capital adjustments		19,263
Torrance Refinery [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred, Initial Estimate	$ 537,500
Net cash	971,932
Preliminary estimate of payable to Seller for working capital adjustments	450,582
Business Combination, Post Close Adjustment To Purchase Price	$ (16,150)
Chalmette Refining L.L.C. [Member]
Business Acquisition [Line Items]
Net cash		587,005
Cash acquired		19,042
Total consideration		567,963
Preliminary estimate of payable to Seller for working capital adjustments		$ 245,963

ACQUISITIONS (Assets and Liabil

ACQUISITIONS (Assets and Liabilities Acquired) (Details) - USD ($) $ in Thousands	Jul. 01, 2016	Nov. 01, 2015
Torrance Refinery [Member]
Business Acquisition [Line Items]
Inventories	$ 404,542
Prepaid expenses and other current assets	1,186
Property, plant and equipment	701,617
Accounts payable	(2,688)
Accrued expenses	(62,311)
Estimated fair value of net assets acquired	971,932
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets	68,053
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other	$ (138,467)
Chalmette Refining L.L.C. [Member]
Business Acquisition [Line Items]
Accounts receivable		$ 1,126
Inventories		271,434
Prepaid expenses and other current assets		913
Property, plant and equipment		356,961
Deferred charges and other assets		8,312
Deferred charges and other assets		8,312
Accounts payable		(4,870)
Accrued expenses		(28,371)
Deferred tax liability		(25,721)
Noncontrolling interest		(11,821)
Estimated fair value of net assets acquired		$ 567,963

ACQUISITIONS (Pro Forma Informa

ACQUISITIONS (Pro Forma Information) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014
Torrance Refinery [Member]
Business Acquisition [Line Items]
Revenue since acquisition	$ 928,225
Net income since acquisition	$ 51,457
Revenues		$ 12,243,582	$ 12,195,070
Net income attributable to PBF Holdings LLC		$ (60,908)	115,236
Chalmette Refining L.L.C. [Member]
Business Acquisition [Line Items]
Revenues			13,151,698	$ 16,811,922	$ 26,685,661
Net income attributable to PBF Holdings LLC			$ 682,671	$ 397,108	$ 47,030

ACQUISITIONS (Additional Inform

ACQUISITIONS (Additional Information) (Details) - USD ($) $ in Thousands	Jul. 01, 2016	Nov. 01, 2015	Dec. 31, 2015	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Business Acquisition [Line Items]
Preliminary estimate of payable to Seller for working capital adjustments		$ 19,263
Net income				$ 65,072	$ 48,179	$ 148,148	$ 411,803	$ 187,294	$ 21,117	$ 238,876
Torrance Refinery [Member]
Business Acquisition [Line Items]
Purchase price after adjustments	$ 521,350
Preliminary estimate of payable to Seller for working capital adjustments	450,582
Deferred tax liability	$ 62,311
Chalmette Refining L.L.C. [Member]
Business Acquisition [Line Items]
Deferred tax liability		25,721
Purchase price after adjustments		322,000
Preliminary estimate of payable to Seller for working capital adjustments		245,963
Deferred tax liability		$ 28,371
Revenues			$ 643,267
Net income			53,539
Business acquisition, transaction costs			$ 5,833					$ 5,833
Business Combination, Acquisition Related Costs				$ 3,912	$ 1,555	$ 13,622	$ 1,704
PBF Energy Inc. [Member] | Chalmette Refining L.L.C. [Member]
Business Acquisition [Line Items]
Noncontrolling Interest, ownership Percentage by Parent		100.00%
Chalmette Refining [Member] | T&M Terminal Company [Member]
Business Acquisition [Line Items]
Noncontrolling Interest, ownership Percentage by Parent			80.00%	80.00%		80.00%		80.00%
Chalmette Refining [Member] | MOEM Pipeline [Member]
Business Acquisition [Line Items]
Noncontrolling Interest, ownership Percentage by Parent		100.00%		100.00%		100.00%
Chalmette Refining [Member] | Collins Pipeline Company [Member]
Business Acquisition [Line Items]
Noncontrolling Interest, ownership Percentage by Parent		80.00%	80.00%	80.00%		80.00%		80.00%
Noncontrolling Interest [Member] | Chalmette Refining L.L.C. [Member]
Business Acquisition [Line Items]
Deferred tax liability		$ 5,144

INVENTORIES (Details)

INVENTORIES (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Jun. 30, 2016	Jun. 30, 2015
Inventory [Line Items]
Crude oil and feedstocks	$ 1,218,399		$ 1,218,399		$ 1,137,605	$ 979,878
Refined products and blendstocks	1,335,853		1,335,853		1,098,746	775,767
Warehouse stock and other	87,846		87,846		55,257	36,726
Inventory, Gross	2,642,098		2,642,098		2,291,608	1,792,371
Lower of cost or market adjustment	(796,503)	$ 771,257	(796,503)	$ 771,257	(1,117,336)	(690,110)		$ 900,493	$ 562,944
Total inventories	1,845,595		1,845,595		1,174,272	1,102,261
Operating Income (Loss)	(101,182)	(65,073)	(280,437)	(468,736)	(265,952)	(115,149)	$ (328,399)
Titled Inventory [Member]
Inventory [Line Items]
Crude oil and feedstocks	1,218,399		1,218,399		1,137,605	918,756
Refined products and blendstocks	976,556		976,556		687,389	520,308
Warehouse stock and other	87,846		87,846		55,257	36,726
Inventory, Gross	2,282,801		2,282,801		1,880,251	1,475,790
Lower of cost or market adjustment	(677,448)		(677,448)		(966,564)	(609,774)
Total inventories	1,605,353		1,605,353		913,687	866,016
Inventory Supply and Offtake Arrangements [Member]
Inventory [Line Items]
Crude oil and feedstocks	0		0		0	61,122
Refined products and blendstocks	359,297		359,297		411,357	255,459
Warehouse stock and other	0		0		0	0
Inventory, Gross	359,297		359,297		411,357	316,581
Lower of cost or market adjustment	(119,055)		(119,055)		(150,772)	(80,336)
Total inventories	240,242		240,242		260,585	236,245
Scenario, Adjustment [Member]
Inventory [Line Items]
Operating Income (Loss)	$ 103,990	$ 208,313	$ 320,833	$ 81,147	$ 427,226	$ 690,110

PROPERTY, PLANT AND EQUIPMENT58

PROPERTY, PLANT AND EQUIPMENT, NET (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2016
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 2,558,263	$ 2,068,973
Less - Accumulated depreciation	(347,173)	(262,913)
Property, plant and equipment, net	2,211,090	1,806,060		$ 2,659,383
Depreciation	88,474	113,533	$ 79,413
Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	91,256	59,575
Process units, pipelines and equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,209,712	1,843,157
Building and leasehold improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	34,265	28,397
Computers furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	72,642	68,431
Construction in progress [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	150,388	69,413
Capitalized interest	$ 3,529	7,487
Hydrocracker Project [Member]
Property, Plant and Equipment [Line Items]
Impaired Assets to be Disposed of by Method Other than Sale, Carrying Value of Asset		$ 28,508

DEFERRED CHARGES AND OTHER AS59

DEFERRED CHARGES AND OTHER ASSETS, NET (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2016
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Deferred turnaround costs, net	$ 177,236	$ 204,987		$ 253,823
Catalyst	77,725	77,322		106,311
Linefill	13,504	10,230		19,485
Restricted cash	1,500	1,521		1,500
Intangible assets, net	219	357		598
Other	20,529	5,972		29,743
Deferred charges and other assets	290,713	300,389		449,271
Amortization expense	102,636	65,452	$ 32,066
Intangible Assets, Net [Abstract]
Gross amount	3,597	3,599
Accumulated amortization	(3,378)	(3,242)
Net amount	219	357
Deferred financing costs, net	32,217	$ 30,128
Environmental Credits	$ 0			$ 37,811

ACCRUED EXPENSES (Details)

ACCRUED EXPENSES (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015	Dec. 31, 2014
Accrued Expenses:
Inventory-related accruals	$ 845,772	$ 548,800	$ 588,297
Inventory supply and intermediation arrangements	245,983	252,380	253,549
Accrued transportation costs	96,479	91,546	59,959
Accrued salaries and benefits	14,434	61,011	55,993
Excise and sales tax payable	70,871	34,129	40,444
Accrued construction in progress	14,203	7,400	31,452
Customer deposits	12,871	20,395	24,659
Accrued interest	31,838	22,313	22,946
Accrued utilities	39,390	25,192	22,337
Accrued Environmental Loss Contingencies, Current	9,525	0
Renewable energy credit obligations	106,366	19,472	286
Other	33,756	34,797	30,048
Accrued expenses	$ 1,521,488	$ 1,117,435	$ 1,129,970

DELAWARE ECONOMIC DEVELOPMENT61

DELAWARE ECONOMIC DEVELOPMENT AUTHORITY LOAN (Details) - USD ($)	1 Months Ended			12 Months Ended
	Aug. 31, 2014	Oct. 31, 2013	Feb. 28, 2013	Dec. 31, 2015	Dec. 31, 2014	Sep. 30, 2016	Jun. 30, 2010
Debt Instrument [Line Items]
Delaware Economic Development Authority loan				$ 4,000,000	$ 8,000,000	$ 4,000,000	$ 20,000,000
Annual conversion of loan to grant				$ 4,000,000
Term of loan conversion				5 years
Minimum man hours of labor utilized				600000 hours
Minimum qualified capital expenditures				$ 125,000,000
Economic Development Authority Loan, Loan Conversion, Decrease (Increase) to Property, Plant and Equipment				$ 4,000,000	$ 4,000,000
Zero Percent Interest Note [Member]
Debt Instrument [Line Items]
Debt fixed interest rate				0.00%
Tranche 1 [Member]
Debt Instrument [Line Items]
Amount of loan converted during period			$ 4,000,000
Tranche 2 [Member]
Debt Instrument [Line Items]
Amount of loan converted during period		$ 4,000,000
Debt Instrument, Debt Forgiveness, Period Three [Member]
Debt Instrument [Line Items]
Amount of loan converted during period	$ 4,000,000

CREDIT FACILITY AND LONG-TERM62

CREDIT FACILITY AND LONG-TERM DEBT (Details)

Nov. 24, 2015USD ($)

Mar. 26, 2014

Feb. 09, 2012USD ($)

Oct. 31, 2012USD ($)

Sep. 30, 2016USD ($)

Dec. 31, 2015USD ($)

Nov. 30, 2015USD ($)

Jun. 30, 2015

Apr. 29, 2015USD ($)

Dec. 31, 2014USD ($)

Aug. 15, 2014USD ($)

Jun. 30, 2014USD ($)

Mar. 25, 2014USD ($)

Debt Instrument [Line Items]

Line of Credit Facility, Available Increase In Borrowing Capacity

$ 2,750,000,000

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

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 1,610,000,000

2,635,000,000

$ 2,600,000,000

$ 2,500,000,000

Maximum borrowing capacity, as a percentage of aggregate borrowing capacity

10.00%

Alternative maximum borrowing capacity

$ 100,000,000

Effective consolidated fixed charge coverage ratio during period

1.1

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

Debt Instrument [Line Items]

Basis spread on variable rate

0.50%

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

Debt Instrument [Line Items]

Basis spread on variable rate

1.25%

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

Debt Instrument [Line Items]

Basis spread on variable rate

1.50%

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

Debt Instrument [Line Items]

Basis spread on variable rate

2.25%

Line of Credit [Member] | Letter of Credit [Member]

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 1,500,000,000

$ 1,000,000,000

Participation Fee, Percent

1.25%

2.00%

Fronting Fee, Percent

0.25%

Line of Credit [Member] | Standby Letters of Credit [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

351,511,000

$ 400,262,000

Senior Secured Notes [Member]

Debt Instrument [Line Items]

Debt issued

$ 675,500,000

Debt fixed interest rate

8.25%

Redemption price as a percentage

100.00%

Long-term Line of Credit

$ 550,000,000

$ 0

$ 0

2023 Senior Secured Notes [Member]

Debt Instrument [Line Items]

Debt issued

$ 500,000,000

Debt fixed interest rate

7.00%

Proceeds from Debt, Net of Issuance Costs

$ 490,000,000

Financing Arrangements [Member] | Paulsboro Catalyst Lease [Member]

Debt Instrument [Line Items]

Debt fixed interest rate

1.95%

Facility fee

$ 180,000

Financing Arrangements [Member] | Toledo Catalyst Lease [Member]

Debt Instrument [Line Items]

Debt fixed interest rate

1.99%

Facility fee

$ 326,000

Financing Arrangements [Member] | Delaware City Catalyst Lease [Member]

Debt Instrument [Line Items]

Debt fixed interest rate

1.96%

Facility fee

$ 322,000

Financing Arrangements [Member] | Chalmette Catalyst Lease [Member]

Debt Instrument [Line Items]

Debt fixed interest rate

3.85%

Facility fee

$ 185,000

PBF Rail Logistics Company LLC [Member] | Line of Credit [Member]

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 150,000,000

$ 250,000,000

Debt Instrument, Redemption, Period One [Member] | PBF Rail Logistics Company LLC [Member] | Line of Credit [Member] | Revolving Loan [Member]

Debt Instrument [Line Items]

Debt Instrument, Advances, Appraised Value, As a Percentage

70.00%

Debt Instrument, Advances, Appraised Value, Adjusted Upon First Anniversary, Percent

65.00%

Debt Instrument, Redemption, Period Two [Member] | PBF Rail Logistics Company LLC [Member] | Line of Credit [Member] | Revolving Loan [Member]

Debt Instrument [Line Items]

Debt Instrument, Advances, Appraised Value, As a Percentage

65.00%

CREDIT FACILITY AND LONG-TERM63

CREDIT FACILITY AND LONG-TERM DEBT (Summary of Long-Term Debt) (Details) - USD ($)	Nov. 24, 2015	Mar. 26, 2014	Sep. 30, 2016	Dec. 31, 2015	Nov. 30, 2015	Apr. 29, 2015	Dec. 31, 2014	Aug. 15, 2014	Mar. 25, 2014	Oct. 31, 2012	Feb. 09, 2012
Debt Instrument [Line Items]
Line of Credit Facility, Available Increase In Borrowing Capacity				$ 2,750,000,000
Long-term debt			$ 1,794,367,000	1,236,720,000			$ 712,221,000
Deferred financing costs, net				32,217,000			30,128,000
Less—Current maturities			0	0			0
Total long-term debt				1,236,720,000			712,221,000
2023 Senior Secured Notes [Member]
Debt Instrument [Line Items]
Long-term debt							0
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Long-term debt				0
Line of Credit [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity				2,635,000,000	$ 2,600,000,000			$ 2,500,000,000		$ 1,610,000,000
Line of Credit [Member] | Rail Facility [Member]
Debt Instrument [Line Items]
Long-term Line of Credit				67,491,000			37,270,000
Catalyst Lease Obligation [Member]
Debt Instrument [Line Items]
Long-term debt				31,802,000
Capital Lease Obligations [Member]
Debt Instrument [Line Items]
Long-term debt							36,559,000
Senior Secured Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount											$ 675,500,000
Long-term debt				669,644,000			668,520,000
Long-term Line of Credit			550,000,000	0			$ 0
Debt Instrument, Interest Rate, Stated Percentage											8.25%
2023 Senior Secured Notes [Member]
Debt Instrument [Line Items]
Proceeds from Debt, Net of Issuance Costs	$ 490,000,000
Debt Instrument, Face Amount	$ 500,000,000
Long-term debt			$ 500,000,000	500,000,000
Debt Instrument, Interest Rate, Stated Percentage	7.00%
PBF Rail Logistics Company LLC [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity						$ 150,000,000			$ 250,000,000
PBF Rail Logistics Company LLC [Member] | Debt Instrument, Redemption, Period Two [Member] | Line of Credit [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Advances, Appraised Value, As a Percentage		65.00%
PBF Rail Logistics Company LLC [Member] | Debt Instrument, Redemption, Period One [Member] | Line of Credit [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Advances, Appraised Value, Adjusted Upon First Anniversary, Percent		65.00%
Debt Instrument, Advances, Appraised Value, As a Percentage		70.00%
Paulsboro Catalyst Lease [Member] | Capital Lease Obligations [Member]
Debt Instrument [Line Items]
Debt Instrument, Fee Amount				$ 180,000
Debt Instrument, Interest Rate, Stated Percentage				1.95%
Delaware City Catalyst Lease [Member] | Capital Lease Obligations [Member]
Debt Instrument [Line Items]
Debt Instrument, Fee Amount				$ 322,000
Debt Instrument, Interest Rate, Stated Percentage				1.96%
Toledo Catalyst Lease [Member] | Capital Lease Obligations [Member]
Debt Instrument [Line Items]
Debt Instrument, Fee Amount				$ 326,000
Debt Instrument, Interest Rate, Stated Percentage				1.99%
Chalmette Catalyst Lease [Member] | Capital Lease Obligations [Member]
Debt Instrument [Line Items]
Debt Instrument, Fee Amount				$ 185,000
Debt Instrument, Interest Rate, Stated Percentage				3.85%

CREDIT FACILITY AND LONG-TERM64

CREDIT FACILITY AND LONG-TERM DEBT (Debt Maturities) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Long-term Debt, Fiscal Year Maturity [Abstract]
2,016		$ 17,252
2,017		77,164
2,018		4,877
2,019		0
2,020		669,644
Thereafter		500,000
Long-term Debt	$ 1,820,872	$ 1,268,937

AFFILIATE NOTE PAYABLE (Details

AFFILIATE NOTE PAYABLE (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Affiliate notes payable	$ 470,165	$ 470,047	$ 122,264
Notes Payable [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate	2.50%
Debt instrument, term	5 years

INTERCOMPANY NOTE PAYABLE (Deta

INTERCOMPANY NOTE PAYABLE (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Intercompany notes payable	$ 470,165	$ 470,047	$ 122,264
Notes Payable [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	2.50%
Debt instrument, term	5 years
PBF Holding [Member] | Notes Payable [Member]
Debt Instrument [Line Items]
Debt fixed interest rate		2.50%
Debt instrument, term		5 years

OTHER LONG-TERM LIABILITIES (De

OTHER LONG-TERM LIABILITIES (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015	Dec. 31, 2014
Other Long-Term Liabilities [Abstract]
Other long-term liabilities	$ 213,635	$ 69,824	$ 62,752
PBF Holding [Member]
Other Long-Term Liabilities [Abstract]
Defined benefit pension plan liabilities		42,509	40,142
Post retiree medical plan		17,729	14,740
Environmental liabilities		8,189	7,870
Other		1,397	0
Other long-term liabilities		$ 69,824	$ 62,752

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details)

Sep. 01, 2016USD ($)

Aug. 31, 2016USD ($)bbl / d$ / bbl

Apr. 29, 2016terminal$ / bbl

May 15, 2015USD ($)renewal$ / bbl

May 14, 2015USD ($)bbl / dshares

Jan. 01, 2015renewal$ / bbl

Dec. 11, 2014USD ($)renewalshares

Oct. 01, 2014bbl / d$ / bbl

Sep. 30, 2014USD ($)renewalshares

May 14, 2014USD ($)bbl / d$ / bblshares

Sep. 30, 2016USD ($)bbl / d

Sep. 30, 2015USD ($)

May 14, 2015USD ($)

Sep. 30, 2016USD ($)

Sep. 30, 2015USD ($)

Sep. 30, 2014USD ($)

Dec. 31, 2015USD ($)

Dec. 31, 2014USD ($)

Dec. 31, 2013USD ($)

Dec. 31, 2012USD ($)

Jul. 01, 2016$ / bbl

Jan. 01, 2016$ / bbl

Jul. 01, 2015$ / bbl

May 05, 2015USD ($)

Related Party Transaction [Line Items]

Payments to acquire businesses

$ 971,932,000

$ 0

$ 565,304,000

$ 0

$ 0

Number of Contract Renewals | renewal

2

Term of Renewal

5 years

Blackstone and First Reserve [Member] | Series B Units [Member]

Related Party Transaction [Line Items]

Distributions to Series B Unitholders

19,592,000

130,523,000

6,427

$ 0

Fuel Strategies International, Inc, [Member]

Related Party Transaction [Line Items]

Charges incurred during period

588,000

646,000

Executive Chairman of the Board of Directors [Member]

Related Party Transaction [Line Items]

Charges incurred during period

$ 957,000

1,214,000

$ 1,274,000

Fourth Amended and Restated Omnibus Agreement [Member] | PBF LLC [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Annual Fee

$ 4,000,000

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

Related Party Transaction [Line Items]

Related Party, Annual Fee

$ 4,400,000

$ 797,000

$ 797,000

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

Related Party Transaction [Line Items]

Related Party, Annual Fee

$ 490,000

Related Party Transaction, Notice Of Withdrawal Period

30 days

Omnibus Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party, Transaction Period

5 years

Related Party Transaction, Annual Fee

$ 2,300,000

$ 2,300,000

Related Party Transaction, Expense Reimbursement, Salaries and Benefit Costs Reimbursement, Minimum Time Commitment to Company, Percent

50.00%

Related Party Transaction, Maximum Reimbursement per Event, Net of Insurance Recoveries

$ 20,000,000

Omnibus Agreement [Member] | PBF LLC [Member]

Related Party Transaction [Line Items]

Related Party Transactions, First Offer Term On Certain Logistical Assets Retained In Company Partnership

10 years

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

Related Party Transaction [Line Items]

Related Party Transaction, Annual Fee

2,700,000

2,525,000

Third Amended and Restated Omnibus Agreement [Member] | PBF LLC [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Annual Fee

$ 2,350,000

Second Amended and Restated Omnibus Agreement [Member] | PBF LLC [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Annual Fee

$ 2,225,000

Third Amended and Restated Services Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

Related Party, Annual Fee

$ 4,486,000

Fourth Amended and Restated O&M Agreement [Member] | PBF LLC [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Annual Fee

6,386,000

Partnership [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Noncontrolling Interest, ownership Percentage by Parent

50.00%

Total purchase price

$ 175,000,000

$ 175,000,000

Payments to acquire businesses

20,000,000

Proceeds from Sale and Maturity of Marketable Securities

76,200,000

PBF Logistics LP [Member] | Contribution Agreement [Member] | PBF LLC [Member]

Related Party Transaction [Line Items]

Rights To Distribution Made To Limited Partner, Reimbursement Of Capital Expenditures

$ 30,000,000

Rights To Distribution Made To Limited Partner

298,664,000

Partners' Capital Account, Redemptions

$ 1

PBF Logistics LP [Member] | Contribution Agreement [Member] | PBF LLC [Member] | Common Units [Member]

Related Party Transaction [Line Items]

Partners' Capital Account, Units, Issued In Non-Cash Exchange | shares

74,053

PBF Logistics LP [Member] | Contribution Agreement [Member] | PBF LLC [Member] | Subordinated Units [Member]

Related Party Transaction [Line Items]

Partners' Capital Account, Units, Issued In Non-Cash Exchange | shares

15,886,553

PBF Logistics LP [Member] | Contribution Agreement [Member] | PBF LLC [Member]

Related Party Transaction [Line Items]

Rights To Distribution Made To Limited Partner, Reimbursement Of Capital Expenditures

$ 30,000,000

Rights To Distribution Made To Limited Partner

$ 298,664,000

Limited Partner, Public [Member] | Partnership [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Payments to acquire businesses

$ 78,800,000

Limited Partner [Member] | PBF Logistics LP [Member] | PBF LLC [Member]

Related Party Transaction [Line Items]

Limited Partners' Capital Account, Ownership Percentage

50.20%

Delaware City West Heavy Crude Unloading Rack [Member] | PBF Logistics LP [Member] | PBF LLC [Member]

Related Party Transaction [Line Items]

Total purchase price

150,000,000

150,000,000

Payments to acquire businesses

135,000,000

135,000,000

Business acquisition, equity interest issued, value

$ 15,000,000

$ 15,000,000

Business acquisition, equity interest issued or issuable, number of shares | shares

589,536

Toledo Storage Facility [Member] | PBF Logistics LP [Member] | PBF LLC [Member]

Related Party Transaction [Line Items]

Total purchase price

150,000,000

Payments to acquire businesses

135,000,000

Business acquisition, equity interest issued, value

$ 15,000,000

Business acquisition, equity interest issued or issuable, number of shares | shares

620,935

East Coast Terminals [Member] | East Coast Terminals commercial agreements [Member]

Related Party Transaction [Line Items]

Number Of Refined Product Terminals Acquired | terminal

4

East Coast Terminals [Member] | East Coast Terminals commercial agreements [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

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

448,000

Related Party Transaction, Notice Of Withdrawal Period

30 days

Delaware City Products Pipeline [Member] | Delaware City Pipeline Services Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

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

50,000

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

0.5266

0.5396

0.5507

Delaware City Pipeline Services Agreement [Member]

Related Party Transaction [Line Items]

Term of Agreement

10 years

Term of Renewal

5 years

Toledo Tank Farm Storage and Terminaling Agreement [Member]

Related Party Transaction [Line Items]

Term of Agreement

10 years

Number of Contract Renewals | renewal

2

Term of Renewal

5 years

West Ladder Rack Terminaling Agreement [Member]

Related Party Transaction [Line Items]

Term of Agreement

7 years

Number of Contract Renewals | renewal

2

Term of Renewal

5 years

Delaware City Products Pipeline and Truck Rack [Member] | Partnership [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Total purchase price

$ 143,000,000

Payments to acquire businesses

112,500,000

Business acquisition, equity interest issued, value

$ 30,500,000

$ 30,500,000

$ 30,500,000

Business acquisition, equity interest issued or issuable, number of shares | shares

1,288,420

Toledo Storage Facility [Member]

Related Party Transaction [Line Items]

Term of Agreement

10 years

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

Related Party Transaction [Line Items]

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

4,400

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

2.52

Oil And Gas Plant, Terminaling Services Fee, Fee For Volume Above Minimum | $ / bbl

2.52

Oil And Gas Plant, Storage Services Fee | $ / bbl

0.50

Toledo Truck Unloading Terminal [Member]

Related Party Transaction [Line Items]

Term of Agreement

7 years

Toledo Truck Unloading Terminal [Member] | Toledo Terminaling Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

1.016

1.007

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

Related Party Transaction [Line Items]

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

4,000

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

1

Toledo Truck Unloading Terminal [Member] | Agreement Period Three [Member] | Services Agreement [Member] | Toledo Terminaling Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

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

5,500

Delaware City Rail Unloading Terminal [Member]

Related Party Transaction [Line Items]

Term of Agreement

7 years

Delaware City Rail Unloading Terminal [Member] | DCR Terminaling Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

2.032

2.014

Oil And Gas Plant, Terminaling Services Fee, Fee For Volume Above Minimum | $ / bbl

0.508

0.503

Number of Contract Renewals | renewal

2

Term of Renewal

5 years

Delaware City Rail Unloading Terminal [Member] | Services Agreement [Member] | DCR Terminaling Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

2

Oil And Gas Plant, Terminaling Services Fee, Fee For Volume Above Minimum | $ / bbl

0.50

Delaware City Rail Unloading Terminal [Member] | Agreement Period One [Member] | DCR Terminaling Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

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

75,000

Delaware City Rail Unloading Terminal [Member] | Agreement Period One [Member] | Services Agreement [Member] | DCR Terminaling Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

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

85,000

Delaware City West Heavy Crude Unloading Rack [Member]

Related Party Transaction [Line Items]

Term of Agreement

7 years

Delaware City West Heavy Crude Unloading Rack [Member] | West Ladder Rack Terminaling Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

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

40,000

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

2.20

Oil And Gas Plant, Terminaling Services Fee, Fee For Volume Above Minimum | $ / bbl

1.50

Delaware Truck Loading Services Agreement [Member]

Related Party Transaction [Line Items]

Term of Agreement

10 years

Term of Renewal

5 years

Torrance Valley Pipeline - North [Member] | Torrance Valley Pipeline Transportation Services Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

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

50,000

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

0.5625

Torrance Valley Pipeline - South [Member] | Torrance Valley Pipeline Transportation Services Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

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

70,000

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

1.5625

Oil And Gas Plant, Terminaling Services Fee, Fee For Volume Above Minimum | $ / bbl

0.3125

Torrance Valley Pipeline - Midway Tank [Member] | Torrance Valley Pipeline Transportation Services Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Storage Services Fee | $ / bbl

0.85

Torrance Valley Pipeline - Belridge and Emidio Tanks [Member] [Member] | Torrance Valley Pipeline Transportation Services Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Storage Service Fee, Fee For Volume Above Minimum | $ / bbl

0.425

Oil And Gas Plant, Storage Services Fee | $ / bbl

0.85

Torrance Valley Pipeline - Belridge Tanks [Member] | Torrance Valley Pipeline Transportation Services Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

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

715,000

Torrance Valley Pipeline - Emidio Tanks [Member] | Torrance Valley Pipeline Transportation Services Agreement [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

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

600,000

Cost of Sales [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction

$ 43,842,000

$ 37,082,000

118,356,000

104,796,000

Cost of Sales [Member] | Delaware Truck Loading Services Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction

$ 6,155,000

0

Cost of Sales [Member] | Delaware City Pipeline Services Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction

6,328,000

0

Cost of Sales [Member] | DCR Terminaling Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction

63,043,000

36,640,000

Cost of Sales [Member] | Toledo Terminaling Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction

5,578,000

2,131,000

Cost of Sales [Member] | West Ladder Rack Terminaling Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction

32,120,000

9,639,000

Cost of Sales [Member] | Toledo Tank Farm Storage and Terminaling Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction

25,495,000

1,420,000

General and Administrative Expense [Member] | Services Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction

1,280,000

1,122,000

3,523,000

3,412,000

General and Administrative Expense [Member] | Omnibus Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction

$ 1,201,000

$ 1,471,000

$ 3,460,000

$ 3,941,000

5,216,000

2,174,000

Operating Expense [Member] | Services Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction

$ 4,455,000

$ 579,000

Refined Clean Product [Member] | Delaware City Truck Rack [Member] | Delaware City Terminaling Services Agreement [Member] | PBF Holding Company LLC [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 | $ / bbl

0.462

LPGs [Member] | Delaware City Truck Rack [Member] | Delaware City Terminaling Services Agreement [Member] | PBF Holding Company LLC [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 | $ / bbl

2.52

Torrance Valley Pipeline Company [Member]

Related Party Transaction [Line Items]

Noncontrolling Interest, ownership Percentage by Parent

50.00%

50.00%

50.00%

Minimum [Member]

Related Party Transaction [Line Items]

Term of Agreement

7 years

Minimum [Member] | East Coast Terminals [Member] | East Coast Terminals commercial agreements [Member]

Related Party Transaction [Line Items]

Term of Agreement

3 months

Term of Renewal

3 months

Minimum [Member] | East Coast Terminals [Member] | East Coast Terminals commercial agreements [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Storage Service Fee, Fee For Volume Above Minimum | $ / bbl

0.30

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

0.10

Oil And Gas Plant, Storage Services Fee | $ / bbl

0.45

Maximum [Member]

Related Party Transaction [Line Items]

Term of Agreement

10 years

Maximum [Member] | East Coast Terminals [Member] | East Coast Terminals commercial agreements [Member]

Related Party Transaction [Line Items]

Term of Agreement

1 year

Term of Renewal

1 year

Maximum [Member] | East Coast Terminals [Member] | East Coast Terminals commercial agreements [Member] | PBF Holding Company LLC [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Storage Service Fee, Fee For Volume Above Minimum | $ / bbl

0.351

Oil And Gas Plant, Terminaling Services Fee, Base Commitment | $ / bbl

1.25

Oil And Gas Plant, Storage Services Fee | $ / bbl

0.55

COMMITMENTS AND CONTINGENCIES69

COMMITMENTS AND CONTINGENCIES (Details)	Jul. 01, 2016	Mar. 03, 2014ppm	Mar. 01, 2011	Sep. 30, 2016USD ($)	Sep. 30, 2016USD ($)ppm	Dec. 31, 2015USD ($)ppmstate	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2010ppm
Commitments and Contingencies Disclosure [Abstract]
Rent expense						$ 126,060,000	$ 98,473,000	$ 70,581,000
Inventory purchases						36,139,000	40,444,000	$ 38,383,000
Environmental Matters
Restricted cash for environmental liabilities				$ 1,500,000	$ 1,500,000	$ 1,500,000	$ 1,521,000
Percent of tax benefit received from increases in tax basis paid to stockholders					85.00%	85.00%
Percentage of ownership in PBF LLC						100.00%
PBF Energy [Member] | Class A Common Stock [Member]
Environmental Matters
Percentage of ownership in PBF LLC				95.20%	95.20%	95.10%	89.90%
Environmental Issue [Member]
Environmental Matters
Environmental liability				$ 11,198,000	$ 11,198,000	$ 10,367,000	$ 10,476,000
Discount rate used for environmental liability assessment				8.00%	8.00%	8.00%
Undiscounted liability						$ 15,646,000
Expected future payments						$ 5,998,000
Expected payment period					5 years	5 years
Restricted cash for environmental liabilities						$ 0
Maximum amount of sulfur allowed in heating oil (in ppm) | ppm		10			10	80
Public Utilities, Description of Specific Regulatory Liabilities					80
Environmental Issue [Member] | Valero [Member]
Environmental Matters
Maximum pre-disposal environmental obligations of Valero					$ 20,000,000	$ 20,000,000
Environmental Issue [Member] | PBF Energy and Valero [Member]
Environmental Matters
Maximum pre-disposal environmental obligations of Valero					$ 75,000,000
Term of insurance policies					10 years	10 years
Payments to acquire environmental insurance policies						$ 75,000,000
Environmental Issue [Member] | Sunoco, Inc. [Member]
Environmental Matters
Loss Contingency Accrual, Insurance-Related Assessment, Expiration Of Liability Period			20 years
Environmental Issue [Member] | Torrance Refinery [Member]
Environmental Matters
Environmental liability				$ 146,300,000	$ 146,300,000
Expected future payments				31,402,000	31,402,000
Maximum pre-disposal environmental obligations of Valero					$ 100,000,000
Site Contingency, Loss Exposure in Excess of Accrual, Best Estimate				$ 100,000
Term of insurance policies	10 years
Minimum [Member]
Loss Contingencies [Line Items]
Non-cancelable operating lease term						1 year
Maximum [Member]
Loss Contingencies [Line Items]
Non-cancelable operating lease term						20 years
Executive [Member] | Minimum [Member]
Employee Agreements
Potential lump sum payment as a multiple of base salary						1.5
Potential payment upon death or disability as a multiple of base salary						0.50
Executive [Member] | Maximum [Member]
Employee Agreements
Potential lump sum payment as a multiple of base salary						2.99
New York [Member] | Environmental Issue [Member]
Environmental Matters
Maximum amount of sulfur allowed in heating oil (in ppm) | ppm									15
Northeastern states [Member] | Environmental Issue [Member]
Environmental Matters
Additional States Requiring Heating Oils | state						6
PENNSYLVANIA | Environmental Issue [Member]
Environmental Matters
Maximum amount of sulfur allowed in heating oil (in ppm) | ppm									500
Chalmette Refinery [Member] | Environmental Issue [Member]
Environmental Matters
Expected payment period					30 years	30 years
Term of insurance policies					10 years
Payments to acquire environmental insurance policies					$ 100,000,000	$ 100,000,000
Environmental Costs Recognized, Recovery Credited to Expense					$ 3,936,000	$ 3,936,000

COMMITMENTS AND CONTINGENCIES70

COMMITMENTS AND CONTINGENCIES (Future Minimum Rental Payments) (Details) $ in Thousands	Dec. 31, 2015USD ($)
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2,016	$ 138,890
2,017	131,057
2,018	122,286
2,019	95,397
2,020	94,666
Thereafter	237,435
Total future obligation payments due	$ 819,731

EQUITY STRUCTURE (Additional In

EQUITY STRUCTURE (Additional Information) (Details)	12 Months Ended
	Dec. 31, 2015USD ($)vote / sharesshares	Sep. 30, 2016	Nov. 01, 2015
Class of Stock [Line Items]
Shares outstanding	0
Percentage of ownership in PBF LLC	100.00%
PBF Finance Corporation [Member]
Class of Stock [Line Items]
Shares outstanding	100
PBF Energy [Member] | Class B Common Stock [Member]
Class of Stock [Line Items]
Common Stock, Voting Rights, Votes Per Share | vote / shares	1
PBF LLC [Member] | Series B Units [Member]
Class of Stock [Line Items]
Equity unit, stated value per share | $	$ 0
Number of units authorized	1,000,000
Collins Pipeline Company [Member] | Chalmette Refining [Member]
Class of Stock [Line Items]
Noncontrolling Interest, ownership Percentage by Parent	80.00%	80.00%	80.00%
T&M Terminal Company [Member] | Chalmette Refining [Member]
Class of Stock [Line Items]
Noncontrolling Interest, ownership Percentage by Parent	80.00%	80.00%

STOCK-BASED COMPENSATION (Share

STOCK-BASED COMPENSATION (Share-Based Compensation Expense) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
PBF LLC [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value	$ 16,797
PBF LLC [Member] | Series A Units [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Non-compensatory warrants outstanding	32,719	56,719
General and Administrative Expense [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	$ 9,218	$ 6,095	$ 3,753
General and Administrative Expense [Member] | PBF LLC [Member] | Series A Units [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	0	522	779
General and Administrative Expense [Member] | PBF LLC [Member] | Series B Units [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	0	0	530
General and Administrative Expense [Member] | PBF Energy Inc. [Member] | Class A Common Stock [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	7,528	4,343	2,051
Restricted Stock [Member] | General and Administrative Expense [Member] | Parent Company [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	1,690	$ 1,230	$ 393
Employee Stock Option [Member] | PBF Energy Inc. [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value	38,167
Total intrinsic value of stock options exercisable	$ 12,139

STOCK-BASED COMPENSATION (Sha73

STOCK-BASED COMPENSATION (Share-Based Compensation Activity) (Details) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
PBF LLC [Member] | Series A Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Class Of Warrant Or Right, Warrants Exercised In Period	24,000	11,700
Options
Options, beginning balance	801,479	841,079	1,184,726
Exercised	(160,700)	(32,934)	(301,979)
Forfeited		(6,666)	(41,668)
Options, ending balance	640,779	801,479	841,079	1,184,726
Weighted Average Exercise Price
Weighted average exercise price, beginning balance	$ 10.53	$ 10.52	$ 10.44
Exercised	10.28	10	10.11
Forfeited		11.59	11.27
Weighted average exercise price, ending balance	$ 10.59	$ 10.53	$ 10.52	$ 10.44
Weighted average remaining contractual term, outstanding	5 years 5 months 15 days	6 years 4 months 28 days	7 years 4 months 24 days	8 years 2 months 23 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	640,779	753,985	545,247
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price	$ 10.59	$ 10.41	$ 10.24
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Term	5 years 5 months 15 days	6 years 4 months 3 days	7 years 2 months 23 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Number	640,779
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price	$ 10.59
Weighted average remaining contractual term, expected to vest	5 years 5 months 15 days
PBF Energy Inc. [Member]
Options
Options, beginning balance	2,401,875	1,320,000	682,500
Granted	1,899,500	1,135,000	697,500
Exercised	(30,000)	0	0
Forfeited	(15,000)	(53,125)	(60,000)
Options, ending balance	4,256,375	2,401,875	1,320,000	682,500
Weighted Average Exercise Price
Weighted average exercise price, beginning balance	$ 25.97	$ 26.97	$ 26
Granted	30.28	24.78	27.79
Exercised	25.79	0	0
Forfeited	26.38	25.44	25.36
Weighted average exercise price, ending balance	$ 27.89	$ 25.97	$ 26.97	$ 26
Weighted average remaining contractual term, outstanding	8 years 3 months 26 days	8 years 8 months 2 days	9 years 3 months 29 days	9 years 11 months 12 days
Weighted average remaining contractual term, granted	10 years	10 years	10 years
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	1,136,250	485,000	158,125
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price	$ 26.22	$ 26.66	$ 26
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Term	7 years 7 months 11 days	8 years 2 months 16 days	8 years 11 months 12 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Number	4,256,375
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price	$ 27.89
Weighted average remaining contractual term, expected to vest	8 years 2 months 24 days

STOCK-BASED COMPENSATION (Weigh

STOCK-BASED COMPENSATION (Weighted Average Assumptions) (Details) - PBF Energy Inc. [Member] - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life (in years)	6 years 3 months	6 years 3 months	6 years 3 months
Expected volatility	38.40%	52.00%	52.10%
Dividend yield	3.96%	4.82%	4.43%
Risk-free rate of return	1.58%	1.80%	1.53%
Exercise price	$ 30.28	$ 24.78	$ 27.79

STOCK-BASED COMPENSATION (Summa

STOCK-BASED COMPENSATION (Summary of Unit Activity) (Details) - PBF LLC [Member] - Series B Units [Member]	12 Months Ended
	Dec. 31, 2013$ / sharesshares
Non-Vested Units
Units, beginning balance	250,000
Allocated	0
Vested	(250,000)
Forfeited	0
Units, ending balance	0
Weighted Average Grant Date Fair Value
Weighted average grant date fair value, beginning balance | $ / shares	$ 5.11
Vested | $ / shares	5.11
Forfeited | $ / shares	0
Weighted average grant date fair value, ending balance | $ / shares	$ 0

STOCK-BASED COMPENSATION (Addit

STOCK-BASED COMPENSATION (Additional Information) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
PBF LLC [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value	$ 16,797,000
Total intrinsic value of stock options exercised during period	3,452,000	$ 618,000	$ 4,298,000
Unrecognized compensation expense	$ 0	$ 140,000
PBF LLC [Member] | Series A Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting rights percentage	25.00%
Warrants issued		2,740,718
Exercise price per unit		$ 10
Warrants exercised in period	24,000	11,700
Non-compensatory warrants outstanding	32,719	56,719
PBF LLC [Member] | Series B Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting rights percentage	25.00%
Vesting period	3 years
PBF LLC [Member] | Warrant [Member] | Series A Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period	3 years
Expiration period	10 years
PBF LLC [Member] | Employee Stock Option [Member] | Series A Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expiration period	10 years
Parent Company [Member] | Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total intrinsic value of stock options exercised during period	$ 133,000
Parent Company [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted in period	247,720	30,348
PBF Energy Inc. [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period	4 years
Granted in period	1,899,500	1,135,000	697,500
Expiration period	10 years
PBF Energy Inc. [Member] | Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted in period	1,899,500	1,135,000
Total estimated fair value, granted in period	$ 14,512,000	$ 9,068,000
Weighted average fair value per unit	$ 7.64	$ 7.99
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value	$ 38,167,000
Total intrinsic value of stock options exercisable	12,139,000
Unrecognized compensation expense	$ 21,556,000

EMPLOYEE BENEFIT PLANS (Changes

EMPLOYEE BENEFIT PLANS (Changes in Benefit Obligations, Fair Value of Plan Assets, and Funded Status of Plan) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Accumulated Benefit Obligation								$ 80,897	$ 66,576
Pension Benefits [Member]
Change in benefit obligation:
Benefit obligation at beginning of year			$ 100,011	$ 81,098	$ 81,098	$ 53,350
Service cost	$ 10,064	$ 5,790	24,743	17,369	24,298	19,407	$ 14,794
Interest cost	772	710	2,323	2,126	2,974	2,404	992
Plan amendments					0	529
Benefit payments					(2,231)	(2,634)
Actuarial loss (gain)					(6,128)	8,042
Projected benefit obligation at end of year					100,011	81,098	53,350
Change in plan assets:
Fair value of plan assets at beginning of year			57,502	40,956	40,956	25,050
Actual return on plan assets					(13)	1,822
Benefits paid					(2,231)	(2,634)
Employer contributions					18,790	16,718
Fair value of plan assets at end of year					57,502	40,956	25,050
Reconciliation of funded status:
Fair value of plan assets at end of year			57,502	40,956	40,956	25,050	25,050	57,502	40,956
Less benefit obligation at end of year			100,011	81,098	81,098	53,350	53,350	100,011	81,098
Funded status at end of year								(42,509)	(40,142)
Post Retirement Medical Plan [Member]
Change in benefit obligation:
Benefit obligation at beginning of year			17,729	14,740	14,740	8,225
Service cost	304	243	743	731	967	1,099	726
Interest cost	$ 131	$ 134	398	403	558	520	334
Plan amendments					1,533	3,911
Benefit payments					(381)	(215)
Actuarial loss (gain)					312	1,200
Projected benefit obligation at end of year					17,729	14,740	8,225
Change in plan assets:
Fair value of plan assets at beginning of year			0	0	0	0
Actual return on plan assets					0	0
Benefits paid					(381)	(215)
Employer contributions					381	215
Fair value of plan assets at end of year					0	0	0
Reconciliation of funded status:
Fair value of plan assets at end of year			0	0	0	0	0	0	0
Less benefit obligation at end of year			$ 17,729	$ 14,740	$ 14,740	$ 8,225	$ 8,225	17,729	14,740
Funded status at end of year								$ (17,729)	$ (14,740)

EMPLOYEE BENEFIT PLANS (Expecte

EMPLOYEE BENEFIT PLANS (Expected Benefit Payments) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	$ 16,700
2,016	11,125
2,017	8,271
2,018	9,403
2,019	10,694
2,020	13,429
Year 2021 - 2024	88,044
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
2,016	843
2,017	1,141
2,018	1,296
2,019	1,580
2,020	1,788
Year 2021 - 2024	$ 8,835

EMPLOYEE BENEFIT PLANS (Net Per

EMPLOYEE BENEFIT PLANS (Net Periodic Benefit Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year					$ 16,700
Service cost	$ 10,064	$ 5,790	$ 24,743	$ 17,369	24,298	$ 19,407	$ 14,794
Interest cost	772	710	2,323	2,126	2,974	2,404	992
Expected return on plan assets	(1,234)	(830)	(3,447)	(2,489)	(3,422)	(2,156)	(550)
Amortization of prior service costs	13	13	39	39	53	39	11
Amortization of loss	328	311	716	933	1,228	1,033	421
Net periodic benefit cost	9,943	5,994	24,374	17,978	25,131	20,727	15,668
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	304	243	743	731	967	1,099	726
Interest cost	131	134	398	403	558	520	334
Expected return on plan assets					0	0	0
Amortization of prior service costs	161	76	379	228	326	258	0
Amortization of loss	0	0	0	0	0	(4)	0
Net periodic benefit cost	$ 596	$ 453	$ 1,520	$ 1,362	$ 1,851	$ 1,873	$ 1,060

EMPLOYEE BENEFIT PLANS (Pre-tax

EMPLOYEE BENEFIT PLANS (Pre-tax Amounts Recognized in Other Comprehensive Income (Loss)) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service costs (credits)	$ 0	$ 529	$ 0
Net actuarial loss (gain)	(2,220)	8,151	8,235
Amortization of loss	(1,281)	(1,072)	(432)
Total changes in other comprehensive loss (income)	(3,501)	7,608	7,803
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service costs (credits)	1,533	3,911	(860)
Net actuarial loss (gain)	312	1,201	(1,654)
Amortization of loss	(326)	(255)	0
Total changes in other comprehensive loss (income)	$ 1,519	$ 4,857	$ (2,514)

EMPLOYEE BENEFIT PLANS (Pre-t81

EMPLOYEE BENEFIT PLANS (Pre-tax Amounts in AOCI Not Yet Recognized as Components of Net Periodic Costs) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service (costs) credits	$ (529)	$ (582)
Net actuarial (loss) gain	(19,841)	(23,762)
Total	(20,370)	(24,344)
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service (costs) credits	(3,999)	(2,793)
Net actuarial (loss) gain	(391)	(78)
Total	$ (4,390)	$ (2,871)

EMPLOYEE BENEFIT PLANS (Pre-t82

EMPLOYEE BENEFIT PLANS (Pre-tax Amounts in AOCI to be Recognized Over Next Fiscal Year) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service costs (credits)	$ (53)
Amortization of net actuarial loss (gain)	(775)
Total	(828)
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service costs (credits)	(436)
Amortization of net actuarial loss (gain)	0
Total	$ (436)

EMPLOYEE BENEFIT PLANS (Assumpt

EMPLOYEE BENEFIT PLANS (Assumptions Used) (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Pension Benefits [Member]
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate	4.17%	3.70%
Rate of compensation increase	4.81%	4.96%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Expected long-term rate of return on plan assets	7.00%	6.70%	3.50%
Rate of compensation increase	4.81%	4.64%	4.00%
Supplemental Employee Retirement Plan [Member]
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate	4.22%	3.70%
Rate of compensation increase	5.50%	4.96%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Expected long-term rate of return on plan assets	0.00%	0.00%	0.00%
Rate of compensation increase	5.50%	4.64%	4.00%
Post Retirement Medical Plan [Member]
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate	3.76%	3.70%
Rate of compensation increase	0.00%	0.00%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Expected long-term rate of return on plan assets	0.00%	0.00%	0.00%
Rate of compensation increase	0.00%	0.00%	0.00%
Service Cost [Member] | Pension Benefits [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	4.25%	4.55%	3.45%
Service Cost [Member] | Supplemental Employee Retirement Plan [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	4.30%	4.55%	3.45%
Service Cost [Member] | Post Retirement Medical Plan [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	4.32%	4.55%	3.45%
Effective rate for interest cost [Member] | Pension Benefits [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	3.31%	4.55%	3.45%
Effective rate for interest cost [Member] | Supplemental Employee Retirement Plan [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	3.16%	4.55%	3.45%
Effective rate for interest cost [Member] | Post Retirement Medical Plan [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	3.09%	4.55%	3.45%
Effective rate for interest on service cost [Member] | Pension Benefits [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	3.51%	4.55%	3.45%
Effective rate for interest on service cost [Member] | Supplemental Employee Retirement Plan [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	3.37%	4.55%	3.45%
Effective rate for interest on service cost [Member] | Post Retirement Medical Plan [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	4.04%	4.55%	3.45%

EMPLOYEE BENEFIT PLANS (Assumed

EMPLOYEE BENEFIT PLANS (Assumed Health Care Cost Trend Rates) (Details) - Post Retirement Medical Plan [Member]	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	6.10%	6.70%
Rate to which the cost trend rate was assumed to decline (the ultimate trend rate)	4.50%	4.50%
Year that the rate reached the ultimate trend rate	2,038	2,027

EMPLOYEE BENEFIT PLANS (Effect

EMPLOYEE BENEFIT PLANS (Effect of One-percentage-point Change in Assumed Health Care Cost Trend Rates) (Details) - Post Retirement Medical Plan [Member] $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Defined Benefit Plan Disclosure [Line Items]
Effect on total of service and interest cost components, 1% increase	$ 21
Effect on total of service and interest cost components, 1% decrease	(20)
Effect on accumulated postretirement benefit obligation, 1% increase	413
Effect on accumulated postretirement benefit obligation, 1% decrease	$ (388)

EMPLOYEE BENEFIT PLANS (Fair Va

EMPLOYEE BENEFIT PLANS (Fair Value of Assets of the Company's Qualified Plan) (Details) - Pension Benefits [Member] - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$ 57,502	$ 40,956	$ 25,050
Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	57,502	40,956
Level 1 [Member] | Domestic Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	17,660	12,682
Level 1 [Member] | Developed International Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	8,320	5,600
Level 1 [Member] | Emerging Market Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	4,017	2,629
Level 1 [Member] | Global Low Volatility Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	4,930	3,478
Level 1 [Member] | Fixed-Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	22,495	16,517
Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$ 80	$ 50

EMPLOYEE BENEFIT PLANS (Additio

EMPLOYEE BENEFIT PLANS (Additional Information) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Maximum age to receive health care coverage	65 years
Defined Benefit Plan, Accumulated Benefit Obligation	$ 80,897	$ 66,576
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Required service period for employee participation	30 days
Basic contributions as a percentage of annual salary	50.00%
Company matching contribution, percent of match	200.00%
Company matching contribution, percent of employees' annual pay	3.00%
Contribution to the qualified defined contribution plans	$ 12,753	$ 11,364	$ 10,450
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	$ 16,700
Pension Benefits [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	60.00%
Pension Benefits [Member] | Fixed Income Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	40.00%

REVENUES (Details)

REVENUES (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Product Information [Line Items]
Revenues	$ 4,508,613	$ 3,217,640	$ 11,164,571	$ 9,763,440	$ 13,123,929	$ 19,828,155	$ 19,151,455
Gasoline and Distillates [Member]
Product Information [Line Items]
Revenues					11,553,716	17,050,096	16,973,239
Chemicals [Member]
Product Information [Line Items]
Revenues					452,304	739,096	746,396
Asphalt and blackoils [Member]
Product Information [Line Items]
Revenues					536,496	706,494	690,305
Lubricants [Member]
Product Information [Line Items]
Revenues					266,371	410,466	468,315
Other [Member]
Product Information [Line Items]
Revenues					$ 315,042	$ 922,003	$ 273,200

INCOME TAXES Income Tax (Detail

INCOME TAXES Income Tax (Details) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended	9 Months Ended		12 Months Ended
	Sep. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Jun. 30, 2016	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax [Line Items]
Income tax expense	$ 2,291		$ 0		$ 29,287	$ 0	$ 648	$ 0	$ 0
Deferred income taxes					27,813	$ 0
Collins Pipeline Company And T&M Terminal Company [Member]
Income Tax [Line Items]
Income tax expense	348				1,512
PBF Energy Limited [Member]
Income Tax [Line Items]
Current Income Tax Expense (Benefit)	(41)				(38)
Deferred income taxes	$ 1,902				$ 27,813
Restatement Adjustment [Member]
Income Tax [Line Items]
Income tax expense		$ 30,481
Deferred Tax Liabilities, Net		$ 30,481
Restatement Adjustment [Member] | Prior Period Error Correction [Member] | PBF Energy Limited [Member]
Income Tax [Line Items]
Current Income Tax Expense (Benefit)				$ 30,602
Deferred income taxes				121
Deferred Tax Liabilities, Net				30,602
Taxes Payable, Current				$ 121

FAIR VALUE MEASUREMENTS (Measur

FAIR VALUE MEASUREMENTS (Measured on Recurring Basis) (Details) - Fair Value, Measurements, Recurring [Member] - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 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		$ 9,325	$ 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	$ 9,773	9,325	5,494
Fair Value, Inputs, 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
Inventory Supply Arrangement Obligation [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		35,511	4,251
Derivative, Collateral, Obligation to Return Cash		0	0
Derivative Asset		35,511	4,251
Inventory Supply Arrangement Obligation [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
Inventory Supply Arrangement Obligation [Member] | Fair Value, Inputs, 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		35,511	4,251
Inventory Supply Arrangement Obligation [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
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	30,065	52,482	397,676
Derivative, Collateral, Right to Reclaim Cash	(30,065)	(52,482)	(397,676)
Derivative Liability	0	0	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	26,618	49,960	390,144
Derivative Liability		49,960
Commodity contract [Member] | Fair Value, Inputs, 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	3,447	2,522	7,338
Derivative Liability		2,522
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	0	0	194
Derivative Liability		0
Catalyst Lease Obligation [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative, Collateral, Right to Reclaim Cash	0	0	0
Obligations, Fair Value Disclosure	44,286	31,802	36,559
Catalyst Lease Obligation [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0	0
Catalyst Lease Obligation [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	44,286	31,802	36,559
Catalyst Lease Obligation [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Obligations, Fair Value Disclosure	0	0	0
Money market funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	307,508	631,280	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, Fair Value Disclosure	307,508	631,280	5,575
Money market funds [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	0	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, Fair Value Disclosure	0	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	34,908	98,609	428,831
Derivative, Collateral, Obligation to Return Cash	(30,065)	(52,482)	(397,676)
Derivative Asset	4,843	46,127	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	24,086	63,810	415,023
Derivative Asset		63,810
Commodity contract [Member] | Fair Value, Inputs, 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	10,440	31,256	12,093
Derivative Asset		31,256
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	382	3,543	1,715
Derivative Asset		3,543
Inventory Intermediation Agreement Obligation [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	6,194	35,511	94,834
Derivative, Collateral, Obligation to Return Cash	0	0	0
Derivative Asset	6,194	35,511	94,834
Inventory Intermediation Agreement Obligation [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
Derivative Asset		0
Inventory Intermediation Agreement Obligation [Member] | Fair Value, Inputs, 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	6,194		94,834
Derivative Asset		35,511
Inventory Intermediation Agreement Obligation [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
Derivative Asset		$ 0

FAIR VALUE MEASUREMENTS (Change

FAIR VALUE MEASUREMENTS (Change in Fair Value at Level 3) (Details) - USD ($)	3 Months Ended				9 Months Ended		12 Months Ended
	Sep. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Mar. 31, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Transfers into Level 3	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0
Commodity Contract [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at beginning of period	493,000	$ 3,543,000	1,905,000	$ 1,521,000	3,543,000	1,521,000	$ 1,521,000	$ (23,365,000)
Purchases	0		0		0	0	0	0
Settlements	(90,000)		(1,238,000)		(1,093,000)	(12,549,000)	(15,222,000)	(22,055,000)
Unrealized loss included in earnings	(21,000)		(852,000)		(2,068,000)	10,843,000	17,244,000	46,941,000
Transfers into Level 3	0		0		0	0	0	0
Transfers out of Level 3	0		0		0	0	0	0
Balance at end of period	$ 382,000		$ (185,000)		$ 382,000	$ (185,000)	$ 3,543,000	$ 1,521,000

FAIR VALUE MEASUREMENTS (Fair V

FAIR VALUE MEASUREMENTS (Fair Value and Carrying Value of Debt) (Details) - USD ($) $ in Thousands		Sep. 30, 2016	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		$ 1,820,872	$ 1,268,937
Long-term Debt, Gross			1,268,937	$ 742,349
Long-term debt, Fair value		1,823,001	1,297,991	749,409
Less - Current maturities		0	0	0
Less - Current maturities, Fair value		0	0	0
Unamortized Debt Issuance Expense		26,505	32,217	30,128
Long-term debt		1,794,367	1,236,720	712,221
Long-term debt, Fair value		1,823,001	1,297,991	749,409
Senior secured notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		670,551	669,644
Long-term Debt, Gross	[1]			668,520
Long-term debt, Fair value		697,649	706,246	675,580	[1]
Long-term Line of Credit		550,000	0	0
Lines of Credit, Fair Value Disclosure		550,000	0	0
Long-term debt			669,644	668,520
2023 Senior Secured Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Gross	[2]			0
Long-term debt, Fair value		475,031	492,452	0
Long-term debt		500,000	500,000
Rail Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Line of Credit		56,035	67,491
Lines of Credit, Fair Value Disclosure		56,035	67,491
Catalyst lease [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		44,286	31,802
Long-term Debt, Gross	[3]			36,559
Long-term debt, Fair value		44,286	31,802	36,559	[3]
Long-term debt			31,802
Revolving Credit Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt			0
Rail Facility [Member] | Line of Credit [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, Measurements, Recurring [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Obligations, Fair Value Disclosure		44,286	31,802	36,559
Catalyst lease [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Obligations, Fair Value Disclosure		$ 44,286	$ 31,802	$ 36,559
[1]	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.
[2]	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.
[3]	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 (Narrative) (Detail

DERIVATIVES (Narrative) (Details)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016USD ($)bbl	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)bbl	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)bbl	Dec. 31, 2014USD ($)bbl	Dec. 31, 2013USD ($)
Derivative [Line Items]
Gain (loss) on fair value hedge ineffectiveness | $	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ (7,264,000)
Crude Oil and Feedstock Inventory [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	0		0		0	0
Crude Oil and Feedstock Inventory [Member] | Fair Value Hedging [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	0		0		0	662,579
Intermediates and Refined Products Inventory [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	0		0		0	0
Intermediates and Refined Products Inventory [Member] | Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, notional amount, volume	3,284,395		3,284,395		3,776,011
Intermediates and Refined Products Inventory [Member] | Fair Value Hedging [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume					3,776,011	3,106,325
Crude Oil Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	22,482,500		22,482,500		39,577,000	47,339,000
Refined Product Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	8,927,000		8,927,000		4,599,136	1,970,871

DERIVATIVES (Fair Value of Deri

DERIVATIVES (Fair Value of Derivative Instruments) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 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)		$ 0	$ 4,251
Designated as Hedging Instrument [Member] | Inventory Intermediation Agreement Obligation [Member] | Accrued Expenses [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	$ 6,194	35,511	94,834
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Accrued Expenses [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)			$ 31,155
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Accounts Receivable [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	$ 4,843	$ 46,127

DERIVATIVES (Gain (Loss) Recogn

DERIVATIVES (Gain (Loss) Recognized in Income) (Details) - Cost of Sales [Member] - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Designated as Hedging Instrument [Member] | Inventory Supply Arrangement Obligation [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives		$ 1,409		$ (3,220)	$ (4,251)	$ 4,428	$ (5,773)
Designated as Hedging Instrument [Member] | Inventory Intermediation Agreement Obligation [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	$ (3,145)	34,424	$ (29,317)	(50,150)	(59,323)	88,818	6,016
Designated as Hedging Instrument [Member] | Crude Oil and Feedstock Inventory [Member] | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives		(1,409)		3,220	4,251	(4,428)	(1,491)
Designated as Hedging Instrument [Member] | Intermediates and Refined Products Inventory [Member] | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	3,145	(34,424)	29,317	50,150	59,323	(88,818)	(6,016)
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	$ (15,559)	$ 31,017	$ (54,646)	$ (14,080)	$ 32,416	$ 146,016	$ (88,962)

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details)	Oct. 28, 2016USD ($)$ / shares	Oct. 18, 2016USD ($)lease	Feb. 11, 2016USD ($)$ / shares	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Oct. 19, 2016USD ($)
Subsequent Event [Line Items]
Payments of Capital Distribution				$ 92,503,000	$ 0	$ 350,658,000	$ 361,352,000	$ 215,846,000
Stockholders' Equity, Capital Distributions						$ 350,658,000	$ 361,352,000	$ 215,846,000
PBF Energy Inc. [Member]
Subsequent Event [Line Items]
Payments of Capital Distribution			$ 30,829,000
PBF Energy Inc. [Member] | Class A Common Stock [Member]
Subsequent Event [Line Items]
Dividends declared per share | $ / shares			$ 0.30
Subsequent Event [Member] | PBF Energy [Member] | Class A Common Stock [Member]
Subsequent Event [Line Items]
Dividends declared per share | $ / shares	$ 0.3
Stockholders' Equity, Capital Distributions	$ 30,839,000
Catalyst Lease Obligation [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Number Of Leases | lease		2
Non-cancelable operating lease term		3 years
Catalyst Lease Obligation, Platinum [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Lessee Leasing Arrangements, Capital Leases, Stated Interest Rate		1.95%
Lessee Leasing Arrangement, Annual Payment		$ 210,000
Catalyst Lease Obligation, Palladium [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Lessee Leasing Arrangements, Capital Leases, Stated Interest Rate		2.05%
Lessee Leasing Arrangement, Annual Payment		$ 30,000
Chalmette Catalyst Lease [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Lessee Leasing Arrangements, Capital Leases, Stated Interest Rate									2.20%
Lessee Leasing Arrangement, Annual Payment									$ 43,000

CONSOLIDATING FINANCIAL STATE97

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Narrative) (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015	Sep. 01, 2016
PBF Services Company [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries	100.00%	100.00%
Delaware City Refining Company LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries	100.00%	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%	100.00%
Paulsboro Refining Company LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries	100.00%	100.00%
Paulsboro Natural Gas Pipeline Company LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries	100.00%	100.00%
Toledo Refining Company LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries	100.00%	100.00%
Chalmette Refining L.L.C. [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries	100.00%
PBF Investments LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of ownership in subsidiaries	100.00%	100.00%
Torrance Valley Pipeline Company [Member]
Condensed Financial Statements, Captions [Line Items]
Noncontrolling Interest, ownership Percentage by Parent	50.00%		50.00%

CONSOLIDATING FINANCIAL STATE98

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Balance Sheet) (Details) - USD ($)	Sep. 30, 2016	Dec. 31, 2015	Sep. 30, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jun. 30, 2010
Current assets:
Cash and cash equivalents	$ 519,375,000	$ 914,749,000	$ 369,421,000	$ 218,403,000	$ 76,970,000	$ 254,291,000
Accounts receivable	649,657,000	454,759,000		551,269,000
Accounts receivable - affiliate	3,041,000	3,438,000		3,223,000
Inventories	1,845,595,000	1,174,272,000		1,102,261,000
Prepaid expense and other current assets	55,090,000	33,701,000		32,157,000
Due from related parties	0	0		0
Total current assets	3,072,758,000	2,580,919,000		1,907,313,000
Property, plant and equipment, net	2,659,383,000	2,211,090,000		1,806,060,000
Investment in subsidiaries	0	0		0
Investment in equity method investee	176,267,000	0
Deferred charges and other assets, net	449,271,000	290,713,000		300,389,000
Due from related party - long term		0
Total assets	6,357,679,000	5,082,722,000		4,013,762,000
Current liabilities:
Accounts payable	367,829,000	314,843,000		335,182,000
Accounts payable	31,746,000	23,949,000		11,630,000
Accrued expenses	1,521,488,000	1,117,435,000		1,129,970,000
Current portion of long-term debt	0	0		0
Deferred tax liabilities	27,989,000	0
Deferred revenue	12,072,000	4,043,000		1,227,000
Due to related parties	0	0		0
Total current liabilities	1,961,124,000	1,460,270,000		1,478,009,000
Delaware Economic Development Authority loan	4,000,000	4,000,000		8,000,000			$ 20,000,000
Long-term debt	1,794,367,000	1,236,720,000		712,221,000
Intercompany notes payable	470,165,000	470,047,000		122,264,000
Deferred tax liabilities	25,721,000	20,577,000		0
Other long-term liabilities	213,635,000	69,824,000		62,752,000
Due to related party - long term		0
Total liabilities	4,469,012,000	3,261,438,000		2,383,246,000
Commitments and contingencies
Equity:
Member's equity	1,494,477,000	1,479,175,000		1,144,100,000
Retained earnings	404,777,000	349,654,000		513,292,000
Accumulated other comprehensive loss	(23,307,000)	(24,770,000)		(26,876,000)
Total PBF Holding Company LLC equity	1,875,947,000	1,804,059,000		1,630,516,000
Noncontrolling interest	12,720,000	17,225,000		0
Total equity	1,888,667,000	1,821,284,000		1,630,516,000	1,772,153,000	1,751,654,000
Total liabilities and equity	6,357,679,000	5,082,722,000		4,013,762,000
Issuer [Member]
Current assets:
Cash and cash equivalents	456,179,000	882,820,000	361,037,000	185,381,000	76,179,000	241,926,000
Accounts receivable	636,625,000	430,809,000		518,498,000
Accounts receivable - affiliate	21,000	917,000		529,000
Inventories	1,640,072,000	608,646,000		510,947,000
Prepaid expense and other current assets	30,573,000	24,243,000		26,964,000
Due from related parties	23,111,940,000	20,236,649,000		16,189,384,000
Total current assets	25,875,410,000	22,184,084,000		17,431,703,000
Property, plant and equipment, net	34,647,000	25,240,000		68,218,000
Investment in subsidiaries	1,072,153,000	1,740,111,000		2,569,636,000
Investment in equity method investee	0	0
Deferred charges and other assets, net	31,696,000	23,973,000		5,899,000
Due from related party - long term		0
Total assets	27,013,906,000	23,973,408,000		20,075,456,000
Current liabilities:
Accounts payable	234,062,000	196,988,000		235,791,000
Accounts payable	31,746,000	23,949,000		11,600,000
Accrued expenses	1,240,409,000	503,179,000		487,783,000
Current portion of long-term debt		0		0
Deferred tax liabilities	0
Deferred revenue	10,602,000	4,043,000		1,227,000
Due to related parties	21,414,670,000	19,787,807,000		16,924,490,000
Total current liabilities	22,931,489,000	20,515,966,000		17,660,891,000
Delaware Economic Development Authority loan	0	0		0
Long-term debt	1,694,390,000	1,137,980,000		639,579,000
Intercompany notes payable	470,165,000	470,047,000		122,264,000
Deferred tax liabilities	0	0
Other long-term liabilities	29,195,000	28,131,000		22,206,000
Due to related party - long term		0
Total liabilities	25,125,239,000	22,152,124,000		18,444,940,000
Commitments and contingencies
Equity:
Member's equity	1,494,477,000	1,479,175,000		1,144,100,000
Retained earnings	404,777,000	349,654,000		513,292,000
Accumulated other comprehensive loss	(23,307,000)	(24,770,000)		(26,876,000)
Total PBF Holding Company LLC equity	1,875,947,000	1,804,059,000
Noncontrolling interest	12,720,000	17,225,000		0
Total equity	1,888,667,000	1,821,284,000		1,630,516,000
Total liabilities and equity	27,013,906,000	23,973,408,000		20,075,456,000
Guarantors Subsidiaries [Member]
Current assets:
Cash and cash equivalents	20,531,000	6,236,000	3,000	704,000	791,000	12,365,000
Accounts receivable	7,362,000	11,057,000		26,238,000
Accounts receivable - affiliate	0	2,521,000		2,694,000
Inventories	0	363,151,000		435,924,000
Prepaid expense and other current assets	22,026,000	9,074,000		5,193,000
Due from related parties	21,567,312,000	20,547,503,000		18,805,509,000
Total current assets	21,617,231,000	20,939,542,000		19,276,262,000
Property, plant and equipment, net	2,303,359,000	1,960,066,000		1,683,294,000
Investment in subsidiaries	605,169,000	143,349,000		0
Investment in equity method investee	0	0
Deferred charges and other assets, net	416,062,000	265,240,000		292,990,000
Due from related party - long term		0
Total assets	24,941,821,000	23,308,197,000		21,252,546,000
Current liabilities:
Accounts payable	133,195,000	113,564,000		92,984,000
Accounts payable	0	0		30,000
Accrued expenses	160,036,000	495,842,000		450,856,000
Current portion of long-term debt		0		0
Deferred tax liabilities	0
Deferred revenue	0	0		0
Due to related parties	23,247,282,000	21,026,310,000		18,151,095,000
Total current liabilities	23,540,513,000	21,635,716,000		18,694,965,000
Delaware Economic Development Authority loan	4,000,000	4,000,000		8,000,000
Long-term debt	44,219,000	31,717,000		36,451,000
Intercompany notes payable	0	0		0
Deferred tax liabilities	0	0
Other long-term liabilities	176,821,000	41,693,000		40,546,000
Due to related party - long term		20,577,000
Total liabilities	23,765,553,000	21,733,703,000		18,779,962,000
Commitments and contingencies
Equity:
Member's equity	1,733,830,000	1,062,717,000		749,278,000
Retained earnings	(562,045,000)	502,788,000		1,731,694,000
Accumulated other comprehensive loss	(8,237,000)	(8,236,000)		(8,388,000)
Total PBF Holding Company LLC equity	1,163,548,000	1,557,269,000
Noncontrolling interest	12,720,000	17,225,000		0
Total equity	1,176,268,000	1,574,494,000		2,472,584,000
Total liabilities and equity	24,941,821,000	23,308,197,000		21,252,546,000
Non-Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	44,534,000	28,968,000	10,231,000	34,334,000	0	0
Accounts receivable	5,670,000	12,893,000		6,533,000
Accounts receivable - affiliate	3,020,000	0		0
Inventories	205,523,000	202,475,000		155,390,000
Prepaid expense and other current assets	2,491,000	384,000		0
Due from related parties	4,215,051,000	3,262,382,000		1,607,878,000
Total current assets	4,476,289,000	3,507,102,000		1,804,135,000
Property, plant and equipment, net	321,377,000	225,784,000		54,548,000
Investment in subsidiaries	0	0		0
Investment in equity method investee	176,267,000	0
Deferred charges and other assets, net	1,513,000	1,500,000		1,500,000
Due from related party - long term		20,577,000
Total assets	4,975,446,000	3,754,963,000		1,860,183,000
Current liabilities:
Accounts payable	2,441,000	7,566,000		8,423,000
Accounts payable	0	0		0
Accrued expenses	121,043,000	118,414,000		191,331,000
Current portion of long-term debt		0		0
Deferred tax liabilities	27,989,000
Deferred revenue	1,470,000	0		0
Due to related parties	4,232,351,000	3,232,417,000		1,527,186,000
Total current liabilities	4,385,294,000	3,358,397,000		1,726,940,000
Delaware Economic Development Authority loan	0	0		0
Long-term debt	55,758,000	67,023,000		36,191,000
Intercompany notes payable	0	0		0
Deferred tax liabilities	25,721,000	20,577,000
Other long-term liabilities	7,619,000	0		0
Due to related party - long term		0
Total liabilities	4,474,392,000	3,445,997,000		1,763,131,000
Commitments and contingencies
Equity:
Member's equity	433,421,000	182,696,000		44,346,000
Retained earnings	67,633,000	126,270,000		52,706,000
Accumulated other comprehensive loss	0	0		0
Total PBF Holding Company LLC equity	501,054,000	308,966,000
Noncontrolling interest	0	0		0
Total equity	501,054,000	308,966,000		97,052,000
Total liabilities and equity	4,975,446,000	3,754,963,000		1,860,183,000
Combining and Consolidated Adjustments [Member]
Current assets:
Cash and cash equivalents	(1,869,000)	(3,275,000)	$ (1,850,000)	(2,016,000)	$ 0	$ 0
Accounts receivable	0	0		0
Accounts receivable - affiliate	0	0		0
Inventories	0	0		0
Prepaid expense and other current assets	0	0		0
Due from related parties	(48,894,303,000)	(44,046,534,000)		(36,602,771,000)
Total current assets	(48,896,172,000)	(44,049,809,000)		(36,604,787,000)
Property, plant and equipment, net	0	0		0
Investment in subsidiaries	(1,677,322,000)	(1,883,460,000)		(2,569,636,000)
Investment in equity method investee	0	0
Deferred charges and other assets, net	0	0		0
Due from related party - long term		(20,577,000)
Total assets	(50,573,494,000)	(45,953,846,000)		(39,174,423,000)
Current liabilities:
Accounts payable	(1,869,000)	(3,275,000)		(2,016,000)
Accounts payable	0	0		0
Accrued expenses	0	0		0
Current portion of long-term debt		0		0
Deferred tax liabilities	0
Deferred revenue	0	0		0
Due to related parties	(48,894,303,000)	(44,046,534,000)		(36,602,771,000)
Total current liabilities	(48,896,172,000)	(44,049,809,000)		(36,604,787,000)
Delaware Economic Development Authority loan	0	0		0
Long-term debt	0	0		0
Intercompany notes payable	0	0		0
Deferred tax liabilities	0	0
Other long-term liabilities	0	0		0
Due to related party - long term		(20,577,000)
Total liabilities	(48,896,172,000)	(44,070,386,000)		(36,604,787,000)
Commitments and contingencies
Equity:
Member's equity	(2,167,251,000)	(1,245,413,000)		(793,624,000)
Retained earnings	494,412,000	(629,058,000)		(1,784,400,000)
Accumulated other comprehensive loss	8,237,000	8,236,000		8,388,000
Total PBF Holding Company LLC equity	(1,664,602,000)	(1,866,235,000)
Noncontrolling interest	(12,720,000)	(17,225,000)		0
Total equity	(1,677,322,000)	(1,883,460,000)		(2,569,636,000)
Total liabilities and equity	$ (50,573,494,000)	$ (45,953,846,000)		$ (39,174,423,000)

CONSOLIDATING FINANCIAL STATE99

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Statement of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Income Statements, Captions [Line Items]
Revenues	$ 4,508,613	$ 3,217,640	$ 11,164,571	$ 9,763,440	$ 13,123,929	$ 19,828,155	$ 19,151,455
Cost and expenses:
Cost of sales, excluding depreciation	3,904,258	2,858,409	9,634,989	8,414,423	11,611,599	18,514,054	17,803,314
Operating expenses, excluding depreciation	404,045	200,014	972,223	625,542	889,368	880,701	812,652
General and administrative expenses	39,912	47,802	111,272	116,115	166,904	140,150	95,794
Equity (income) loss in investee	(1,621)	0	(1,621)	0
Loss (gain) on sale of assets	8,159	(142)	11,381	(1,133)	(1,004)	(895)	(183)
Depreciation and amortization expense	52,678	46,484	155,890	139,757	191,110	178,996	111,479
Total cost and expenses	4,407,431	3,152,567	10,884,134	9,294,704	12,857,977	19,713,006	18,823,056
Income from operations	101,182	65,073	280,437	468,736	265,952	115,149	328,399
Other income (expense)
Equity in earnings (loss) of subsidiaries	0	0	0	0	0	0	0
Change in fair value of catalyst lease	77	4,994	(4,556)	8,982	10,184	3,969	4,691
Acquisition related costs							0
Interest expense, net	(33,896)	(21,888)	(98,446)	(65,915)	(88,194)	(98,001)	(94,214)
Income before income taxes	67,363	48,179	177,435	411,803	187,942	21,117	238,876
Income tax expense	2,291	0	29,287	0	648	0	0
Net income	65,072	48,179	148,148	411,803	187,294	21,117	238,876
Less income attributable to noncontrolling interests	45	0	438	0	274	0	0
Net income attributable to PBF Holding Company LLC	65,027	48,179	147,710	411,803	187,020	21,117	238,876
Comprehensive income (loss) attributable to PBF Holding Company LLC	65,453	48,698	149,173	413,118	189,126	8,779	233,279
Issuer [Member]
Condensed Income Statements, Captions [Line Items]
Revenues	4,488,925	3,215,163	11,119,301	9,737,169	13,085,122	19,847,045	16,190,178
Cost and expenses:
Cost of sales, excluding depreciation	3,914,018	2,843,303	9,653,945	8,370,720	11,514,115	18,467,533	16,486,851
Operating expenses, excluding depreciation	25	(95)	(375)	(3,814)	(3,683)	218	(482)
General and administrative expenses	34,820	40,002	92,126	98,330	143,580	123,692	82,284
Equity (income) loss in investee	0	0	0	0
Loss (gain) on sale of assets	2,418	(70)	2,418	(251)	(249)	(277)	(388)
Depreciation and amortization expense	1,341	2,117	4,417	7,664	9,687	13,583	12,856
Total cost and expenses	3,952,622	2,885,257	9,752,531	8,472,649	11,663,450	18,604,749	16,581,121
Income from operations	536,303	329,906	1,366,770	1,264,520	1,421,672	1,242,296	(390,943)
Other income (expense)
Equity in earnings (loss) of subsidiaries	(438,249)	(262,000)	(1,123,054)	(793,606)	(1,154,420)	(1,131,321)	722,673
Change in fair value of catalyst lease	0	0	0	0	0	0	0
Acquisition related costs							0
Interest expense, net	(32,982)	(19,727)	(95,568)	(59,111)	(79,310)	(89,858)	(92,854)
Income before income taxes	65,072	48,179	148,148	411,803	187,942	21,117	238,876
Income tax expense	0	0	0	0	0	0	0
Net income	65,072	48,179	148,148	411,803	187,942	21,117	238,876
Less income attributable to noncontrolling interests	45	0	438	0	274	0	0
Net income attributable to PBF Holding Company LLC	65,027	48,179	147,710	411,803	187,668	21,117	238,876
Comprehensive income (loss) attributable to PBF Holding Company LLC	65,453	48,698	149,173	413,118	189,774	8,779	233,279
Guarantors Subsidiaries [Member]
Condensed Income Statements, Captions [Line Items]
Revenues	441,554	132,000	586,336	668,576	884,930	1,402,253	7,641,498
Cost and expenses:
Cost of sales, excluding depreciation	428,587	176,823	532,040	749,706	1,026,846	1,522,901	5,996,684
Operating expenses, excluding depreciation	385,761	200,384	948,403	629,846	891,534	880,339	813,134
General and administrative expenses	4,312	6,827	20,372	15,987	21,016	16,259	13,510
Equity (income) loss in investee	0	0	0	0
Loss (gain) on sale of assets	73	1	97	(232)	(105)	0	205
Depreciation and amortization expense	47,472	43,820	143,994	130,496	178,578	164,525	98,623
Total cost and expenses	866,205	427,855	1,644,906	1,525,803	2,117,869	2,584,024	6,922,156
Income from operations	(424,651)	(295,855)	(1,058,570)	(857,227)	(1,232,939)	(1,181,771)	719,342
Other income (expense)
Equity in earnings (loss) of subsidiaries	0	0	0	0	0	0	0
Change in fair value of catalyst lease	77	4,994	(4,556)	8,982	10,184	3,969	0
Acquisition related costs							4,691
Interest expense, net	(447)	(1,277)	(1,289)	(4,342)	(5,876)	(6,225)	(1,360)
Income before income taxes	(425,021)	(292,138)	(1,064,415)	(852,587)	(1,228,631)	(1,184,027)	722,673
Income tax expense	0	0	0	0	0	0	0
Net income	(425,021)	(292,138)	(1,064,415)	(852,587)	(1,228,631)	(1,184,027)	722,673
Less income attributable to noncontrolling interests	45	0	438	0	274	0	0
Net income attributable to PBF Holding Company LLC	(425,066)	(292,138)	(1,064,853)	(852,587)	(1,228,905)	(1,184,027)	722,673
Comprehensive income (loss) attributable to PBF Holding Company LLC	(425,066)	(292,138)	(1,064,853)	(852,587)	(1,228,905)	(1,194,031)	724,930
Non-Guarantor Subsidiaries [Member]
Condensed Income Statements, Captions [Line Items]
Revenues	345,215	422,306	1,005,656	1,250,957	1,633,818	1,007,407	0
Cost and expenses:
Cost of sales, excluding depreciation	328,734	390,112	995,726	1,187,259	1,550,579	952,170	0
Operating expenses, excluding depreciation	18,259	(275)	24,195	(490)	1,517	144	0
General and administrative expenses	780	973	(1,226)	1,798	2,308	199	0
Equity (income) loss in investee	(1,621)	0	(1,621)	0
Loss (gain) on sale of assets	5,668	(73)	8,866	(650)	(650)	(618)	0
Depreciation and amortization expense	3,865	547	7,479	1,597	2,845	888	0
Total cost and expenses	355,685	391,284	1,033,419	1,189,514	1,556,599	952,783	0
Income from operations	(10,470)	31,022	(27,763)	61,443	77,219	54,624	0
Other income (expense)
Equity in earnings (loss) of subsidiaries	0	0	0	0	0	0	0
Change in fair value of catalyst lease	0	0	0	0	0	0	0
Acquisition related costs							0
Interest expense, net	(467)	(884)	(1,589)	(2,462)	(3,008)	(1,918)	0
Income before income taxes	(10,937)	30,138	(29,352)	58,981	74,211	52,706	0
Income tax expense	2,291	0	29,287	0	648	0	0
Net income	(13,228)	30,138	(58,639)	58,981	73,563	52,706	0
Less income attributable to noncontrolling interests	0	0	0	0	0	0	0
Net income attributable to PBF Holding Company LLC	(13,228)	30,138	(58,639)	58,981	73,563	52,706	0
Comprehensive income (loss) attributable to PBF Holding Company LLC	(13,228)	30,138	(58,639)	58,981	73,563	52,706	0
Combining and Consolidated Adjustments [Member]
Condensed Income Statements, Captions [Line Items]
Revenues	(767,081)	(551,829)	(1,546,722)	(1,893,262)	(2,479,941)	(2,428,550)	(4,680,221)
Cost and expenses:
Cost of sales, excluding depreciation	(767,081)	(551,829)	(1,546,722)	(1,893,262)	(2,479,941)	(2,428,550)	(4,680,221)
Operating expenses, excluding depreciation	0	0	0	0	0	0	0
General and administrative expenses	0	0	0	0	0	0	0
Equity (income) loss in investee	0	0	0	0
Loss (gain) on sale of assets	0	0	0	0	0	0	0
Depreciation and amortization expense	0	0	0	0	0	0	0
Total cost and expenses	(767,081)	(551,829)	(1,546,722)	(1,893,262)	(2,479,941)	(2,428,550)	(4,680,221)
Income from operations	0	0	0	0	0	0	0
Other income (expense)
Equity in earnings (loss) of subsidiaries	438,249	262,000	1,123,054	793,606	1,154,420	1,131,321	(722,673)
Change in fair value of catalyst lease	0	0	0	0	0	0	0
Acquisition related costs							0
Interest expense, net	0	0	0	0	0	0	0
Income before income taxes	438,249	262,000	1,123,054	793,606	1,154,420	1,131,321	(722,673)
Income tax expense	0	0	0	0	0	0	0
Net income	438,249	262,000	1,123,054	793,606	1,154,420	1,131,321	(722,673)
Less income attributable to noncontrolling interests	(45)	0	(438)	0	(274)	0	0
Net income attributable to PBF Holding Company LLC	438,294	262,000	1,123,492	793,606	1,154,694	1,131,321	(722,673)
Comprehensive income (loss) attributable to PBF Holding Company LLC	$ 438,294	$ 262,000	$ 1,123,492	$ 793,606	$ 1,154,694	$ 1,141,325	$ (724,930)

CONSOLIDATING FINANCIAL STAT100

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Statement of Cash Flows) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash flows from operating activities:
Net income	$ 65,072	$ 48,179	$ 148,148	$ 411,803	$ 187,294	$ 21,117	$ 238,876
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization			162,565	145,975	199,383	186,412	118,001
Stock-based compensation			12,658	6,329	9,218	6,095	3,753
Change in fair value of catalyst lease obligation			4,556	(8,982)	(10,184)	(3,969)	(4,691)
Deferred income taxes			27,813	0
Non-cash lower of cost or market inventory adjustment			(320,833)	81,147	427,226	690,110	0
Non-cash change inventory repurchase obligations			29,317	53,370	63,389	(93,246)	(20,492)
Pension and other post retirement benefits costs			25,894	19,340	26,982	22,600	16,728
Gain on disposition of property, plant and equipment			11,381	(1,133)	(1,004)	(895)	(183)
(Gain) loss on sale of assets	8,159	(142)	11,381	(1,133)	(1,004)	(895)	(183)
Equity in earnings of subsidiaries	0	0	0	0	0	0	0
Equity (income) loss in investee	(1,621)	0	(1,621)	0
Changes in current assets and current liabilities:
Accounts receivable			(194,898)	155,645	97,636	45,378	(92,851)
Due to/from affiliates					12,104	8,407	14,721
Due to/from affiliates			8,194	12,566
Inventories			54,052	(110,830)	(271,892)	(394,031)	45,991
Prepaid expense and other current assets			(20,203)	(22,995)	(631)	23,686	(42,455)
Accounts payable			50,297	(122,748)	(25,015)	(67,111)	42,236
Accrued expenses			308,047	(342,781)	(37,737)	59,899	214,817
Deferred revenue			8,029	2,947	2,816	(6,539)	(202,777)
Other assets and liabilities			(21,880)	(21,884)	(27,182)	(2,225)	(20,403)
Net cash provided by operations			291,516	257,769	652,403	495,688	311,271
Cash flow from investing activities:
Acquisition of Torrance refinery and related logistics assets			(971,932)	0	(565,304)	0	0
Expenditures for property, plant and equipment			(187,743)	(287,931)	(352,365)	(470,460)	(318,394)
Expenditures for deferred turnaround costs			(138,936)	(39,725)	(53,576)	(137,688)	(64,616)
Expenditures for other assets			(27,735)	(7,275)	(8,236)	(17,255)	(32,692)
Investment in subsidiaries			0	0
Chalmette Acquisition working capital settlement			(2,659)	0
Proceeds from sale of assets			13,030	168,270	168,270	202,654	102,428
Net cash used in investing activities			(1,315,975)	(166,661)	(811,211)	(422,749)	(313,274)
Cash flows from financing activities:
Proceeds from catalyst lease			7,927	0	0	0	14,337
Contributions from PBF LLC related to TVPC			175,000	0
Distribution to Parent			0
Distribution to members			(92,503)	0	(350,658)	(361,352)	(215,846)
Proceeds from intercompany notes payable			635	29,773	347,783	90,631	31,835
Repayments of affiliate notes payable			(517)	0
Proceeds from revolver borrowings			550,000	0	170,000	395,000	1,450,000
Proceeds from members' capital contributions					345,000	328,664	1,757
Proceeds from Issuance of Other Long-term Debt				102,075
Repayments of revolver borrowings			(11,457)	(71,938)	(170,000)	(410,000)	(1,435,000)
Repayments of Debt			(11,457)
Business Combination, Payment of Contingent Consideration				(71,938)	0	0	(21,357)
Proceeds from Rail Facility revolver borrowings			0	102,075	102,075	83,095	0
Repayments of Rail Facility revolver borrowings					(71,938)	(45,825)	0
Proceeds from 2023 Senior Secured Notes					500,000	0	0
Deferred financing costs					(17,108)	(11,719)	(1,044)
Net cash provided by (used in) financing activities			629,085	59,910	855,154	68,494	(175,318)
Net increase (decrease) in cash and cash equivalents			(395,374)	151,018	696,346	141,433	(177,321)
Cash and equivalents, beginning of period			914,749	218,403	218,403	76,970	254,291
Cash and equivalents, end of period	519,375	369,421	519,375	369,421	914,749	218,403	76,970
PBF Holding [Member]
Cash flows from operating activities:
Net income					187,294	21,117
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization					199,383	186,412
Stock-based compensation					9,218	6,095
Change in fair value of catalyst lease obligation					(10,184)	(3,969)
Non-cash lower of cost or market inventory adjustment					427,226	690,110
Non-cash change inventory repurchase obligations					63,389	(93,246)
Pension and other post retirement benefits costs					26,982	22,600
Gain on disposition of property, plant and equipment					(1,004)	(895)
Equity in earnings of subsidiaries					0	0
Changes in current assets and current liabilities:
Accounts receivable					97,636	45,378
Due to/from affiliates					12,104	8,407
Inventories					(271,892)	(394,031)
Prepaid expense and other current assets					(631)	23,686
Accounts payable					(25,015)	(67,111)
Accrued expenses					(37,737)	59,899
Deferred revenue					2,816	(6,539)
Other assets and liabilities					(27,182)	(2,225)
Net cash provided by operations					652,403	495,688
Cash flow from investing activities:
Acquisition of Torrance refinery and related logistics assets					(565,304)
Expenditures for property, plant and equipment					(352,365)	(470,460)
Expenditures for deferred turnaround costs					(53,576)	(137,688)
Expenditures for other assets					(8,236)	(17,255)
Investment in subsidiaries					0	0
Capital Contribution to Subsidiaries					0
Proceeds from sale of assets					168,270	202,654
Net cash used in investing activities					(811,211)	(422,749)
Cash flows from financing activities:
Distribution to members					(350,658)	(361,352)
Proceeds from intercompany notes payable					347,783	90,631
Proceeds from revolver borrowings					170,000	395,000
Proceeds from members' capital contributions					345,000	328,664
Repayments of revolver borrowings					(170,000)	(410,000)
Proceeds from Rail Facility revolver borrowings					102,075	83,095
Repayments of Rail Facility revolver borrowings					(71,938)	(45,825)
Proceeds from 2023 Senior Secured Notes					500,000
Deferred financing costs					(17,108)	(11,719)
Net cash provided by (used in) financing activities					855,154	68,494
Net increase (decrease) in cash and cash equivalents					696,346	141,433
Cash and equivalents, beginning of period			914,749	218,403	218,403	76,970
Cash and equivalents, end of period					914,749	218,403	76,970
Issuer [Member]
Cash flows from operating activities:
Net income	65,072	48,179	148,148	411,803	187,942	21,117	238,876
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization			10,828	13,085	17,063	20,334	19,296
Stock-based compensation			0	0	0	0	0
Change in fair value of catalyst lease obligation			0	0	0	0	0
Deferred income taxes			0
Non-cash lower of cost or market inventory adjustment			(320,833)	(2,091)	279,785	566,412
Non-cash change inventory repurchase obligations			29,317	0	0	0	0
Pension and other post retirement benefits costs			5,249	5,769	7,576	6,426	4,575
Gain on disposition of property, plant and equipment			2,418	(251)	(249)	(277)	(388)
(Gain) loss on sale of assets	2,418	(70)	2,418	(251)	(249)	(277)	(388)
Equity in earnings of subsidiaries	438,249	262,000	1,123,054	793,606	1,154,420	1,131,321	(722,673)
Equity (income) loss in investee	0	0	0	0
Changes in current assets and current liabilities:
Accounts receivable			(205,816)	149,427	87,689	69,887	(281,386)
Due to/from affiliates					(1,018,176)	(1,227,851)	626,623
Due to/from affiliates			(1,624,741)	(729,595)
Inventories			56,792	(34,187)	(108,751)	(259,352)	(153,782)
Prepaid expense and other current assets			(6,330)	(17,976)	2,721	22,287	(40,416)
Accounts payable			37,074	(113,856)	(38,609)	(71,821)	109,988
Accrued expenses			661,974	(206,906)	27,925	(131,903)	222,194
Deferred revenue			6,559	2,947	2,816	(6,539)	7,766
Other assets and liabilities			(7,573)	(3,430)	(423)	(1,966)	(1,140)
Net cash provided by operations			(83,880)	268,345	601,729	138,075	29,533
Cash flow from investing activities:
Acquisition of Torrance refinery and related logistics assets			(971,932)		(601,311)
Expenditures for property, plant and equipment			(16,244)	(188,364)	(193,898)	(152,814)	(127,653)
Expenditures for deferred turnaround costs			0	0	0	0	0
Expenditures for other assets			0	0	0	0	0
Investment in subsidiaries			12,800	5,000	10,000	(44,346)
Capital Contribution to Subsidiaries					(5,000)
Chalmette Acquisition working capital settlement			0
Proceeds from sale of assets			0	60,902	60,902	133,845	102,428
Net cash used in investing activities			(975,376)	(122,462)	(729,307)	(63,315)	(25,225)
Cash flows from financing activities:
Proceeds from catalyst lease			0				0
Contributions from PBF LLC related to TVPC			175,000	0
Distribution to Parent			0
Distribution to members			(92,503)	0	(350,658)	(361,352)	(215,846)
Proceeds from intercompany notes payable			635	29,773	347,783	90,631	31,835
Repayments of affiliate notes payable			(517)
Proceeds from revolver borrowings			550,000		170,000	395,000	1,450,000
Proceeds from members' capital contributions					345,000	328,664	0
Proceeds from Issuance of Other Long-term Debt				0
Repayments of revolver borrowings					(170,000)	(410,000)	(1,435,000)
Repayments of Debt			0
Business Combination, Payment of Contingent Consideration				0			0
Proceeds from Rail Facility revolver borrowings					0	0
Repayments of Rail Facility revolver borrowings					0	0
Proceeds from 2023 Senior Secured Notes					500,000
Deferred financing costs					(17,108)	(8,501)	(1,044)
Net cash provided by (used in) financing activities			632,615	29,773	825,017	34,442	(170,055)
Net increase (decrease) in cash and cash equivalents			(426,641)	175,656	697,439	109,202	(165,747)
Cash and equivalents, beginning of period			882,820	185,381	185,381	76,179	241,926
Cash and equivalents, end of period	456,179	361,037	456,179	361,037	882,820	185,381	76,179
Guarantors Subsidiaries [Member]
Cash flows from operating activities:
Net income	(425,021)	(292,138)	(1,064,415)	(852,587)	(1,228,631)	(1,184,027)	722,673
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization			144,011	130,513	178,601	164,550	98,705
Stock-based compensation			12,658	6,329	9,218	6,095	3,753
Change in fair value of catalyst lease obligation			4,556	(8,982)	(10,184)	(3,969)	(4,691)
Deferred income taxes			0
Non-cash lower of cost or market inventory adjustment			0	83,238	147,441	123,698
Non-cash change inventory repurchase obligations			0	53,370	63,389	(93,246)	(20,492)
Pension and other post retirement benefits costs			20,645	13,571	19,406	16,174	12,153
Gain on disposition of property, plant and equipment			97	(232)	(105)	0	205
(Gain) loss on sale of assets	73	1	97	(232)	(105)	0	205
Equity in earnings of subsidiaries	0	0	0	0	0	0	0
Equity (income) loss in investee	0	0	0	0
Changes in current assets and current liabilities:
Accounts receivable			3,695	7,589	16,124	(17,976)	188,535
Due to/from affiliates					1,133,364	1,328,439	(611,902)
Due to/from affiliates			1,588,690	818,461
Inventories			0	(54,258)	(116,074)	20,711	199,773
Prepaid expense and other current assets			(11,768)	(5,019)	(2,999)	1,399	(2,039)
Accounts payable			16,943	(654)	15,710	(1,697)	(67,752)
Accrued expenses			(353,030)	(27,197)	8,172	471	(7,377)
Deferred revenue			0	0	0	0	(210,543)
Other assets and liabilities			(14,210)	(18,276)	(26,769)	(258)	(19,263)
Net cash provided by operations			347,872	145,866	206,663	360,364	281,738
Cash flow from investing activities:
Acquisition of Torrance refinery and related logistics assets			0		19,042
Expenditures for property, plant and equipment			(172,174)	(99,567)	(158,361)	(205,508)	(190,741)
Expenditures for deferred turnaround costs			(138,936)	(39,725)	(53,576)	(137,688)	(64,616)
Expenditures for other assets			(27,735)	(7,275)	(8,236)	(17,255)	(32,692)
Investment in subsidiaries			0	0	0	0
Capital Contribution to Subsidiaries					0
Chalmette Acquisition working capital settlement			(2,659)
Proceeds from sale of assets			0	0	0	0	0
Net cash used in investing activities			(341,504)	(146,567)	(201,131)	(360,451)	(288,049)
Cash flows from financing activities:
Proceeds from catalyst lease			7,927				14,337
Contributions from PBF LLC related to TVPC			0	0
Distribution to Parent			0
Distribution to members			0	0	0	0	0
Proceeds from intercompany notes payable			0	0	0	0	0
Repayments of affiliate notes payable			0
Proceeds from revolver borrowings			0		0	0	0
Proceeds from members' capital contributions					0	0	1,757
Proceeds from Issuance of Other Long-term Debt				0
Repayments of revolver borrowings					0	0	0
Repayments of Debt			0
Business Combination, Payment of Contingent Consideration				0			(21,357)
Proceeds from Rail Facility revolver borrowings					0	0
Repayments of Rail Facility revolver borrowings					0	0
Proceeds from 2023 Senior Secured Notes					0
Deferred financing costs					0	0	0
Net cash provided by (used in) financing activities			7,927	0	0	0	(5,263)
Net increase (decrease) in cash and cash equivalents			14,295	(701)	5,532	(87)	(11,574)
Cash and equivalents, beginning of period			6,236	704	704	791	12,365
Cash and equivalents, end of period	20,531	3	20,531	3	6,236	704	791
Non-Guarantor Subsidiaries [Member]
Cash flows from operating activities:
Net income	(13,228)	30,138	(58,639)	58,981	73,563	52,706	0
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization			7,726	2,377	3,719	1,528	0
Stock-based compensation			0	0	0	0	0
Change in fair value of catalyst lease obligation			0	0	0	0	0
Deferred income taxes			27,813
Non-cash lower of cost or market inventory adjustment			0	0	0	0
Non-cash change inventory repurchase obligations			0	0			0
Pension and other post retirement benefits costs			0	0	0	0	0
Gain on disposition of property, plant and equipment			8,866	(650)	(650)	(618)	0
(Gain) loss on sale of assets	5,668	(73)	8,866	(650)	(650)	(618)	0
Equity in earnings of subsidiaries	0	0	0	0	0	0	0
Equity (income) loss in investee	(1,621)	0	(1,621)	0
Changes in current assets and current liabilities:
Accounts receivable			7,223	(1,371)	(6,177)	(6,533)	0
Due to/from affiliates					(103,084)	(92,181)	0
Due to/from affiliates			44,245	(76,300)
Inventories			(2,740)	(22,385)	(47,067)	(155,390)	0
Prepaid expense and other current assets			(2,105)	0	(353)	0	0
Accounts payable			(5,126)	(8,404)	(857)	8,423	0
Accrued expenses			(897)	(108,678)	(73,834)	191,331	0
Deferred revenue			1,470	0	0	0	0
Other assets and liabilities			(97)	(178)	10	(1)	0
Net cash provided by operations			26,118	(156,608)	(154,730)	(735)	0
Cash flow from investing activities:
Acquisition of Torrance refinery and related logistics assets			0		16,965
Expenditures for property, plant and equipment			675	0	(106)	(112,138)	0
Expenditures for deferred turnaround costs			0	0	0	0	0
Expenditures for other assets			0	0	0	0	0
Investment in subsidiaries			0	0	0	0
Capital Contribution to Subsidiaries					0
Chalmette Acquisition working capital settlement			0
Proceeds from sale of assets			13,030	107,368	107,368	68,809	0
Net cash used in investing activities			13,705	107,368	124,227	(43,329)	0
Cash flows from financing activities:
Proceeds from catalyst lease			0				0
Contributions from PBF LLC related to TVPC			0	5,000
Distribution to Parent			(12,800)
Distribution to members			0	(10,000)	0	0	0
Proceeds from intercompany notes payable			0	0	0	0	0
Repayments of affiliate notes payable			0
Proceeds from revolver borrowings			0		0	0	0
Proceeds from members' capital contributions					5,000	44,346	0
Proceeds from Issuance of Other Long-term Debt				102,075
Repayments of revolver borrowings					0	0	0
Repayments of Debt			(11,457)
Business Combination, Payment of Contingent Consideration				(71,938)			0
Proceeds from Rail Facility revolver borrowings					102,075	83,095
Repayments of Rail Facility revolver borrowings					(71,938)	(45,825)
Proceeds from 2023 Senior Secured Notes					0
Deferred financing costs					0	(3,218)	0
Net cash provided by (used in) financing activities			(24,257)	25,137	25,137	78,398	0
Net increase (decrease) in cash and cash equivalents			15,566	(24,103)	(5,366)	34,334	0
Cash and equivalents, beginning of period			28,968	34,334	34,334	0	0
Cash and equivalents, end of period	44,534	10,231	44,534	10,231	28,968	34,334	0
Combining and Consolidated Adjustments [Member]
Cash flows from operating activities:
Net income	438,249	262,000	1,123,054	793,606	1,154,420	1,131,321	(722,673)
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization			0	0	0	0	0
Stock-based compensation			0	0	0	0	0
Change in fair value of catalyst lease obligation			0	0	0	0	0
Deferred income taxes			0
Non-cash lower of cost or market inventory adjustment			0	0	0	0
Non-cash change inventory repurchase obligations			0	0			0
Pension and other post retirement benefits costs			0	0	0	0	0
Gain on disposition of property, plant and equipment			0	0	0	0	0
(Gain) loss on sale of assets	0	0	0	0	0	0	0
Equity in earnings of subsidiaries	(438,249)	(262,000)	(1,123,054)	(793,606)	(1,154,420)	(1,131,321)	722,673
Equity (income) loss in investee	0	0	0	0
Changes in current assets and current liabilities:
Accounts receivable			0	0	0	0	0
Due to/from affiliates					0	0	0
Due to/from affiliates			0	0
Inventories			0	0	0	0	0
Prepaid expense and other current assets			0	0	0	0	0
Accounts payable			1,406	166	(1,259)	(2,016)	0
Accrued expenses			0	0	0	0	0
Deferred revenue			0	0	0	0	0
Other assets and liabilities			0	0	0	0	0
Net cash provided by operations			1,406	166	(1,259)	(2,016)	0
Cash flow from investing activities:
Acquisition of Torrance refinery and related logistics assets			0		0
Expenditures for property, plant and equipment			0	0	0	0	0
Expenditures for deferred turnaround costs			0	0	0	0	0
Expenditures for other assets			0	0	0	0	0
Investment in subsidiaries			(12,800)	(5,000)	(10,000)	44,346
Capital Contribution to Subsidiaries					5,000
Chalmette Acquisition working capital settlement			0
Proceeds from sale of assets			0	0	0	0	0
Net cash used in investing activities			(12,800)	(5,000)	(5,000)	44,346	0
Cash flows from financing activities:
Proceeds from catalyst lease			0				0
Contributions from PBF LLC related to TVPC			0	(5,000)
Distribution to Parent			12,800
Distribution to members			0	10,000	0	0	0
Proceeds from intercompany notes payable			0	0	0	0	0
Repayments of affiliate notes payable			0
Proceeds from revolver borrowings			0		0	0	0
Proceeds from members' capital contributions					(5,000)	(44,346)	0
Proceeds from Issuance of Other Long-term Debt				0
Repayments of revolver borrowings					0	0	0
Repayments of Debt			0
Business Combination, Payment of Contingent Consideration				0			0
Proceeds from Rail Facility revolver borrowings					0	0
Repayments of Rail Facility revolver borrowings					0	0
Proceeds from 2023 Senior Secured Notes					0
Deferred financing costs					0	0	0
Net cash provided by (used in) financing activities			12,800	5,000	5,000	(44,346)	0
Net increase (decrease) in cash and cash equivalents			1,406	166	(1,259)	(2,016)	0
Cash and equivalents, beginning of period			(3,275)	(2,016)	(2,016)	0	0
Cash and equivalents, end of period	$ (1,869)	$ (1,850)	$ (1,869)	$ (1,850)	$ (3,275)	$ (2,016)	$ 0