PBF Investments S-4 8 Sep 17 Registration of securities issued in business combination transactions Financial data

Document and Entity Information

Document and Entity Information	6 Months Ended
	Jun. 30, 2017
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	Jun. 30, 2017
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, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 626,705,000	$ 914,749,000
Accounts receivable	615,881,000	454,759,000
Accounts receivable - affiliate	7,631,000	3,438,000
Accounts receivable - affiliate	7,631,000	3,438,000
Affiliate notes receivable	0
Inventories	1,863,560,000	1,174,272,000
Prepaid expense and other current assets	40,536,000	33,701,000
Total current assets	3,154,313,000	2,580,919,000
Property, plant and equipment, net	2,728,699,000	2,211,090,000
Investment in equity method investee	179,882,000	0
Deferred charges and other assets, net	504,003,000	290,713,000
Total assets	6,566,897,000	5,082,722,000
Current liabilities:
Accounts payable	530,365,000	314,843,000
Accounts payable - affiliate	37,863,000	23,949,000
Accounts payable - affiliate	37,863,000	23,949,000
Accrued expenses	1,462,729,000	1,117,435,000
Deferred revenue	12,340,000	4,043,000
Total current liabilities	2,043,297,000	1,460,270,000
Delaware Economic Development Authority loan	0	4,000,000
Long-term debt	1,576,559,000	1,236,720,000
Affiliate notes payable	86,298,000	470,047,000
Deferred tax liabilities	45,699,000	20,577,000
Other long-term liabilities	226,111,000	69,824,000
Total liabilities	3,977,964,000	3,261,438,000
Commitments and contingencies (Note 13)
Equity:
Member's equity	2,155,863,000	1,479,175,000
Retained earnings	446,519,000	349,654,000
Accumulated other comprehensive loss	(25,962,000)	(24,770,000)
Total PBF Holding Company LLC equity	2,576,420,000	1,804,059,000
Noncontrolling interest	12,513,000	17,225,000
Total equity	2,588,933,000	1,821,284,000
Total liabilities and equity	$ 6,566,897,000	$ 5,082,722,000

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Statement [Abstract]
Revenues	$ 5,013,251	$ 3,855,773	$ 9,763,449	$ 6,655,958	$ 15,908,537	$ 13,123,929	$ 19,828,155
Cost, expenses and other
Cost of sales, excluding depreciation	4,662,833	3,284,748	8,914,587	5,730,731	13,765,088	11,611,599	18,514,054
Operating expenses, excluding depreciation	398,570	271,539	835,423	568,178	1,390,582	889,368	880,701
General and administrative expenses	34,920	38,091	75,399	71,360	149,643	166,904	140,150
Equity (income) loss in investee	(3,820)	0	(7,419)	0	(5,679)	0	0
Loss (gain) on sale of assets	29	3,222	912	3,222	11,374	(1,004)	(895)
Depreciation and amortization expense	62,993	48,919	118,683	103,212	209,840	191,110	178,996
Total cost and expenses	5,155,525	3,646,519	9,937,585	6,476,703	15,520,848	12,857,977	19,713,006
Income from operations	(142,274)	209,254	(174,136)	179,255	387,689	265,952	115,149
Other income (expense)
Change in fair value of catalyst lease	1,104	(1,748)	(1,484)	(4,633)	1,422	10,184	3,969
Debt extinguishment costs	(25,451)	0	(25,451)	0
Interest expense, net	(32,857)	(31,279)	(63,513)	(64,550)	(129,536)	(88,194)	(98,001)
Income before income taxes	(199,478)	176,227	(264,584)	110,072	259,575	187,942	21,117
Income tax expense	5,898	(5,277)	6,332	26,996	23,689	648	0
Net income	(205,376)	181,504	(270,916)	83,076	235,886	187,294	21,117
Less income attributable to noncontrolling interests	267	90	380	393	269	274	0
Net income attributable to PBF Holding Company LLC	$ (205,643)	$ 181,414	$ (271,296)	$ 82,683	$ 235,617	$ 187,020	$ 21,117

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Comprehensive Income [Abstract]
Net income	$ (205,376)	$ 181,504	$ (270,916)	$ 83,076	$ 235,886	$ 187,294	$ 21,117
Other comprehensive (loss) income:
Unrealized (loss) gain on available for sale securities	43	99	77	405	(42)	124	127
Net (loss) gain on pension and other post-retirement benefits	287	316	574	632	(2,550)	1,982	(12,465)
Total other comprehensive (loss) income	330	415	651	1,037	(2,592)	2,106	(12,338)
Comprehensive income	(205,046)	181,919	(270,265)	84,113	233,294	189,400	8,779
Less: comprehensive income attributable to noncontrolling interests	267	90	380	393	269	274	0
Comprehensive income attributable to PBF Holding Company LLC	$ (205,313)	$ 181,829	$ (270,645)	$ 83,720	$ 233,025	$ 189,126	$ 8,779

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, 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
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
Net income					$ 274
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]
Member distributions	(139,434)			(139,434)
Member capital contributions	830,247	830,247
Distribution of assets to PBF LLC	(172,743)	(172,743)
Stock based compensation	18,296	18,296
Exercise of options and other	886	886
Net income	235,886
Net income	235,617			235,617
Net income					269
Other comprehensive income	(2,592)		(2,592)
Other	(2,897)	2	1,400	682	(4,981)
Ending balance at Dec. 31, 2016	2,588,933	$ 2,155,863	$ (25,962)	$ 446,519	$ 12,513
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	(270,916)
Net income	(271,296)
Other comprehensive income	651
Ending balance at Jun. 30, 2017	$ 2,504,807

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net income	$ (270,916)	$ 83,076	$ 235,886	$ 187,294	$ 21,117
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization	122,849	107,945	218,933	199,383	186,412
Stock-based compensation	10,134	9,999	18,296	9,218	6,095
Change in fair value of catalyst lease obligation	1,484	4,633	(1,422)	(10,184)	(3,969)
Deferred income taxes	5,123	27,060	19,802	0	0
Non-cash change inventory repurchase obligations	(3,107)	26,172	29,453	63,389	(93,246)
Non-cash lower of cost or market inventory adjustment	167,134	(216,843)	(521,348)	427,226	690,110
Debt extinguishment costs	25,451	0
Pension and other post retirement benefits costs	21,121	15,355	37,987	26,982	22,600
Equity (income) loss in investee	(7,419)	0	(5,679)	0	0
Distributions from equity method investee	12,254	0
Loss (gain) on sale of assets	912	3,222	11,374	(1,004)	(895)
Changes in operating assets and liabilities:
Accounts receivable	6,121	(190,645)	(161,122)	97,636	45,378
Due to/from affiliates	(13,505)	(2,457)
Due to/from affiliates			9,721	12,104	8,407
Inventories	(178,738)	82,579	236,602	(271,892)	(394,031)
Prepaid expense and other current assets	(18,038)	(16,422)	(5,783)	(631)	23,686
Accounts payable	(144,819)	58,642	213,514	(25,015)	(67,111)
Accrued expenses	106,073	164,247	227,986	(37,737)	59,899
Deferred revenue	(7,408)	3,767	8,297	2,816	(6,539)
Other assets and liabilities	(40,525)	(12,522)	(20,878)	(27,182)	(2,225)
Net cash provided by operations	(205,819)	147,808	551,619	652,403	495,688
Cash flows from investing activities:
Expenditures for property, plant and equipment	(179,575)	(110,035)	(282,430)	(352,365)	(470,460)
Expenditures for deferred turnaround costs	(214,375)	(106,649)	(198,664)	(53,576)	(137,688)
Expenditures for other assets	(23,747)	(21,325)	(42,506)	(8,236)	(17,255)
Chalmette Acquisition working capital settlement	0	(2,659)
Proceeds from sale of assets	0	6,860	24,692	168,270	202,654
Net cash used in investing activities	(417,697)	(233,808)	(1,473,499)	(811,211)	(422,749)
Cash flows from financing activities:
Contributions from PBF LLC	97,000	0	450,300		328,664
Contributions from PBF LLC			450,300	345,000	328,664
Distributions to members	(5,252)	(61,667)	(139,434)	(350,658)	(361,352)
Repayments of affiliate notes payable	0	(517)	(53,524)	0	0
Proceeds from affiliate notes payable	0	635	43,396	347,783	90,631
Proceeds from revolver borrowings	290,000	550,000	550,000	170,000	395,000
Repayments of revolver borrowings	(290,000)	0	(200,000)	(170,000)	(410,000)
Proceeds from Rail Facility revolver borrowings			0	102,075	83,095
Repayments of Rail Facility revolver borrowings			(67,491)	(71,938)	(45,825)
Proceeds from 2023 Senior Secured Notes			0	500,000	0
Additional catalyst lease			15,589	0	0
Payment of contingent consideration related to acquisition of Toledo refinery		(6,970)
Deferred financing costs and other	(12,414)	0	0	(17,108)	(11,719)
Net cash provided by financing activities	110,830	481,481	633,836	855,154	68,494
Net (decrease) increase in cash and cash equivalents	(512,686)	395,481	(288,044)	696,346	141,433
Cash and equivalents, beginning of period	626,705	914,749	914,749	218,403	76,970
Cash and equivalents, end of period	114,019	1,310,230	626,705	914,749	218,403
Non-cash activities:
Conversion of affiliate notes payable to capital contribution	86,298		379,947	0	0
Conversion of Delaware Economic Development Authority loan to grant			4,000	4,000	4,000
Distribution of assets to PBF Energy Company LLC	25,547	0
Accrued construction in progress and unpaid fixed assets	127,805	8,149	34,055	7,974	33,296
Distribution of assets to PBF Energy Company LLC			172,743	19,233	126,280
Cash paid during the year for:
Interest (including capitalized interest of $8,333, $3,529 and $7,487 in 2016, 2015 and 2014, respectively)			116,880	83,371	96,346
Income taxes			2,449	0	0
2025 Senior Notes [Member]
Cash flows from financing activities:
Proceeds from 2023 Senior Secured Notes	725,000
Proceeds from 2025 7.25% Senior Notes	725,000	0
2020 Senior Secured Notes [Member]
Cash flows from financing activities:
Repayments of Long-term Debt	(690,209)	0
Rail Term Loan [Member]
Cash flows from financing activities:
Proceeds from 2025 7.25% Senior Notes			35,000	0	0
Repayments of Long-term Debt	(3,295)	0
Rail Facility [Member]
Cash flows from financing activities:
Proceeds from revolver borrowings					83,095
Repayments of revolver borrowings	$ 0	$ (6,970)			(45,825)
Torrance Refinery [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired			(971,932)	0	0
Chalmette Refinery [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired			$ (2,659)	$ (565,304)	$ 0

Consolidated Statements of Cas7

Consolidated Statements of Cash Flows (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Statement of Cash Flows [Abstract]
Capitalized interest	$ 8,333	$ 3,529	$ 7,487

DESCRIPTION OF THE BUSINESS AND

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION	6 Months Ended
	Jun. 30, 2017
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 96.5% of the outstanding economic interest, in PBF LLC as of December 31, 2016 . PBF Investments LLC ("PBF Investments"), Toledo Refining Company LLC ("Toledo Refining" or "TRC"), Paulsboro Refining Company LLC ("Paulsboro Refining" or "PRC"), Delaware City Refining Company LLC (“Delaware City Refining” or “DCR”), Chalmette Refining, L.L.C. (“Chalmette Refining”), PBF Western Region LLC (“PBF Western Region”), Torrance Refining Company LLC ("Torrance Refining") and Torrance Logistics Company LLC are PBF LLC's principal operating subsidiaries and are all wholly-owned subsidiaries of PBF Holding. Collectively, PBF Holding and its consolidated subsidiaries are referred to hereinafter as the “Company”. 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. PBF Holding and PBF LLC entered into additional transactions with PBFX since the PBFX Offering as described in "Note 12 - Related Party Transactions”). Substantially all of the Company’s operations are in the United States. 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. 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 96.6% of the outstanding economic interest in, PBF LLC as of June 30, 2017 . PBF Investments LLC (“PBF Investments”), Toledo Refining Company LLC (“Toledo Refining” or “TRC”), Paulsboro Refining Company LLC (“Paulsboro Refining” or “PRC”), Delaware City Refining Company LLC (“Delaware City Refining” or “DCR”), Chalmette Refining, L.L.C. (“Chalmette Refining”), PBF Western Region LLC (“PBF Western Region”), Torrance Refining Company LLC (“Torrance Refining”) and Torrance Logistics Company LLC are PBF LLC’s principal operating subsidiaries and are all wholly-owned subsidiaries of PBF Holding. Collectively, PBF Holding and its consolidated subsidiaries are referred to hereinafter as the “Company”. On May 14, 2014, PBF Logistics LP (“PBFX”), a Delaware master limited partnership, completed its initial public offering (the “PBFX Offering”). PBF Logistics GP LLC (“PBF GP”) serves as the general partner of PBFX. PBF GP is wholly-owned by PBF LLC. In connection with the PBFX Offering, PBF Holding contributed to PBFX the assets and liabilities of certain crude oil terminaling assets. In a series of additional transactions subsequent to the PBFX Offering, PBF Holding distributed certain additional assets to PBF LLC, which in turn contributed those assets to PBFX (as described in “Note 8 - Related Party Transactions”). Substantially all of the Company’s operations are in the United States. As of June 30, 2017 , 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, 2016 of PBF Holding Company LLC and PBF Finance Corporation. The results of operations for the three and six months ended June 30, 2017 are not necessarily indicative of the results to be expected for the full year. Cost Classifications Cost of products and other consists of the cost of crude oil, other feedstocks, blendstocks and purchased refined products and the related in-bound freight and transportation costs. Operating expenses (excluding depreciation) consists of direct costs of labor, maintenance and services, utilities, property taxes, environmental compliance costs and other direct operating costs incurred in connection with our refining operations. Such expenses exclude depreciation related to refining and logistics assets that are integral to the refinery production process, which is presented as a component of Depreciation and amortization expense on our Condensed Consolidated Statement of Operations. Reclassification Certain amounts previously reported in the Company's condensed consolidated financial statements for prior periods have been reclassified to conform to the 2017 presentation. These reclassifications include certain details about accrued expenses in that footnote. Recently Adopted Accounting Guidance Effective January 1, 2017, the Company adopted Accounting Standard Update (“ASU”) No. 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments (a consensus of the FASB Emerging Issues Task Force)” (“ASU 2016-06”). ASU 2016-6 was issued in March 2016 by the Financial Accounting Standards Board (“FASB”) 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 Company’s adoption of this guidance did not materially impact its consolidated financial statements. Effective January 1, 2017, the Company adopted ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”). ASU 2016-09 was issued by the FASB in March 2016 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 could prior to its adoption for tax withholding purposes without triggering liability accounting and to make a policy election to account for forfeitures as they occur. The Company’s adoption of this guidance did not materially impact its consolidated financial statements. Effective January 1, 2017, the Company adopted ASU No. 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control” (“ASU 2016-17”). ASU 2016-17 was issued by the FASB in October 2016 to amend 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 a reporting entity, in determining whether it satisfies the second characteristic of a primary beneficiary, 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. The Company’s adoption of this guidance did not materially impact its consolidated financial statements. In January 2017, the FASB issued ASU No. 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business” (“ASU 2017-01”), which provides guidance to assist entities with evaluating when a set of transferred assets and activities is a business. Under ASU 2017-01, it is expected that the definition of a business will be narrowed and more consistently applied. ASU 2017-01 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods. The amendments in this ASU should be applied prospectively on or after the effective date. Early adoption of ASU 2017-01 is permitted and the Company early adopted the new standard in its consolidated financial statements and related disclosures effective January 1, 2017. The Company’s adoption of this guidance did not materially impact its consolidated financial statements. Recent Accounting Pronouncements 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. 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 modified retrospective 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 has established a working group to assess the Updated Revenue Recognition Guidance, including its impact on the Company’s business processes, accounting systems, controls and financial statement disclosures. The Company’s preliminary expectation is that it will adopt this guidance using the modified retrospective method whereby a cumulative effect adjustment is recognized upon adoption and the Updated Revenue Recognition Guidance is applied prospectively. The Company will not early adopt this new guidance. The working group is progressing through its implementation plan and continues to evaluate the impact of this new standard on the Company’s consolidated financial statements and related disclosures. Although the Company’s analysis of the new standard is still in process and interpretative and industry specific guidance is still developing, the Company currently does not expect the new standard to have a material impact on the amount or timing of revenues recognized for the majority of its revenue arrangements. However, it is expected that the new standard will have some impact on presentation and disclosures in its financial statements. 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 has established a working group to study and lead implementation of the new guidance in ASU 2016-02. This working group was formed during 2016 and has begun the process of compiling a central repository for all leases entered into by the Company and its subsidiaries for further analysis as the implementation project progresses. It is not anticipated that the Company will early adopt this new guidance. The working group continues to evaluate the impact of this new standard on its consolidated financial statements and related disclosures. At this time, the Company has identified that the most significant impacts of this new guidance will be to bring nearly all leases on its balance sheet with “right of use assets” and “lease obligation liabilities” as well as accelerating the interest expense component of financing leases. While the assessment of the impacts arising from this standard is progressing, it remains in its early stages. Accordingly, the Company has not fully determined the impacts on its business processes, controls or financial statement disclosures. In March 2017, the FASB issued ASU No. 2017-07, “Compensation—Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” (“ASU 2017-07”), which provides guidance to improve the reporting of net benefit cost in the income statement and on the components eligible for capitalization in assets. Under the new guidance, employers will present the service cost component of net periodic benefit cost in the same income statement line item(s) as other employee compensation costs arising from services rendered during the period. Only the service cost component will be eligible for capitalization in assets. Additionally, under this guidance, employers will present the other components of the net periodic benefit cost separately from the line item(s) that includes the service cost and outside of any subtotal of operating income, if one is presented. These components will not be eligible for capitalization in assets. Employers will apply the guidance on the presentation of the components of net periodic benefit cost in the income statement retrospectively. The guidance limiting the capitalization of net periodic benefit cost in assets to the service cost component will be applied prospectively. The guidance includes a practical expedient allowing entities to estimate amounts for comparative periods using the information previously disclosed in their pension and other postretirement benefit plan note to the financial statements. The amendments in this ASU are effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In May 2017, the FASB issued ASU No. 2017-09, “Compensation—Stock Compensation (Topic 718): Scope of Modification Accounting” (“ASU 2017-09”), which provides guidance to increase clarity and reduce both diversity in practice and cost and complexity when applying the existing accounting guidance on changes to the terms or conditions of a share-based payment award. The amendments in ASU 2017-09 require an entity to account for the effects of a modification unless all the following are met: (i) the fair value of the modified award is the same as the fair value of the original award immediately before the original award is modified; (ii) the vesting conditions of the modified award are the same as the vesting conditions of the original award immediately before the original award is modified; and (iii) the classification of the modified award as an equity instrument or a liability instrument is the same as the classification of the original award immediately before the original award is modified. The guidance in ASU 2017-09 should be applied prospectively. The amendments in this ASU are effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. The Company will apply the guidance prospectively for any modifications to its stock compensation plans occurring after the effective date of the new standard.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	6 Months Ended
	Jun. 30, 2017
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 2016 presentation. These reclassifications include certain details about accrued expenses and deferred charges and other assets in those respective footnotes. Use of Estimates The preparation of the financial statements in conformity with accounting principles generally accepted in the United States ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures. Actual results could differ from those estimates. 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 years ended December 31, 2016, 2015 and 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, 2016 . Following the Chalmette Acquisition on November 1, 2015, ExxonMobil Oil Corporation and its affiliates represented approximately 18% of our total trade accounts receivable as of December 31, 2015. 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 product 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. On May 29, 2015, PBF Holding entered into amended and restated inventory intermediation agreements (the "A&R Intermediation Agreements") with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. ("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. These purchases and sales are settled monthly at the daily market prices related to those products. These transactions are considered to be made in contemplation of each other and, accordingly, do not result in the recognition of a sale when title passes from the refineries to J. Aron. Additionally, 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. 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, 2016 and 2015 . 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 Morgan Stanley Capital Group, Inc. ("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. Investments in Equity Method Investments For equity investments that are not required to be consolidated under the variable or voting interest model, the Company evaluates the level of influence it is able to exercise over an entity’s operations to determine whether to use the equity method of accounting.The Company's judgment regarding the level of control over an equity method investment includes considering key factors such as its ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Amounts recognized for equity method investments are included in equity method investments in the consolidated balance sheet and adjusted for the Company's shares of the net earnings and losses of the investee and cash distributions, which are included in the consolidated statements of operations and the consolidated statements of cash flows. Amounts recognized for earnings in excess of distributions of the Company's equity method investments are included in the operating section of the consolidated statements of cash flows. The Company evaluates its equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. A loss is recorded in earnings in the current period to write down the carrying value of the investment to fair value if a decline in the value of an equity method investment is determined to be other than temporary. Asset Retirement Obligations The Company records an asset retirement obligation at fair value for the estimated cost to retire a tangible long-lived asset at the time the Company incurs that liability, which is generally when the asset is purchased, constructed, or leased. The Company records the liability when it has a legal or contractual obligation to incur costs to retire the asset and when a reasonable estimate of the fair value of the liability can be made. If a reasonable estimate cannot be made at the time the liability is incurred, the Company will record the liability when sufficient information is available to estimate the liability’s fair value. Certain of the Company’s asset retirement obligations are based on its legal obligation to perform remedial activity at its refinery sites when it permanently ceases operations of the long-lived assets. The Company therefore considers the settlement date of these obligations to be indeterminable. Accordingly, the Company cannot calculate an associated asset retirement liability for these obligations at this time. The Company will measure and recognize the fair value of these asset retirement obligations when the settlement date is determinable. Environmental Matters Liabilities for future remediation costs are recorded when environmental assessments and/or remedial efforts are probable and the costs can be reasonably estimated. Other than for assessments, the timing and magnitude of these accruals generally are based on the completion of investigations or other studies or a commitment to a formal plan of action. Environmental liabilities are based on best estimates of probable future costs using currently available technology and applying current regulations, as well as the Company’s own internal environmental policies. The measurement of environmental remediation liabilities may be discounted to reflect the time value of money if the aggregate amount and timing of cash payments of the liabilities are fixed or reliably determinable. The actual settlement of the Company’s liability for environmental matters could materially differ from its estimates due to a number of uncertainties such as the extent of contamination, changes in environmental laws and regulations, potential improvements in remediation technologies and the participation of other responsible parties. Stock-Based Compensation Stock-based compensation includes the accounting effect of options to purchase PBF Energy Class A common stock granted by PBF Energy to certain PBF Holding employees, Series A warrants issued or granted by PBF LLC to employees in connection with their acquisition of PBF LLC Series A units, options to acquire Series A units of PBF LLC granted by PBF LLC to certain employees, Series B units of PBF LLC that were granted to certain members of management and restricted PBF LLC Series A Units and restricted PBF Energy Class A common stock granted to certain directors and officers. The estimated fair value of the options to purchase PBF Energy Class A common stock and the PBF LLC Series A warrants and options, is based on the Black-Scholes option pricing model and the fair value of the PBF LLC Series B units is estimated based on a Monte Carlo simulation model. The estimated fair value is amortized as stock-based compensation expense on a straight-line method over the vesting period and included in general and administration expense with forfeitures recognized in the period they occur. 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 tax returns for all years since 2013 and state tax returns for all years since 2012 or 2013 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 Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update 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 has adopted this guidance retrospectively. The adoption of this guidance did not have any impact on the Company as it does not have any variable interest entities that would be affected by this ASU. In August 2015, the FASB issued Accounting Standards Update 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. 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 modified retrospective 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 has established a working group to assess the Updated Revenue Recognition Guidance, including its impact on our business processes, accounting systems, controls and financial statement disclosures. Our preliminary expectation is that we will adopt this guidance using the modified retrospective method whereby a cumulative effect adjustment is recognized upon adoption and the Updated Revenue Recognition is applied prospectively. It is not anticipated that the Company will early adopt this new guidance. The working group is in the early stages of its implementation plan and continues to evaluate the impact of this new standard on the Company’s consolidated financial statements and related disclosures. Although our analysis of the new standard is still in process and interpretative and industry specific guidance is still developing, the Company currently does not expect the new standard to have a material impact on the amount or timing of revenues recognized for the majority of its revenue arrangements. 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 early adopted the new standard in its consolidated financial statements and related disclosures on a prospective basis. The Company did not have any current deferred tax assets or liabilities in the prior year to reclassify from current to non-current. 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 US 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 has established a working group to study and lead implementation of the new guidance in ASU 2016-02. This working group was formed during 2016 and has begun the process of compiling a central repository for all leases entered into by the Company and its subsidiaries for further analysis as the implementation project progresses. It is not anticipated that the Company will early adopt this new guidance. The working group continues to evaluate the impact of this new standard on its consolidated financial statements and related disclosures. At this time, the Company has identified that the most significant impacts of this new guidance will be to bring nearly all leases on its balance sheet with “right of use assets” and “lease obligation liabilities” as well as accelerating the interest expense component of financing leases. 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

ACQUISITIONS

ACQUISITIONS	6 Months Ended
	Jun. 30, 2017
Business Combinations [Abstract]
ACQUISITIONS	ACQUISITIONS 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 provided the Company with a broader more diversified asset base and increased the number of operating refineries from four to five and expanded the Company’s combined crude oil throughput capacity. The acquisition also provided the Company with a presence in the PADD 5 market. In addition to refining assets, the transaction included 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 were 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 after post-closing purchase price adjustments, plus final 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 certain PBF Energy equity offerings and borrowings under the Company’s asset based revolving credit agreement (the “Revolving Loan”). The Company accounted for the Torrance Acquisition as a business combination under GAAP whereby the Company recognizes assets acquired and liabilities assumed in an acquisition at their estimated fair values as of the date of acquisition. The final purchase price and fair value allocation were completed as of June 30, 2017. During the measurement period, which ended in June 2017, adjustments were made to the Company’s preliminary fair value estimates related primarily to Property, plant and equipment and Other long-term liabilities reflecting the finalization of the Company’s assessment of the costs and duration of certain assumed pre-existing environmental obligations. The total purchase consideration and the fair values of the assets and liabilities at the acquisition date 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 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 982 Property, plant and equipment 704,633 Deferred charges and other assets, net 68,053 Accounts payable (2,688 ) Accrued expenses (64,137 ) Other long-term liabilities (139,453 ) Fair value of net assets acquired $ 971,932 The Company’s condensed consolidated financial statements for the six months ended June 30, 2017 include the results of operations of the Torrance refinery and related logistics assets subsequent to the Torrance Acquisition whereas the same period in 2016 does not include the results of operations of such assets. 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. Six Months Ended June 30, 2016 Pro forma revenues $ 7,734,969 Pro forma net loss attributable to PBF Holding Company LLC $ (121,369 ) The unaudited amount of revenues and net loss 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. 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”). While the Company’s condensed consolidated financial statements for both the three and six months ended June 30, 2017 and 2016 include the results of operations of Chalmette Refining, the final working capital settlement for the Chalmette Acquisition was finalized in the first quarter of 2016. Additionally, certain acquisition related costs for the Chalmette Acquisition were recorded in the first quarter of 2016. Acquisition Expenses The Company incurred acquisition related costs consisting primarily of consulting and legal expenses related to completed, pending and non-consummated acquisitions of $94 and $466 in the three and six months ended June 30, 2017 , respectively. In the three and six months ended June 30, 2016 , the Company incurred acquisition related costs of $2,410 and $7,134 respectively. These costs are included in the condensed consolidated statements of operations in General and administrative expenses.
ACQUISITIONS	ACQUISITIONS 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 expands the Company's combined crude oil throughput capacity. The acquisition also provides the Company with a presence in the 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 after post-closing purchase price adjustments, plus final 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 the 2023 Senior Secured Notes Offering and borrowings under the asset based revolving credit agreement (the "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 final purchase valuation was in process as of December 31, 2016 as the purchase price and fair value allocation may be subject to adjustment pending completion of our assessment of the estimated costs and duration of certain assumed pre-existing environmental obligations. 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 703,443 Deferred charges and other assets, net 68,053 Accounts payable (2,688 ) Accrued expenses (64,137 ) Other long-term liabilities (138,467 ) Fair value of net assets acquired $ 971,932 The Company’s condensed consolidated financial statements for the year ended December 31, 2016 , include the results of operations of the Torrance refinery and related logistics assets since July 1, 2016 during which period the Torrance refinery and related logistics assets contributed revenues of $1,977,204 and net income of $86,394 . 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 related financing. Years ended December 31, (Unaudited) 2016 2015 Pro forma revenues $ 16,987,548 $ 16,252,729 Pro forma net income (loss) attributable to PBF Holding Company LLC $ 31,565 $ (176,410 ) 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. 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 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 Revolving Loan. 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 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 interest (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 interest of $5,144 . The Company’s condensed consolidated financial statements for the year ended December 31, 2016 include the results of operations of the Chalmette refinery for the full year. 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. Year ended December 31, (Unaudited) 2015 Pro forma revenues $ 16,811,922 Pro forma net income attributable to PBF Holding Company LLC 397,108 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. 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 $13,622 and $5,833 in the years ended December 31, 2016 and 2015 , respectively. These costs are included in the consolidated income statement in General and administrative expenses.

INVENTORIES

INVENTORIES	6 Months Ended
	Jun. 30, 2017
Inventory Disclosure [Abstract]
INVENTORIES	INVENTORIES Inventories consisted of the following: December 31, 2016 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 1,102,007 $ — $ 1,102,007 Refined products and blendstocks 915,397 352,464 1,267,861 Warehouse stock and other 89,680 — 89,680 $ 2,107,084 $ 352,464 $ 2,459,548 Lower of cost or market adjustment (492,415 ) (103,573 ) (595,988 ) Total inventories $ 1,614,669 $ 248,891 $ 1,863,560 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 adjustment (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 year ended December 31, 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 $521,348 reflecting the net change in the lower of cost or market inventory reserve from $1,117,336 at December 31, 2015 to $595,988 at December 31, 2016 . 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 . An actual valuation of inventories valued under the LIFO method is made at the end of each year based on inventory levels and costs at that time. We recorded a charge related to a LIFO layer decrement of $11,746 during the year ended December 31, 2016 . No such LIFO decrement was recorded in the year ended December 31, 2015 . INVENTORIES Inventories consisted of the following: June 30, 2017 Titled Inventory Inventory Intermediation Arrangements Total Crude oil and feedstocks $ 1,307,816 $ — $ 1,307,816 Refined products and blendstocks 935,041 300,939 1,235,980 Warehouse stock and other 94,490 — 94,490 $ 2,337,347 $ 300,939 $ 2,638,286 Lower of cost or market adjustment (650,702 ) (112,420 ) (763,122 ) Total inventories $ 1,686,645 $ 188,519 $ 1,875,164 December 31, 2016 Titled Inventory Inventory Intermediation Arrangements Total Crude oil and feedstocks $ 1,102,007 $ — $ 1,102,007 Refined products and blendstocks 915,397 352,464 1,267,861 Warehouse stock and other 89,680 — 89,680 $ 2,107,084 $ 352,464 $ 2,459,548 Lower of cost or market adjustment (492,415 ) (103,573 ) (595,988 ) Total inventories $ 1,614,669 $ 248,891 $ 1,863,560 Inventory under inventory intermediation arrangements included certain light finished products sold to counterparties and stored in the Paulsboro and Delaware City refineries’ storage facilities in connection with the amended and restated inventory intermediation agreements (as amended in the second quarter of 2017, the “A&R Intermediation Agreements”) with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. (“J. Aron”). During the three months ended June 30, 2017 , the Company recorded an adjustment to value its inventories to the lower of cost or market (“LCM”) which decreased both operating income and net income by $151,095 reflecting the net change in the lower of cost or market inventory reserve from $612,027 at March 31, 2017 to $763,122 at June 30, 2017 . During the six months ended June 30, 2017 , 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 $167,134 reflecting the net change in the lower of cost or market inventory reserve from $595,988 at December 31, 2016 to $763,122 at June 30, 2017 . During the three months ended June 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 $157,780 reflecting the net change in the lower of cost or market inventory reserve from $1,058,273 at March 31, 2016 to $900,493 at June 30, 2016 . During the six months ended June 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 $216,843 reflecting the net change in the lower of cost or market inventory reserve from $1,117,336 at December 31, 2015 to $900,493 at June 30, 2016 .

PROPERTY, PLANT AND EQUIPMENT,

PROPERTY, PLANT AND EQUIPMENT, NET	6 Months Ended
	Jun. 30, 2017
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 $ 253,110 $ 91,256 Process units, pipelines and equipment 2,504,008 2,209,712 Buildings and leasehold improvements 49,020 34,265 Computers, furniture and fixtures 81,780 72,642 Construction in progress 289,338 150,388 3,177,256 2,558,263 Less—Accumulated depreciation (448,557 ) (347,173 ) $ 2,728,699 $ 2,211,090 Depreciation expense for the years ended December 31, 2016 , 2015 and 2014 was $104,293 , $88,474 and $113,533 , respectively. The Company capitalized $8,333 and $3,529 in interest during 2016 and 2015 , 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	6 Months Ended
	Jun. 30, 2017
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: December 31, December 31, 2015 Deferred turnaround costs, net $ 302,919 $ 177,236 Catalyst 114,788 77,725 Linefill 19,485 13,504 Restricted cash — 1,500 Environmental credits 51,636 10,829 Intangible assets, net 577 219 Other 14,598 9,700 $ 504,003 $ 290,713 The Company recorded amortization expense related to deferred turnaround costs, catalyst and intangible assets of $105,547 , $102,636 and $65,452 for the years ended December 31, 2016 , 2015 and 2014 respectively. The restricted cash consisted 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, 2015 Gross amount $ 3,996 $ 3,597 Accumulated amortization (3,419 ) (3,378 ) Net amount $ 577 $ 219

ACCRUED EXPENSES

ACCRUED EXPENSES	6 Months Ended
	Jun. 30, 2017
Payables and Accruals [Abstract]
ACCRUED EXPENSES	ACCRUED EXPENSES Accrued expenses consisted of the following: December 31, December 31, 2015 Inventory-related accruals $ 810,027 $ 548,800 Inventory intermediation arrangements 225,524 252,380 Accrued transportation costs 89,830 91,546 Excise and sales tax payable 86,046 34,129 Renewable energy credit and emissions obligations 70,158 19,472 Accrued utilities 44,190 25,192 Accrued interest 28,934 22,313 Accrued construction in progress 33,610 7,400 Accrued salaries and benefits 17,466 61,011 Customer deposits 9,215 20,395 Environmental liabilities 8,882 2,178 Other 38,847 32,619 Total accrued expenses $ 1,462,729 $ 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. As of December 31, 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 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. In addition, the Company is subject to obligations to comply with federal and state legislative and regulatory measures to address environmental compliance and greenhouse gas and other emissions, including AB 32 in California. These requirements include incremental costs to operate and maintain our facilities as well as to implement and manage new emission controls and programs, which have contributed to the increase in accrued environmental liabilities and emission obligations following the Torrance Acquisition. ACCRUED EXPENSES Accrued expenses consisted of the following: June 30, December 31, Inventory-related accruals $ 778,746 $ 810,027 Inventory intermediation arrangements 233,455 225,524 Renewable energy credit and emissions obligations 172,331 70,158 Excise and sales tax payable 100,998 86,046 Accrued transportation costs 83,312 89,830 Accrued capital expenditures 75,711 33,610 Accrued refinery maintenance and support costs 32,326 28,670 Accrued utilities 28,914 44,190 Customer deposits 23,912 9,215 Accrued salaries and benefits 15,961 17,466 Accrued interest 9,047 28,934 Environmental liabilities 8,902 8,882 Other 30,685 10,177 Total accrued expenses $ 1,594,300 $ 1,462,729 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 June 30, 2017 and December 31, 2016 , a liability is recognized for the inventory 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 products and other. 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. In addition, the Company is subject to obligations to comply with federal and state legislative and regulatory measures to address environmental compliance and greenhouse gas and other emissions, including AB32 in California. These requirements include incremental costs to operate and maintain our facilities as well as to implement and manage new emission controls and programs, which have contributed to the increase in accrued environmental liabilities and emission obligations following the Torrance Acquisition. Renewable energy credit and emissions obligations fluctuate with the volume of applicable product sales and timing of credit purchases.

LONG-TERM DEBT (Notes)

LONG-TERM DEBT (Notes)	6 Months Ended
	Jun. 30, 2017
Long-term Debt, Unclassified [Abstract]
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 the 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. The LC Participation Fee ranges from 1.25% to 2.0% depending on the Company's senior secured 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 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 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 senior secured 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 contains customary covenants and restrictions on the activities of PBF Holding and its subsidiaries, including, but not limited to, limitations on the incurrence of additional indebtedness; liens, negative pledges, guarantees, investments, loans, asset sales, mergers, acquisitions and prepayment of other debt; distributions, dividends and the repurchase of capital stock; transactions with affiliates; the ability to change the nature of our business or our fiscal year; the ability to amend the terms of the Senior Secured Notes facility documents; and sale and leaseback transactions. In addition, 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. The outstanding borrowings under the Revolving Loan as of December 31, 2016 was $350,000 . There were no outstanding borrowings under the Revolving Loan as of December 31, 2015 . Standby letters of credit were $411,997 and $351,511 , as of December 31, 2016 and December 31, 2015, 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 as Administrative Agent. The primary purpose of the Rail Facility was 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 before December 2015. The Rail was amended on two occasions in 2015 and 2016. On December 22, 2016, the Rail Facility was repaid in full and terminated in connection with the issuance of the PBF Rail Term Loan (defined below). There was no amount outstanding under the Rail Facility at December 31, 2016 . There was $67,491 outstanding under the Rail Facility at December 31, 2015 . PBF Rail Term Loan On December 22, 2016, PBF Rail entered into a $35,000 term loan (the “PBF Rail Term Loan”) with DVB Bank SE (“DVB”). The PBF Rail Term Loan amortizes monthly over its five year term and bears interest at the one month LIBOR plus 2.0% . As security for the PBF Rail Term Loan, PBF Rail pledged, among other things: (i) certain eligible railcars; (ii) the Debt Service Reserve Account; and (iii) PBF Holding's membership interest in PBF Rail. Additionally, the PBF Rail Term Loan contains customary terms, events of default and covenants for transactions of this nature. PBF Rail may at any time repay the PBF Rail Term Loan without penalty in the event that railcars collateralizing the loan are sold, scrapped or otherwise removed from the collateral pool. As of December 31, 2016 , there was $35,000 outstanding under the PBF Rail Term Loan. Senior Secured Notes On February 9, 2012, PBF Holding and PBF Holding's wholly-owned subsidiary, PBF Finance Corporation, 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 used the proceeds for general corporate purposes, including to fund a portion of the purchase price for the acquisition of the Torrance refinery and related logistics assets. The 2023 Senior Secured Notes included a registration payment arrangement whereby the Company agreed to use commercially reasonable efforts to consummate an offer to exchange the 2023 Senior Secured Notes for an issue of registered notes with terms substantially identical to the notes not later than 365 days after the date of the original issuance of the notes. This registration statement was declared effective on December 1, 2016 and the exchange was consummated on January 19, 2017. As the exchange offer was not consummated by November 24, 2016, additional interest was added at a rate of 0.25% per annum for the period from November 24, 2016 through the consummation of the exchange. As a result, the Company recognized approximately $127 of additional interest expense in 2016. 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 customary terms, events of default and covenants for an issuer of non-investment grade debt securities including limitations on PBF Holding's and its restricted subsidiaries’ ability to, among other things, incur additional indebtedness or issue certain preferred stock; make equity distributions, pay dividends on or repurchase capital stock or make other restricted payments; enter into transactions with affiliates; create liens; engage in mergers and consolidations or otherwise sell all or substantially all of our assets; designate subsidiaries as unrestricted subsidiaries; make certain investments; and limit the ability of restricted subsidiaries to make payments to PBF Holding. 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 Certain subsidiaries of the Company have entered into agreements whereby such subsidiary sold a portion of its precious metals catalyst to a major commercial bank and then leased the catalyst back. The volume of the precious metals catalyst and the lease rate are fixed over the term of each lease, which is generally three years. At the maturity of each lease, the Company must repurchase the precious metals catalyst in question at its then fair market value. The Company believes that there is a substantial market for precious metals catalyst leases and that it will be able to release such catalyst at maturity. 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 the Company's refineries as of December 31, 2016 are included in the following table: Annual lease fee Annual interest rate Expiration date Paulsboro catalyst lease $ 140 2.20 % December 2019 Delaware City catalyst lease $ 210 1.95 % October 2019 Delaware City catalyst lease - Palladium $ 30 2.05 % October 2019 Toledo catalyst lease $ 331 1.99 % June 2017* Chalmette catalyst lease $ 185 3.85 % November 2018 Chalmette catalyst lease $ 171 2.20 % November 2019 Torrance catalyst lease $ 143 1.78 % July 2019 * The Toledo catalyst lease is included in long-term debt as of December 31, 2016 as the Company has the ability and intent to finance this debt through availability under other credit facilities if the catalyst lease is not renewed at maturity. Long-term debt outstanding consisted of the following: December 31, 2016 December 31, 2015 2020 Senior Secured Notes $ 670,867 $ 669,644 2023 Senior Secured Notes 500,000 500,000 Revolving Loan 350,000 — PBF Rail Term Loan 35,000 — Rail Facility — 67,491 Catalyst leases 45,969 31,802 Unamortized deferred financing costs (25,277 ) (32,217 ) 1,576,559 1,236,720 Less—Current maturities — — Long-term debt $ 1,576,559 $ 1,236,720 Debt Maturities Debt maturing in the next five years and thereafter is as follows: Year Ending December 31, 2017 $ 9,798 2018 4,941 2019 381,230 2020 670,867 2021 35,000 Thereafter 500,000 $ 1,601,836 LONG-TERM DEBT Senior Notes On May 30, 2017, PBF Holding entered into an Indenture (the “Indenture”) among PBF Holding and PBF Holding’s wholly-owned subsidiary, PBF Finance Corporation (“PBF Finance” and, together with PBF Holding, the “Issuers”), the guarantors named therein (collectively the “Guarantors”) and Wilmington Trust, National Association, as Trustee, under which the Issuers issued $725,000 in aggregate principal amount of 7.25% senior notes due 2025 (the “2025 Senior Notes”). The Issuers received net proceeds of approximately $712,586 from the offering after deducting the initial purchasers’ discount and estimated offering expenses. The Company used the net proceeds to fund the cash tender offer (the “Tender Offer”) for any and all of its outstanding 8.25% senior secured notes due 2020 (the “2020 Senior Secured Notes”), to pay the related redemption price and accrued and unpaid interest for any 2020 Senior Secured Notes that remained outstanding after the completion of the Tender Offer, and for general corporate purposes. The difference between the carrying value of the 2020 Senior Secured Notes on the date they were reacquired and the amount for which they were reacquired has been classified as debt extinguishment costs in the condensed consolidated statement of operations. The 2025 Senior 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, a registration statement relating to an offer to exchange the 2025 Senior Notes for an issue of registered notes with terms substantially identical to the notes. The Issuers will be obligated to pay additional interest if they fail to comply with their obligations to register the 2025 Senior Notes within the specified time period. The Company fully intends to file a registration statement for the exchange of the 2025 Senior Notes within the 365 day period following the closing of the 2025 Senior Notes. In addition, there are no restrictions or hindrances that the Company is aware of that would prohibit the Issuers 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 2025 Senior Notes are guaranteed on a senior unsecured basis by substantially all of PBF Holding’s subsidiaries. The 2025 Senior Notes and guarantees are senior unsecured obligations and rank equal in right of payment with all of the Issuers’ and the Guarantors’ existing and future senior indebtedness, including PBF Holding’s Revolving Loan and the Issuers’ 7.00% senior notes due 2023 (the “2023 Senior Notes”). The 2025 Senior Notes and the guarantees rank senior in right of payment to the Issuers’ and the Guarantors’ existing and future indebtedness that is expressly subordinated in right of payment thereto. The 2025 Senior Notes and the guarantees are effectively subordinated to any of the Issuers’ and the Guarantors’ existing or future secured indebtedness (including the Revolving Loan) to the extent of the value of the collateral securing such indebtedness. The 2025 Senior Notes and the guarantees are structurally subordinated to any existing or future indebtedness and other obligations of the Issuers’ non-guarantor subsidiaries. PBF Holding has optional redemption rights to repurchase all or a portion of the 2025 Senior Notes at varying prices no less than 100% of the principal amounts of the notes plus accrued and unpaid interest. The holders of the 2025 Senior Notes have repurchase options exercisable only upon a change in control, certain asset sale transactions, or in event of a default as defined in the Indenture. In addition, the 2025 Senior Notes contain customary terms, events of default and covenants for an issuer of non-investment grade debt securities that limit certain types of additional debt, equity issuances, and payments. Many of these covenants will cease to apply or will be modified if the 2025 Senior Notes are rated investment grade. Upon the satisfaction and discharge of the 2020 Senior Secured Notes in connection with the closing of the Tender Offer and the redemption described above, a Collateral Fall-Away Event under the indenture governing the 2023 Senior Notes occurred on May 30, 2017, and the 2023 Senior Notes became unsecured and certain covenants were modified, as provided for in the indenture governing the 2023 Senior Notes and related documents.

DELAWARE ECONOMIC DEVELOPMENT A

DELAWARE ECONOMIC DEVELOPMENT AUTHORITY LOAN	6 Months Ended
	Jun. 30, 2017
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 converted to a grant in tranches of $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 December 2016, the Company received confirmation from the Authority that the final tranche had satisfied the conditions necessary to be converted to a grant. Accordingly, there was no outstanding balance under the Delaware Economic Development Authority Loan at December 31, 2016.

CREDIT FACILITY AND LONG-TERM D

CREDIT FACILITY AND LONG-TERM DEBT	6 Months Ended
	Jun. 30, 2017
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 the 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. The LC Participation Fee ranges from 1.25% to 2.0% depending on the Company's senior secured 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 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 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 senior secured 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 contains customary covenants and restrictions on the activities of PBF Holding and its subsidiaries, including, but not limited to, limitations on the incurrence of additional indebtedness; liens, negative pledges, guarantees, investments, loans, asset sales, mergers, acquisitions and prepayment of other debt; distributions, dividends and the repurchase of capital stock; transactions with affiliates; the ability to change the nature of our business or our fiscal year; the ability to amend the terms of the Senior Secured Notes facility documents; and sale and leaseback transactions. In addition, 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. The outstanding borrowings under the Revolving Loan as of December 31, 2016 was $350,000 . There were no outstanding borrowings under the Revolving Loan as of December 31, 2015 . Standby letters of credit were $411,997 and $351,511 , as of December 31, 2016 and December 31, 2015, 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 as Administrative Agent. The primary purpose of the Rail Facility was 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 before December 2015. The Rail was amended on two occasions in 2015 and 2016. On December 22, 2016, the Rail Facility was repaid in full and terminated in connection with the issuance of the PBF Rail Term Loan (defined below). There was no amount outstanding under the Rail Facility at December 31, 2016 . There was $67,491 outstanding under the Rail Facility at December 31, 2015 . PBF Rail Term Loan On December 22, 2016, PBF Rail entered into a $35,000 term loan (the “PBF Rail Term Loan”) with DVB Bank SE (“DVB”). The PBF Rail Term Loan amortizes monthly over its five year term and bears interest at the one month LIBOR plus 2.0% . As security for the PBF Rail Term Loan, PBF Rail pledged, among other things: (i) certain eligible railcars; (ii) the Debt Service Reserve Account; and (iii) PBF Holding's membership interest in PBF Rail. Additionally, the PBF Rail Term Loan contains customary terms, events of default and covenants for transactions of this nature. PBF Rail may at any time repay the PBF Rail Term Loan without penalty in the event that railcars collateralizing the loan are sold, scrapped or otherwise removed from the collateral pool. As of December 31, 2016 , there was $35,000 outstanding under the PBF Rail Term Loan. Senior Secured Notes On February 9, 2012, PBF Holding and PBF Holding's wholly-owned subsidiary, PBF Finance Corporation, 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 used the proceeds for general corporate purposes, including to fund a portion of the purchase price for the acquisition of the Torrance refinery and related logistics assets. The 2023 Senior Secured Notes included a registration payment arrangement whereby the Company agreed to use commercially reasonable efforts to consummate an offer to exchange the 2023 Senior Secured Notes for an issue of registered notes with terms substantially identical to the notes not later than 365 days after the date of the original issuance of the notes. This registration statement was declared effective on December 1, 2016 and the exchange was consummated on January 19, 2017. As the exchange offer was not consummated by November 24, 2016, additional interest was added at a rate of 0.25% per annum for the period from November 24, 2016 through the consummation of the exchange. As a result, the Company recognized approximately $127 of additional interest expense in 2016. 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 customary terms, events of default and covenants for an issuer of non-investment grade debt securities including limitations on PBF Holding's and its restricted subsidiaries’ ability to, among other things, incur additional indebtedness or issue certain preferred stock; make equity distributions, pay dividends on or repurchase capital stock or make other restricted payments; enter into transactions with affiliates; create liens; engage in mergers and consolidations or otherwise sell all or substantially all of our assets; designate subsidiaries as unrestricted subsidiaries; make certain investments; and limit the ability of restricted subsidiaries to make payments to PBF Holding. 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 Certain subsidiaries of the Company have entered into agreements whereby such subsidiary sold a portion of its precious metals catalyst to a major commercial bank and then leased the catalyst back. The volume of the precious metals catalyst and the lease rate are fixed over the term of each lease, which is generally three years. At the maturity of each lease, the Company must repurchase the precious metals catalyst in question at its then fair market value. The Company believes that there is a substantial market for precious metals catalyst leases and that it will be able to release such catalyst at maturity. 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 the Company's refineries as of December 31, 2016 are included in the following table: Annual lease fee Annual interest rate Expiration date Paulsboro catalyst lease $ 140 2.20 % December 2019 Delaware City catalyst lease $ 210 1.95 % October 2019 Delaware City catalyst lease - Palladium $ 30 2.05 % October 2019 Toledo catalyst lease $ 331 1.99 % June 2017* Chalmette catalyst lease $ 185 3.85 % November 2018 Chalmette catalyst lease $ 171 2.20 % November 2019 Torrance catalyst lease $ 143 1.78 % July 2019 * The Toledo catalyst lease is included in long-term debt as of December 31, 2016 as the Company has the ability and intent to finance this debt through availability under other credit facilities if the catalyst lease is not renewed at maturity. Long-term debt outstanding consisted of the following: December 31, 2016 December 31, 2015 2020 Senior Secured Notes $ 670,867 $ 669,644 2023 Senior Secured Notes 500,000 500,000 Revolving Loan 350,000 — PBF Rail Term Loan 35,000 — Rail Facility — 67,491 Catalyst leases 45,969 31,802 Unamortized deferred financing costs (25,277 ) (32,217 ) 1,576,559 1,236,720 Less—Current maturities — — Long-term debt $ 1,576,559 $ 1,236,720 Debt Maturities Debt maturing in the next five years and thereafter is as follows: Year Ending December 31, 2017 $ 9,798 2018 4,941 2019 381,230 2020 670,867 2021 35,000 Thereafter 500,000 $ 1,601,836 LONG-TERM DEBT Senior Notes On May 30, 2017, PBF Holding entered into an Indenture (the “Indenture”) among PBF Holding and PBF Holding’s wholly-owned subsidiary, PBF Finance Corporation (“PBF Finance” and, together with PBF Holding, the “Issuers”), the guarantors named therein (collectively the “Guarantors”) and Wilmington Trust, National Association, as Trustee, under which the Issuers issued $725,000 in aggregate principal amount of 7.25% senior notes due 2025 (the “2025 Senior Notes”). The Issuers received net proceeds of approximately $712,586 from the offering after deducting the initial purchasers’ discount and estimated offering expenses. The Company used the net proceeds to fund the cash tender offer (the “Tender Offer”) for any and all of its outstanding 8.25% senior secured notes due 2020 (the “2020 Senior Secured Notes”), to pay the related redemption price and accrued and unpaid interest for any 2020 Senior Secured Notes that remained outstanding after the completion of the Tender Offer, and for general corporate purposes. The difference between the carrying value of the 2020 Senior Secured Notes on the date they were reacquired and the amount for which they were reacquired has been classified as debt extinguishment costs in the condensed consolidated statement of operations. The 2025 Senior 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, a registration statement relating to an offer to exchange the 2025 Senior Notes for an issue of registered notes with terms substantially identical to the notes. The Issuers will be obligated to pay additional interest if they fail to comply with their obligations to register the 2025 Senior Notes within the specified time period. The Company fully intends to file a registration statement for the exchange of the 2025 Senior Notes within the 365 day period following the closing of the 2025 Senior Notes. In addition, there are no restrictions or hindrances that the Company is aware of that would prohibit the Issuers 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 2025 Senior Notes are guaranteed on a senior unsecured basis by substantially all of PBF Holding’s subsidiaries. The 2025 Senior Notes and guarantees are senior unsecured obligations and rank equal in right of payment with all of the Issuers’ and the Guarantors’ existing and future senior indebtedness, including PBF Holding’s Revolving Loan and the Issuers’ 7.00% senior notes due 2023 (the “2023 Senior Notes”). The 2025 Senior Notes and the guarantees rank senior in right of payment to the Issuers’ and the Guarantors’ existing and future indebtedness that is expressly subordinated in right of payment thereto. The 2025 Senior Notes and the guarantees are effectively subordinated to any of the Issuers’ and the Guarantors’ existing or future secured indebtedness (including the Revolving Loan) to the extent of the value of the collateral securing such indebtedness. The 2025 Senior Notes and the guarantees are structurally subordinated to any existing or future indebtedness and other obligations of the Issuers’ non-guarantor subsidiaries. PBF Holding has optional redemption rights to repurchase all or a portion of the 2025 Senior Notes at varying prices no less than 100% of the principal amounts of the notes plus accrued and unpaid interest. The holders of the 2025 Senior Notes have repurchase options exercisable only upon a change in control, certain asset sale transactions, or in event of a default as defined in the Indenture. In addition, the 2025 Senior Notes contain customary terms, events of default and covenants for an issuer of non-investment grade debt securities that limit certain types of additional debt, equity issuances, and payments. Many of these covenants will cease to apply or will be modified if the 2025 Senior Notes are rated investment grade. Upon the satisfaction and discharge of the 2020 Senior Secured Notes in connection with the closing of the Tender Offer and the redemption described above, a Collateral Fall-Away Event under the indenture governing the 2023 Senior Notes occurred on May 30, 2017, and the 2023 Senior Notes became unsecured and certain covenants were modified, as provided for in the indenture governing the 2023 Senior Notes and related documents.

AFFILIATE NOTES PAYABLE

AFFILIATE NOTES PAYABLE	6 Months Ended
	Jun. 30, 2017
INTERCOMPANY NOTE PAYABLE [Abstract]
AFFILIATE NOTES PAYABLE	AFFILIATE NOTES PAYABLE During 2013, PBF Holding entered into notes payable with PBF Energy and PBF LLC. As of December 31, 2016 and 2015 , PBF Holding had outstanding notes payable with PBF Energy and PBF LLC for an aggregate principal amount of $86,298 and $470,047 , 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. During 2016, PBF LLC converted $379,947 of the outstanding notes payable from PBF Holding to a capital contribution. AFFILIATE NOTES PAYABLE PBF Holding has entered into affiliate notes payable with PBF Energy and PBF LLC with an interest rate of 2.5% and a five year term, which may be prepaid in whole or in part at any time, at the option of PBF Holding, without penalty or premium. Additional borrowings may be made by PBF Holding under such affiliate notes payable from time to time. In the fourth quarter of 2016, the notes were extended to 2021. Additionally, in the fourth quarter of 2016, PBF LLC converted $379,947 of the outstanding affiliate notes payable from PBF Holding to a capital contribution. In the first quarter of 2017, PBF LLC converted the full amount of outstanding affiliate notes payable from PBF Holding of $86,298 to a capital contribution. Therefore, as of June 30, 2017 , PBF Holding had no outstanding affiliate notes payable with PBF Energy and PBF LLC ( $86,298 outstanding as of December 31, 2016 ).

INTERCOMPANY NOTE PAYABLE

INTERCOMPANY NOTE PAYABLE	6 Months Ended
	Jun. 30, 2017
INTERCOMPANY NOTE PAYABLE [Abstract]
INTERCOMPANY NOTE PAYABLE	AFFILIATE NOTES PAYABLE During 2013, PBF Holding entered into notes payable with PBF Energy and PBF LLC. As of December 31, 2016 and 2015 , PBF Holding had outstanding notes payable with PBF Energy and PBF LLC for an aggregate principal amount of $86,298 and $470,047 , 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. During 2016, PBF LLC converted $379,947 of the outstanding notes payable from PBF Holding to a capital contribution. AFFILIATE NOTES PAYABLE PBF Holding has entered into affiliate notes payable with PBF Energy and PBF LLC with an interest rate of 2.5% and a five year term, which may be prepaid in whole or in part at any time, at the option of PBF Holding, without penalty or premium. Additional borrowings may be made by PBF Holding under such affiliate notes payable from time to time. In the fourth quarter of 2016, the notes were extended to 2021. Additionally, in the fourth quarter of 2016, PBF LLC converted $379,947 of the outstanding affiliate notes payable from PBF Holding to a capital contribution. In the first quarter of 2017, PBF LLC converted the full amount of outstanding affiliate notes payable from PBF Holding of $86,298 to a capital contribution. Therefore, as of June 30, 2017 , PBF Holding had no outstanding affiliate notes payable with PBF Energy and PBF LLC ( $86,298 outstanding as of December 31, 2016 ).

OTHER LONG-TERM LIABILITIES

OTHER LONG-TERM LIABILITIES	6 Months Ended
	Jun. 30, 2017
Other Liabilities Disclosure [Abstract]
OTHER LONG-TERM LIABILITIES	OTHER LONG-TERM LIABILITIES Other long-term liabilities consisted of the following: December 31, December 31, 2015 Defined benefit pension plan liabilities $ 60,007 $ 42,509 Post-retirement medical plan liabilities 22,740 17,729 Environmental liabilities 142,935 8,189 Other 429 1,397 Total other long-term liabilities $ 226,111 $ 69,824

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	6 Months Ended
	Jun. 30, 2017
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONS Transactions and Agreements with PBFX PBF Holding entered into agreements with PBFX that establish fees for certain general and administrative services, and operational and maintenance services provided by the Company to PBFX. In addition, the Company executed terminal, pipeline and storage services agreements with PBFX under which PBFX provides commercial transportation, terminaling, storage and pipeline services to the Company. These agreements with PBFX include: Contribution Agreements Immediately prior to the closing of the contribution agreements, which PBF LLC entered into with PBFX (as defined in the table below, and collectively referred to as the “Contribution Agreements”), PBF Holding contributed certain assets to PBF LLC. PBF LLC in turn contributed those assets to PBFX pursuant to the Contribution Agreements. Certain proceeds received by PBF LLC from PBFX in accordance with the Contribution Agreements were subsequently contributed by PBF LLC to PBF Holding. The Contribution Agreements include the following: Contribution Agreement Contribution Date Assets Contributed Contribution Agreement I 5/8/2014 DCR Rail Terminal and the Toledo Truck Terminal Contribution Agreement II 9/30/2014 DCR West Rack Contribution Agreement III 12/11/2014 Toledo Storage Facility Contribution Agreement IV 5/5/2015 Delaware City Products Pipeline and Truck Rack Contribution Agreement V 8/31/2016 Torrance Valley Pipeline Pursuant to Contribution Agreement V 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 Torrance Valley Pipeline Company LLC (“TVPC”). TVPC's assets consist of the Torrance Valley Pipeline which include the M55, M1 and M70 pipeline systems, including pipeline stations with storage capacity and truck unloading capability at two of the stations. PBFX Operating Company LP ("PBFX Op Co"), PBFX’s wholly-owned subsidiary, 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 Contribution Agreement V, PBF Holding records an investment in equity method investee on its balance sheet for the 50% of TVPC that it owns. The carrying value of the Company's equity method investment in TVPC was $179,882 and $0 at December 31, 2016 and 2015, respectively. The equity investment in TVPC is included in the Non-Guarantor financial position and results of PBF Holding disclosed in "Note 22 - Condensed Consolidating Financial Statements of PBF Holding" as this subsidiary is not a guarantor of the Senior Secured Notes. Commercial Agreements with PBFX 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 pipeline, rail and truck terminaling and storage services to PBF Holding and PBF Holding has committed to provide PBFX with minimum fees based on minimum monthly throughput volumes. The fees under each of these agreements are supported by contractual fee escalations for inflation adjustments and certain increases in operating costs. PBF Holding believes the terms and conditions under these agreements, as well as the Omnibus Agreement (as defined below) and the Services Agreement (as defined below) each with PBFX, are generally no less favorable to either party than those that could have been negotiated with unaffiliated parties with respect to similar services. These commercial agreements (as defined in the table below) with PBFX relating to the Contributed Assets include: Service Agreements Initiation Date Initial Term Renewals (a) MVC Force Majeure Transportation and Terminaling Delaware City Rail Terminaling Services Agreement 5/8/2014 7 years, 8 months 2 x 5 85,000 bpd PBFX or PBF Holding can declare Toledo Truck Unloading & Terminaling Services Agreement 5/8/2014 7 years, 8 months 2 x 5 5,500 bpd Delaware West Ladder Rack Terminaling Services Agreement 10/1/2014 7 years, 3 months 2 x 5 40,000 bpd Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility (b) 12/12/2014 10 years 2 x 5 4,400 bpd Delaware Pipeline Services Agreement 5/15/2015 10 years, 8 months 2 x 5 50,000 bpd Delaware Pipeline Services Agreement- Magellan Connection 11/1/2016 2 years, 5 months - 14,500 bpd Delaware City Truck Loading Services Agreement- Gasoline (c) 5/15/2015 10 years, 8 months 2 x 5 30,000 bpd Delaware City Truck Loading Services Agreement- LPGs (c) 5/15/2015 10 years, 8 months 2 x 5 5,000 bpd Torrance Valley Pipeline Transportation Services Agreement- North Pipeline 8/31/2016 10 years 2 x 5 50,000 bpd Torrance Valley Pipeline Transportation Services Agreement- South Pipeline 8/31/2016 10 years 2 x 5 70,000 bpd Torrance Valley Pipeline Transportation Services Agreement- Midway Storage Tank 8/31/2016 10 years 2 x 5 55,000 barrels (d) Torrance Valley Pipeline Transportation Services Agreement- Emido Storage Tank 8/31/2016 10 years 2 x 5 900,000 barrels per month Torrance Valley Pipeline Transportation Services Agreement- Belridge Storage Tank 8/31/2016 10 years 2 x 5 770,000 barrels per month Storage Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility (b) 12/12/2014 10 years 2 x 5 3,849,271 barrels (d) PBFX or PBF Holding can declare ____________________ (a) PBF Holding has the option to extend the agreements for up to two additional five -year terms. (b) The Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility and the Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility are referred to herein collectively as the “Toledo Storage Facility Storage and Terminaling Services Agreement." (c) The Delaware City Truck Loading Services Agreement- Gasoline and the Delaware City Truck Loading Services Agreement- LPGs are referred to herein collectively as the “Delaware City Truck Loading Services Agreement." (d) Reflects the overall capacity of the storage facility. The storage MVC is subject to effective operating capacity of each tank which can be impacted by routine tank maintenance and other factors. PBFX Plains Asset Purchase On April 29, 2016, PBFX's wholly-owed subsidiary, PBF Logistics Products Terminals LLC, purchased four refined products terminals 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 five years and include: • tank lease agreements, under which PBFX provides tank lease services to PBF Holding at the East Coast Terminals, with MVCs of total aggregate shell capacity; and • terminaling service agreements, under which PBFX provides terminaling and other services to PBF Holding at the East Coast Terminals. The terminaling service agreements have no MVCs and are billed based on actual volumes throughput, other than a terminaling services agreement between the East Coast Terminals' Paulsboro, New Jersey location and PBF Holding with a 15,000 bpd MVC. Omnibus Agreement PBF Holding entered into an omnibus agreement by and among PBFX, PBF GP, PBF LLC and PBF Holding at the closing of the PBFX Offering for the provision of executive management services and support for accounting and finance, legal, human resources, information technology, environmental, health and safety, and other administrative functions, as well as (i) PBF LLC’s agreement not to compete with PBFX under certain circumstances, subject to certain exceptions, (ii) PBFX's right of first offer for ten years to acquire certain logistics assets retained by PBF Energy following the PBFX Offering, including certain logistics assets that PBF LLC or its subsidiaries may construct or acquire in the future, subject to certain exceptions, and (iii) a license to use the PBF Logistics trademark and name. On August 31, 2016, PBF Holding and PBFX entered into the Fourth Amended and Restated Omnibus Agreement (as amended, the "Omnibus Agreement") in connection with the TVPC Acquisition resulting in an increase to the annual administrative fee to $4,000 . Services Agreement In connection with the PBFX Offering, PBF Holding and certain of its subsidiaries entered into an operation and management services and secondment agreement with PBFX Holding, pursuant to which PBF Holding and its subsidiaries provide PBFX with the personnel necessary for PBFX to perform its obligations under the commercial agreements. PBFX reimburses PBF Holding for the use of such employees and the provision of certain infrastructure-related services to the extent applicable to its operations, including storm water discharge and waste water treatment, steam, potable water, access to certain roads and grounds, sanitary sewer access, electrical power, emergency response, filter press, fuel gas, API solids treatment, fire water and compressed air. On August 31, 2016, PBF Holding and PBFX entered into the Fourth Amended and Restated Services Agreement (as amended, the "Services Agreement") in connection with the TVPC Acquisition resulting in an increased annual fee of approximately $6,386 . As noted in "Note 21 - Subsequent Events", the Services Agreement was further amended in 2017. The Services Agreement will terminate upon the termination of the Omnibus Agreement, provided that PBFX may terminate any service on 30 days’ notice. Summary of Transactions with PBFX A summary of revenue and expense transactions with PBFX is as follows: Year Ended December 31, 2016 2015 2014 Revenues under affiliate agreements: Services Agreement $ 5,121 $ 4,533 $ 2,298 Omnibus Agreement 4,805 5,297 3,600 Total expenses under affiliate agreements 175,448 142,102 59,403 The total of revenues under affiliate agreements and expenses under affiliate agreements are included in "Revenues" and "Cost of sales, excluding depreciation", respectively, in the Company's statement of operations. Fuel Strategies International, Inc. Agreement The Company engaged Fuel Strategies International, Inc, the principal of which is the brother of the former Executive Chairman of the Board of Directors of PBF Energy, to provide consulting services relating to petroleum coke and commercial operations. For the years ended December 31, 2016 and 2015 there were no charges under this agreement. For the year ended December 31, 2014 , the Company incurred charges of $588 under this agreement. This agreement has expired and is no longer in force. Agreements with the Former Executive Chairman of the Board of Directors The Company has an agreement with the former 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 former 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, 2016 , 2015 and 2014 , the Company incurred charges of $824 , $957 , and $1,214 , respectively, related to the use of this airplane. Effective July 1, 2016, PBF Investments LLC entered into a Consulting Services Agreement with the former Executive Chairman of the Board of Directors of PBF Energy for executive consultation with respect to strategic, operational, business and financial matters. Consulting payments made under this agreement were $500 for the year ended December 31, 2016 and payments are expected to be $900 annually through the agreement expiration date of December 31, 2018. 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, 2016 , 2015 and 2014 was $6,152 , $19,592 , and $130,523 respectively. RELATED PARTY TRANSACTIONS Transactions and Agreements with PBFX PBF Holding entered into agreements with PBFX that establish fees for certain general and administrative services, and operational and maintenance services provided by the Company to PBFX. In addition, the Company executed terminal, pipeline and storage services agreements with PBFX under which PBFX provides commercial transportation, terminaling, storage and pipeline services to the Company. These agreements with PBFX include the agreements set forth below: Contribution Agreements Immediately prior to the closing of certain contribution agreements, which PBF LLC entered into with PBFX (collectively referred to as the “Contribution Agreements”), PBF Holding contributed certain assets to PBF LLC. PBF LLC in turn contributed those assets to PBFX pursuant to the Contribution Agreements. Certain proceeds received by PBF LLC from PBFX in accordance with the Contribution Agreements were subsequently contributed by PBF LLC to PBF Holding. Pursuant to a Contribution Agreement entered into on February 15, 2017, PBF Holding contributed all of the issued and outstanding limited liability company interests of Paulsboro Natural Gas Pipeline Company LLC (“PNGPC”) to PBF LLC. PBFX Operating Company LP (“PBFX Op Co”), PBFX’s wholly-owned subsidiary, in turn acquired the limited liability company interests in PNGPC from PBF LLC in connection with the Contribution Agreement effective February 28, 2017. PNGPC owns and operates an existing interstate natural gas pipeline which serves PBF Holding's Paulsboro refinery (the “Paulsboro Natural Gas Pipeline”), which is subject to regulation by the Federal Energy Regulatory Commission (“FERC”). PNGPC has FERC approval for, and is in the process of constructing, a new pipeline (the “New Pipeline”) to replace the existing pipeline, which was placed in service in August 2017. In consideration for the PNGPC limited liability company interests, PBFX delivered to PBF LLC (i) an $11,600 intercompany promissory note in favor of Paulsboro Refining Company LLC, a wholly owned subsidiary of PBF Holding (the “Promissory Note”), (ii) an expansion rights and right of first refusal agreement in favor of PBF LLC with respect to the New Pipeline and (iii) an assignment and assumption agreement with respect to certain outstanding litigation involving PNGPC and the existing pipeline. Commercial Agreements In connection with the Contribution Agreements, PBF Holding entered into long-term, fee-based commercial agreements with PBFX. Under these agreements, PBFX provides various pipeline, rail and truck terminaling and storage services to PBF Holding and PBF Holding has committed to provide PBFX with minimum fees based on minimum monthly throughput volumes. The fees under each of these agreements are supported by contractual fee escalations for inflation adjustments and certain increases in operating costs. PBF Holding believes the terms and conditions under these agreements, as well as the Omnibus Agreement (as defined below) and the Services Agreement (as defined below) each with PBFX, are generally no less favorable to either party than those that could have been negotiated with unaffiliated parties with respect to similar services. These commercial agreements (as defined in the table below) with PBFX include: Service Agreements Initiation Date Initial Term Renewals (a) Minimum Volume Commitments Force Majeure Transportation and Terminaling Delaware City Rail Terminaling Services Agreement 5/8/2014 7 years, 8 months 2 x 5 85,000 bpd PBFX or PBF Holding can declare Toledo Truck Unloading & Terminaling Services Agreement 5/8/2014 7 years, 8 months 2 x 5 5,500 bpd Delaware West Ladder Rack Terminaling Services Agreement 10/1/2014 7 years, 3 months 2 x 5 40,000 bpd Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility 12/12/2014 10 years 2 x 5 4,400 bpd Delaware Pipeline Services Agreement 5/15/2015 10 years, 8 months 2 x 5 50,000 bpd Delaware Pipeline Services Agreement- Magellan Connection 11/1/2016 2 years, 5 months N/A 14,500 bpd Delaware City Truck Loading Services Agreement- Gasoline 5/15/2015 10 years, 8 months 2 x 5 30,000 bpd Delaware City Truck Loading Services Agreement- LPGs 5/15/2015 10 years, 8 months 2 x 5 5,000 bpd East Coast Terminals Terminaling Services Agreements 5/1/2016 Various (f) Evergreen 15,000 bpd (e) East Coast Terminals Tank Lease Agreements 5/1/2016 Various (f) Evergreen 350,000 barrels (c) Torrance Valley Pipeline Transportation Services Agreement- North Pipeline 8/31/2016 10 years 2 x 5 50,000 bpd Torrance Valley Pipeline Transportation Services Agreement- South Pipeline 8/31/2016 10 years 2 x 5 70,000 bpd Torrance Valley Pipeline Transportation Services Agreement- Midway Storage Tank 8/31/2016 10 years 2 x 5 55,000 barrels (c) Torrance Valley Pipeline Transportation Services Agreement- Emidio Storage Tank 8/31/2016 10 years 2 x 5 900,000 barrels per month Torrance Valley Pipeline Transportation Services Agreement- Belridge Storage Tank 8/31/2016 10 years 2 x 5 770,000 barrels per month Paulsboro Natural Gas Pipeline Services Agreement (b) 9/1/2011 15 years Evergreen N/A Toledo Terminal Services Agreement (g) 5/1/2016 1 year Evergreen N/A Storage Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility 12/12/2014 10 years 2 x 5 3,849,271 barrels (c) PBFX or PBF Holding can declare Chalmette Storage Agreement (d) See note (d) 10 years 2 x 5 625,000 barrels ____________________ (a) PBF Holding has the option to extend the agreements for up to two additional five -year terms, as applicable, in the table above. (b) In connection with the PNGPC Contribution Agreement, PBFX assumed the current commercial transportation agreement between PNGPC and the Paulsboro refinery. Subsequent to the completion of the New Pipeline, PBF Holding will enter into a new transportation agreement with PBFX. (c) Reflects the overall capacity of the storage facility. The storage minimum volume commitment (“MVC”) is subject to effective operating capacity of each tank which can be impacted by routine tank maintenance and other factors. (d) The Chalmette Storage Agreement was entered into on February 15, 2017 but commences at the earlier of November 1, 2017 or the completion of the Chalmette Storage Tank construction (as defined below). (e) The East Coast Terminals terminaling service agreements have no MVCs and are billed based on actual volumes throughput, other than a terminaling services agreement between the East Coast Terminals' Paulsboro, New Jersey location and PBF Holding with a 15,000 bpd MVC. (f) The East Coast Terminal related party agreements include varying term lengths, ranging from one to five years. (g) Subsequent to the Toledo Terminal Acquisition, the Toledo Terminal was added to the East Coast Terminals Terminaling Service Agreements. Other Agreements In addition to the commercial agreements described above, at the closing of the PBFX Offering, PBFX entered into an omnibus agreement, which has been amended and restated in connection with the closing of each of the contribution agreements with PBF GP, PBF LLC and PBF Holding (as amended, the “Omnibus Agreement”). The Omnibus Agreement addresses the payment of an annual fee for the provision of various general and administrative services and reimbursement of salary and benefit costs for certain PBF Energy employees. The annual fee was increased to $6,900 per year effective as of January 1, 2017. In connection with the PBFX Offering, PBFX also entered into an operation and management services and secondment agreement with PBF Holding and certain of its subsidiaries, pursuant to which PBF Holding and its subsidiaries provide PBFX with the personnel necessary for PBFX to perform its obligations under its commercial agreements. PBFX reimburses PBF Holding for the use of such employees and the provision of certain infrastructure-related services to the extent applicable to its operations, 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. On February 28, 2017, PBF Holding and PBFX entered into a fifth amended and restated services agreement (as amended, the “Services Agreement”) in connection with the PNGPC Contribution Agreement, resulting in an increase to the annual fee to $6,696 . The Services Agreement will terminate upon the termination of the Omnibus Agreement, provided that PBFX may terminate any service on 30 days’ notice. In connection with the Chalmette Storage Agreement, PBF Holding’s subsidiary, Chalmette Refining, entered into a twenty -year lease for the premises upon which a new tank at the Chalmette refinery (the “Chalmette Storage Tank”) will be located (the “Lease”) and a project management agreement (the “Project Management Agreement”) pursuant to which Chalmette Refining will manage the construction of the tank. The Lease can be extended by PBFX Op Co for two additional ten year terms. Summary of Transactions with PBFX A summary of revenue and expense transactions with PBFX is as follows: Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 Revenues under affiliate agreements: Services Agreement $ 1,661 $ 1,121 $ 3,279 $ 2,243 Omnibus Agreement 1,630 1,415 3,284 2,259 Total expenses under affiliate agreements 58,355 37,965 114,557 74,514

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	6 Months Ended
	Jun. 30, 2017
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	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 $129,768 , $126,060 , and $98,473 for the years ended December 31, 2016 , 2015 and 2014 , 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 $53,364 , $36,139 and $40,444 under these supply agreements for the years ended December 31, 2016 , 2015 and 2014 , 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, 2017 $ 156,699 2018 139,440 2019 115,482 2020 101,503 2021 59,305 Thereafter 185,875 $ 758,304 Employment Agreements PBF Investments (“PBFI”) has entered into amended and restated 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, pipelines and related operations are subject to extensive and frequently changing federal, state and local laws and regulations, including, but not limited to, those relating to the discharge of materials into the environment or that otherwise relate to the protection of the environment, 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 Paulsboro environmental liability of $10,792 recorded as of December 31, 2016 ( $10,367 as of December 31, 2015 ) represents the present value of expected future costs discounted at a rate of 8% . At December 31, 2016 the undiscounted liability is $16,655 and the Company expects to make aggregate payments for this liability of $6,591 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, 2016 and 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 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. As of November 1, 2015, the Company acquired Chalmette Refining, which was in discussions with the Louisiana Department of Environmental Quality ("LDEQ") to resolve self-reported deviations from refinery operations relating to certain Clean Air Act Title V permit conditions, limits and other requirements. LDEQ commenced an enforcement action against Chalmette Refining on November 14, 2014 by issuing a Consolidated Compliance Order and Notice of Potential Penalty (the "Order") covering deviations from 2009 and 2010. Chalmette Refining and LDEQ subsequently entered into a dispute resolution agreement, the enforcement of which has been suspended while negotiations are ongoing, which may include the resolution of deviations outside the periods covered by the Order. In February 2017, Chalmette Refining and the LDEQ met to resolve the issues under the Order, including the assessment of an administrative penalty against Chalmette Refining. Although a resolution has not been finalized, the administrative penalty is anticipated to be approximately $700 , including beneficial environmental projects. To the extent the administrative penalty exceeds such amount, it is not expected to be material to the Company. On January 24, 2017, in connection with a Clean Air Act inspection in May 2014 by the EPA to determine compliance with 40 CFR Subpart 68 Chemical Accident Prevention Provisions, EPA notified the Chalmette refinery of its intent to bring an enforcement action on two (2) findings from the audit. No settlement or penalty demand has been received to date. It is reasonably possible that EPA will assess penalties in these matters but any such amount is not expected to have a material impact on the Company's financial position, results of operations or cash flows. On December 23, 2016, the Delaware City refinery received a Notice of Violation (“NOV”) from DNREC concerning a potential violation of the DNREC order authorizing the shipment of crude oil by barge from the Refinery. The NOV alleges that DCR made shipments to locations other than the Paulsboro refinery in violation of the order and requests certain additional information but no penalties have been assessed at this time. On December 28, 2016, DNREC issued a Coastal Zone Act permit (the “Ethanol Permit”) to DCR allowing the utilization of existing tanks and existing marine loading equipment at their existing facilities to enable denatured ethanol to be loaded from storage tanks to marine vessels and shipped to offsite facilities. On January 13, 2017, the issuance of the Ethanol Permit was appealed by two environmental groups. On February 27, 2017, the Coastal Zone Industrial Board held a public hearing and dismissed the appeal, determining that the appellants did not have standing. The release of the Board decision is pending. On February 3, 2011, EPA sent a request for information pursuant to Section 114 of the Clean Air Act to the Paulsboro refinery with respect to compliance with EPA standards governing flaring. The refinery and EPA have recently engaged in discussions regarding a potential settlement. It is reasonably possible that EPA will assess penalties in these but any such amount is not expected to have a material impact on the Company's financial position, results of operations or cash flows. On February 14, 2017, the New Jersey Department of Environmental Protection (“DNJDEP”) submitted a proposed Administrative Consent Order (“ACO”) which covers air emission violations from 2013 through 2016 and work practice standards that were not subject to an affirmative defense at the Paulsboro refinery (“PRC”). In settlement of the violations, the NJDEP has proposed that PRC pay a civil administrative penalty of $313 , which includes $153 for a supplemental environmental project. If the offer is accepted, the remaining $160 shall be remitted by PRC within 30 days of receipt of the offer. This amount is not material to the Company, individually or in the aggregate. In connection with the acquisition of the Torrance refinery and related logistics assets, the Company assumed certain pre-existing environmental liabilities totaling $142,456 as of December 31, 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 $35,677 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 specified notices of violation ("NOVs") issued by the Southern California Air Quality Management District ("SCAQMD") in various years before the Company's ownership. Additionally, subsequent to the acquisition, the Company received further NOVs from the SCAQMD as well as from the City of Torrance and the City of Torrance Fire Department related to alleged operational violations, emission discharges and/or flaring incidents at the refinery. With the exception of one NOV for which a proposed settlement is less than $100 , no settlement or penalty demands have been received to date with respect to the other NOVs. As the ultimate outcomes are uncertain, the Company cannot currently estimate the final amount or timing of their resolution. It is reasonably possible that SCAQMD and/or the City of Torrance will assess penalties in these matters but any such amount is not expected to have a material impact on the Company’s financial position, results of operations or cash flows. On February 17, 2017, in Arnold Goldstein, et al. v. Exxon Mobil Corporation, et al. , PBF Energy Inc., PBF Energy Company LLC, the Company and the Company’s subsidiaries, PBF Energy Western Region LLC and Torrance Refining Company LLC, and the manager of the Company’s Torrance refinery along with Exxon Mobil Corporation were named as defendants in a class action and representative action complaint filed on behalf of Arnold Goldstein, John Covas, Gisela Janette La Bella and others similarly situated. The complaint was filed in the Superior Court of the State of California, County of Los Angeles and alleges negligence, strict liability, ultrahazardous activity, a continuing private nuisance, a permanent private nuisance, a continuing public nuisance, a permanent public nuisance and trespass resulting from the February 18, 2015 electrostatic precipitator ("ESP") explosion at the Torrance Refinery which was then owned and operated by Exxon. The operation of the Torrance Refinery by PBF Holding and its affiliated entities subsequent to the Company’s acquisition of the Torrance refinery in July 2016 is also referenced in the complaint. The Company was served with the lawsuit on March 1, 2017 and has not had an opportunity to evaluate the merits of the plaintiffs’ claims. To the extent that plaintiffs’ claims relate to the ESP explosion, Exxon has retained responsibility for any liabilities that would arise from the lawsuit pursuant to the agreement relating to the acquisition of the Torrance Refinery. The Company cannot currently estimate the amount of its potential liability. The Company's operations and many of the products it manufactures are subject to certain specific requirements of the Clean Air Act (the "CAA") and related state and local regulations. The CAA contains provisions that require capital expenditures for the installation of certain air pollution control devices at the Company's refineries. Subsequent rule making authorized by the CAA or similar laws or new agency interpretations of existing rules, may necessitate additional expenditures in future years. 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 where 500 PPM sulfur is 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 published the final 2014-2016 standards under the Renewable Fuels Standard ("RFS") late in 2015 and issued final 2017 RFS standards in November 2016. It is not clear that renewable fuel producers will be able to produce the volumes of these fuels required for blending in accordance with the 2017 standards. The final 2017 cellulosic standard is at approximately 135% of the 2016 standard. It is likely that cellulosic RIN production will be lower than needed forcing obligated parties, such as the Company, to purchase cellulosic “waiver credits” to comply in 2017 (the waiver credit option by regulation is only available for the cellulosic standard). The advanced and total renewable RIN requirements were raised (by 7% and 3% respectively) above the original proposed level in May 2016. Production of advanced RINs has been below what is needed for compliance in 2016. Obligated parties, such as the Company, will likely be relying on the nesting feature of the biodiesel RIN to comply with the advanced standard in 2017. While the Company believes that total renewable RIN production will be adequate for 2016 needs, the new 2017 standard will put obligated parties up against the E10 blendwall leaving little flexibility. Compliance in 2017 will likely rely on obligated parties drawing down the supply of excess RINs collectively known as the “RIN bank” and could tighten the RIN market potentially raising RIN prices further. The Company is currently evaluating the final standards, including any possible changes to the program following a new presidential administration, and they may have a material impact on the Company’s cost of compliance with RFS 2. 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 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. As a result of the Torrance Acquisition, the Company is subject to greenhouse gas emission control regulations in the state of California pursuant to Assembly Bill 32 (“AB 32”). AB 32 imposes a statewide cap on greenhouse gas emissions, including emissions from transportation fuels, with the aim of returning the state to 1990 emission levels by 2020. 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 RFS. In late 2015, the 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 invalid RINs have been retired and the Company does not expect any settlement with the EPA to resolve this matter to be material . 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 96.5% and 95.1% interest in PBF LLC as of December 31, 2016 and December 31, 2015 , 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. COMMITMENTS AND CONTINGENCIES Environmental Matters The Company’s refineries, pipelines and related operations are subject to extensive and frequently changing federal, state and local laws and regulations, including, but not limited to, those relating to the discharge of materials into the environment or that otherwise relate to the protection of the environment, 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 Paulsboro environmental liability of $11,117 recorded as of June 30, 2017 ( $10,792 as of December 31, 2016 ) 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. 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. As of November 1, 2015, the Company acquired Chalmette Refining, which was in discussions with the Louisiana Department of Environmental Quality (“LDEQ”) to resolve self-reported deviations from refinery operations relating to certain Clean Air Act Title V permit conditions, limits and other requirements. LDEQ commenced an enforcement action against Chalmette Refining on November 14, 2014 by issuing a Consolidated Compliance Order and Notice of Potential Penalty (the “Order”) covering deviations from 2009 and 2010. Chalmette Refining and LDEQ subsequently entered into a dispute resolution agreement, the enforcement of which has been suspended while negotiations are ongoing, which may include the resolution of deviations outside the periods covered by the Order. In February 2017, Chalmette Refining and the LDEQ met to resolve the issues under the Order, including the assessment of an administrative penalty against Chalmette Refining. Although a resolution has not been finalized, the administrative penalty is anticipated to be approximately $700 , including beneficial environmental projects. To the extent the administrative penalty exceeds such amount, it is not expected to be material to the Company. On January 24, 2017, in connection with a Clean Air Act inspection in May 2014 by the EPA to determine compliance with 40 CFR Subpart 68 Chemical Accident Prevention Provisions, EPA notified the Chalmette refinery of its intent to bring an enforcement action on two findings from the audit. In a letter received in June 2017 the EPA stated that there are “no violations or areas of concern” at the Chalmette refinery “for which EPA intends to take enforcement action” relative to the 2014 inspection. On December 23, 2016, the Delaware City refinery received a Notice of Violation (“NOV”) from DNREC concerning a potential violation of the DNREC order authorizing the shipment of crude oil by barge from the refinery. The NOV alleges that DCR made shipments to locations other than the Paulsboro refinery in violation of the order and requests certain additional information. On February 7, 2017, DCR responded to the NOV. On March 10, 2017, DNREC issued a $150 fine in a Notice of Penalty Assessment and Secretary’s Order to the Delaware City refinery for violating the 2013 Secretary’s Order. DNREC’s investigation found that PBF Energy violated the Order throughout 2014, when it made 17 barge shipments of crude oil over 15 days to locations other than the Paulsboro refinery. DNREC determined that the Delaware City refinery had violated the order by failing to make timely and full disclosure to DNREC about the nature and extent of those shipments, and had misrepresented the number of shipments that went to other facilities. The penalty assessment and Secretary’s Order conclude that the 2013 Secretary’s Order was violated by the Delaware City refinery by shipping crude oil from the Delaware City terminal to three locations other than the Paulsboro refinery, on 15 days in 2014, making a total of 17 separate barge shipments containing approximately 35.7 million gallons of crude oil in total. On April 28, 2017, DCR appealed the Notice of Penalty Assessment and Secretary’s Order. To the extent that the penalty and Secretary’s Order are upheld, there will not be a material adverse effect on the Company’s financial position, results of operations or cash flows. On December 28, 2016, DNREC issued a Coastal Zone Act permit (the “Ethanol permit”) to DCR allowing the utilization of existing tanks and existing marine loading equipment at their existing facilities to enable denatured ethanol to be loaded from storage tanks to marine vessels and shipped to offsite facilities. On January 13, 2017, the issuance of the Ethanol Permit was appealed by two environmental groups. On February 27, 2017, the Coastal Zone Industrial Board held a public hearing and dismissed the appeal, determining that the appellants did not have standing. The final opinion and order of the Board was issued March 16, 2017. The appellants filed an appeal of the Board’s decision with the Delaware Superior Court on March 30, 2017. On February 3, 2011, EPA sent a request for information pursuant to Section 114 of the Clean Air Act to the Paulsboro refinery with respect to compliance with EPA standards governing flaring. The refinery and the EPA have reached agreement on settlement, which includes a civil penalty of $180 . On July 13, 2017, the U.S. Department of Justice filed with the Court the motion to enter the consent decree. The refinery is waiting for the Court to take action on the motion, at which point it will be officially lodged. On February 14, 2017, the New Jersey Department of Environmental Protection (“NJDEP”) submitted a proposed Administrative Consent Order (“ACO”) which covers air emission violations from 2013 through 2016, and work practice standards that were not subject to an affirmative defense at the Paulsboro refinery. In settlement of the violations, the NJDEP has proposed that the Paulsboro refinery pay a civil administrative penalty of $313 , which includes $153 for a supplemental environmental project. This offer was accepted. The supplemental environmental project has already been completed, and the remaining $160 was p

EQUITY STRUCTURE

EQUITY STRUCTURE	6 Months Ended
	Jun. 30, 2017
Equity [Abstract]
EQUITY STRUCTURE	EQUITY STRUCTURE PBF Holding has no common stock outstanding. As of December 31, 2016 , 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 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 current and former officers, have no voting rights and are designed to increase in value only after the Company’s financial sponsors achieve certain levels of return on their investment in PBF LLC Series A Units. Accordingly, the amounts paid to the holders of PBF LLC Series B Units, if any, will reduce only the amounts otherwise payable to the PBF LLC Series A Units held by the Company’s financial sponsors, and will not reduce or otherwise impact any amounts payable to PBF Energy (the holder of PBF LLC Series C Units), the holders of PBF Energy's Class A common stock or any other holder of PBF LLC Series A Units. The maximum number of PBF LLC Series B Units authorized to be issued is 1,000,000 . PBF LLC Series C Units The PBF LLC Series C Units rank on a parity with the PBF LLC Series A Units as to distribution rights, voting rights and rights upon liquidation, winding up or dissolution. PBF LLC Series C Units are held solely by PBF Energy. Noncontrolling Interest Subsequent to the Chalmette Acquisition, 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 earnings related to the noncontrolling interest in these subsidiaries of $269 and $274 for the years ended December 31, 2016 and December 31, 2015 , respectively.

STOCK-BASED COMPENSATION

STOCK-BASED COMPENSATION	6 Months Ended
	Jun. 30, 2017
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, 2016 2015 2014 PBF LLC Series A Unit compensatory warrants and options $ — $ — $ 522 PBF Energy options 11,020 7,528 4,343 PBF Energy restricted shares 7,276 1,690 1,230 $ 18,296 $ 9,218 $ 6,095 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 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 2016 , 2015 or 2014 . The following table summarizes activity for PBF LLC Series A compensatory warrants and options for the years ended December 31, 2016 , 2015 and 2014 : 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, 2014 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 Exercised (27,833 ) 10.00 — Outstanding at December 31, 2016 612,946 $ 10.62 4.47 Exercisable and vested at December 31, 2016 612,946 $ 10.62 4.47 Exercisable and vested at December 31, 2015 640,779 $ 10.59 5.46 Exercisable and vested at December 31, 2014 753,985 $ 10.41 5.46 Expected to vest at December 31, 2016 612,946 $ 10.62 4.47 The total intrinsic value of stock options both outstanding and exercisable at December 31, 2016 , was $10,577 . The total intrinsic value of stock options exercised during the years ended December 31, 2016 , 2015 , and 2014 was $461 , $3,452 , and $618 , respectively. There was no unrecognized compensation expense related to PBF LLC Series A warrants and options at December 31, 2016 and December 31, 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. There were no non-compensatory warrants exercised during the year ended December 31, 2016 ( 24,000 non-compensatory warrants were exercised at December 31, 2015 ). At December 31, 2016 and 2015 , there were 32,719 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. There was no activity in the Series B units for the years ended December 31, 2016 , 2015 or 2014 . 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 directors, 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 360,820 , 247,720 and 30,348 shares of restricted Class A common stock were granted to certain directors, employees and management of the Company as of December 31, 2016 , 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, 2016 , 2015 and 2014 was determined using the Black-Scholes pricing model with the following weighted average assumptions: December 31, 2016 December 31, 2015 December 31, 2014 Expected life (in years) 6.25 6.25 6.25 Expected volatility 39.7 % 38.4 % 52.0 % Dividend yield 4.73 % 3.96 % 4.82 % Risk-free rate of return 1.42 % 1.58 % 1.80 % Exercise price $ 26.18 $ 30.28 $ 24.78 The following table summarizes activity for PBF Energy options for the years ended December 31, 2016 , 2015 and 2014 . Number of Weighted Weighted Stock-based awards, outstanding at January 1, 2014 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 Granted 1,792,000 $ 26.18 10.00 Exercised (11,250 ) 25.86 — Forfeited (66,500 ) 28.74 — Outstanding at December 31, 2016 5,970,625 $ 27.37 8.02 Exercisable and vested at December 31, 2016 2,271,375 $ 27.23 7.21 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 Expected to vest at December 31, 2016 5,970,625 $ 27.37 8.02 The total estimated fair value of PBF Energy options granted in 2016 and 2015 was $11,346 and $14,512 and the weighted average per unit fair value was $6.33 and $7.64 . The total intrinsic value of stock options outstanding and exercisable at December 31, 2016 , was $11,676 and $3,914 , respectively. The total intrinsic value of stock options exercised during the years ended December 31, 2016 and 2015 was $5 and $133 , respectively. Unrecognized compensation expense related to PBF Energy options at December 31, 2016 was $21,323 , which will be recognized from 2017 through 2020.

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	6 Months Ended
	Jun. 30, 2017
Compensation and Retirement Disclosure [Abstract]
EMPLOYEE BENEFIT PLANS	EMPLOYEE BENEFIT PLANS Defined Contribution Plan The Company’s defined contribution plan covers all employees. Employees are eligible to participate as of the first day of the month following 30 days of service. Participants can make basic contributions up to 50 percent of their annual salary subject to 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 $19,746 , $12,753 and $11,364 for the years ended December 31, 2016 , 2015 and 2014 , 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, Chalmette and Torrance 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, amended in 2015 to include Chalmette employees and amended in 2016 to include Torrance 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, 2016 and 2015 were as follows: Pension Plans Post-Retirement Medical Plan 2016 2015 2016 2015 Change in benefit obligation: Benefit obligation at beginning of year $ 100,011 $ 81,098 $ 17,729 $ 14,740 Service cost 36,359 24,298 1,047 967 Interest cost 3,096 2,974 528 558 Plan amendments — — 2,524 1,533 Benefit payments (3,449 ) (2,231 ) (575 ) (381 ) Actuarial loss (gain) (509 ) (6,128 ) 1,487 312 Projected benefit obligation at end of year $ 135,508 $ 100,011 $ 22,740 $ 17,729 Change in plan assets: Fair value of plan assets at beginning of year $ 57,502 $ 40,956 $ — $ — Actual return on plan assets 3,995 (13 ) — — Benefits paid (3,449 ) (2,231 ) (575 ) (381 ) Employer contributions 17,319 18,790 575 381 Fair value of plan assets at end of year $ 75,367 $ 57,502 $ — $ — Reconciliation of funded status: Fair value of plan assets at end of year $ 75,367 $ 57,502 $ — $ — Less: benefit obligations at end of year 135,508 100,011 22,740 17,729 Funded status at end of year $ (60,141 ) $ (42,509 ) $ (22,740 ) $ (17,729 ) The accumulated benefit obligations for the Company’s Pension Plans exceed the fair value of the assets of those plans at December 31, 2016 and 2015 . The accumulated benefit obligation for the defined benefit plans approximated $108,838 and $80,897 at December 31, 2016 and 2015 , 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 2017 $ 12,307 $ 1,202 2018 8,873 1,389 2019 11,027 1,653 2020 13,067 1,910 2021 16,079 2,018 Years 2022-2026 114,382 10,438 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 $36,300 to the Company’s Pension Plans during 2017 . The components of net periodic benefit cost were as follows for the years ended December 31, 2016 , 2015 and 2014 : Pension Benefits Post-Retirement Medical Plan 2016 2015 2014 2016 2015 2014 Components of net period benefit cost: Service cost $ 36,359 $ 24,298 $ 19,407 $ 1,047 $ 967 $ 1,099 Interest cost 3,096 2,974 2,404 528 558 520 Expected return on plan assets (4,681 ) (3,422 ) (2,156 ) — — — Amortization of prior service cost 53 53 39 541 326 258 Amortization of actuarial loss (gain) 1,043 1,228 1,033 — — (4 ) Net periodic benefit cost $ 35,870 $ 25,131 $ 20,727 $ 2,116 $ 1,851 $ 1,873 The pre-tax amounts recognized in other comprehensive income (loss) for the years ended December 31, 2016 , 2015 and 2014 were as follows: Pension Benefits Post-Retirement Medical Plan 2016 2015 2014 2016 2015 2014 Prior service costs (credits) $ — $ — $ 529 $ 2,524 $ 1,533 $ 3,911 Net actuarial loss (gain) 176 (2,220 ) 8,151 1,487 312 1,201 Amortization of losses and prior service cost (1,096 ) (1,281 ) (1,072 ) (541 ) (326 ) (255 ) Total changes in other comprehensive loss (income) $ (920 ) $ (3,501 ) $ 7,608 $ 3,470 $ 1,519 $ 4,857 The pre-tax amounts in accumulated other comprehensive loss as of December 31, 2016 and 2015 that have not yet been recognized as components of net periodic costs were as follows: Pension Benefits Post-Retirement Medical Plan 2016 2015 2016 2015 Prior service (costs) credits $ (476 ) $ (529 ) $ (5,983 ) $ (3,999 ) Net actuarial (loss) gain (18,975 ) (19,841 ) (1,878 ) (391 ) Total $ (19,451 ) $ (20,370 ) $ (7,861 ) $ (4,390 ) The following pre-tax amounts included in accumulated other comprehensive loss as of December 31, 2016 are expected to be recognized as components of net period benefit cost during the year ended December 31, 2017 : Pension Benefits Post-Retirement Medical Plan Amortization of prior service costs (credits) $ (53 ) $ (646 ) Amortization of net actuarial loss (gain) (452 ) — Total $ (505 ) $ (646 ) The weighted average assumptions used to determine the benefit obligations as of December 31, 2016 and 2015 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2016 2015 2016 2015 2016 2015 Discount rate - benefit obligations 4.07 % 4.17 % 4.08 % 4.22 % 3.68 % 3.76 % Rate of compensation increase 4.81 % 4.81 % 5.50 % 5.50 % — — The weighted average assumptions used to determine the net periodic benefit costs for the years ended December 31, 2016 , 2015 and 2014 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2016 2015 2014 2016 2015 2014 2016 2015 2014 Discount rates: Effective rate for service cost 4.15 % 4.25 % 4.55 % 4.17 % 4.30 % 4.55 % 4.10 % 4.32 % 4.55 % Effective rate for interest cost 3.38 % 3.31 % 4.55 % 3.20 % 3.16 % 4.55 % 3.11 % 3.09 % 4.55 % Effective rate for interest on service cost 3.59 % 3.51 % 4.55 % 3.63 % 3.37 % 4.55 % 3.84 % 4.04 % 4.55 % Expected long-term rate of return on plan assets 7.00 % 7.00 % 6.70 % — — — — — — Rate of compensation increase 4.81 % 4.81 % 4.64 % 5.50 % 5.50 % 4.64 % — — — The assumed health care cost trend rates as of December 31, 2016 and 2015 were as follows: Post-Retirement Medical Plan 2016 2015 Health care cost trend rate assumed for next year 6.1 % 6.1 % 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 2038 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 $ 14 $ (13 ) Effect on accumulated post-retirement benefit obligation 388 (367 ) The table below presents the fair values of the assets of the Company’s Qualified Plan as of December 31, 2016 and 2015 by level of fair value hierarchy. Assets categorized in Level 2 of the hierarchy consist of collective trusts and are measured at fair value based on the closing net asset value ("NAV") as determined by the fund manager and reported daily. As noted above, the Company’s post retirement medical plan is funded on a pay-as-you-go basis and has no assets. Fair Value Measurements Using NAV as Practical Expedient (Level 2) December 31, 2016 2015 Equities: Domestic equities $ 23,451 $ 17,660 Developed international equities 10,736 8,320 Emerging market equities 5,164 4,017 Global low volatility equities 6,360 4,930 Fixed-income 29,576 22,495 Cash and cash equivalents 80 80 Total $ 75,367 $ 57,502 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, 2016 , 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. EMPLOYEE BENEFIT PLANS The components of net periodic benefit cost related to the Company’s defined benefit plans consisted of the following: Three Months Ended Six Months Ended Pension Benefits 2017 2016 2017 2016 Components of net periodic benefit cost: Service cost $ 10,144 $ 7,339 $ 20,287 $ 14,679 Interest cost 1,084 775 2,168 1,551 Expected return on plan assets (1,442 ) (1,107 ) (2,884 ) (2,213 ) Amortization of prior service cost 13 13 26 26 Amortization of actuarial loss (gain) 113 194 226 388 Net periodic benefit cost $ 9,912 $ 7,214 $ 19,823 $ 14,431 Three Months Ended Six Months Ended Post Retirement Medical Plan 2017 2016 2017 2016 Components of net periodic benefit cost: Service cost $ 316 $ 219 $ 632 $ 439 Interest cost 172 133 344 267 Amortization of prior service cost 161 109 322 218 Amortization of actuarial loss (gain) — — — — Net periodic benefit cost $ 649 $ 461 $ 1,298 $ 924

REVENUES

REVENUES	6 Months Ended
	Jun. 30, 2017
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, 2016 2015 2014 Gasoline and distillates $ 14,017,350 $ 11,553,716 $ 17,050,096 Asphalt and blackoils 699,966 536,496 706,494 Chemicals 554,392 452,304 739,096 Feedstocks and other 376,471 315,042 922,003 Lubricants 260,358 266,371 410,466 Total Revenues $ 15,908,537 $ 13,123,929 $ 19,828,155

INCOME TAXES

INCOME TAXES	6 Months Ended
	Jun. 30, 2017
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 $1,378 and $648 of income tax expense for the years ended December 31, 2016 and 2015 . For the year ended December 31, 2016 , PBF Holding incurred an income tax benefit in its income statement of $8,412 , 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 fourth 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 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 and the Company’s 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 income tax provision (benefit) in the PBF Holding condensed consolidated financial statements of operations consists of the following: Three Months Ended Six Months Ended 2017 2016 2017 2016 Current tax expense (benefit) $ 737 $ 299 $ 1,209 $ (64 ) Deferred tax expense (benefit) 5,161 (5,576 ) 5,123 27,060 Total tax expense (benefit) $ 5,898 $ (5,277 ) $ 6,332 $ 26,996 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. 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.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	6 Months Ended
	Jun. 30, 2017
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	FAIR VALUE MEASUREMENTS The tables below present information about the Company's financial assets and liabilities measured and recorded at fair value on a recurring basis and indicate the fair value hierarchy of the inputs utilized to determine the fair values as of December 31, 2016 and 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 December 31, 2016 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 $ 342,837 $ — $ — $ 342,837 N/A $ 342,837 Commodity contracts 948 35 — 983 (983 ) — Derivatives included with inventory intermediation agreement — 6,058 — 6,058 — 6,058 Liabilities: Commodity contracts 859 3,548 84 4,491 (983 ) 3,508 Catalyst lease obligations — 45,969 — 45,969 — 45,969 As of December 31, 2015 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 Commodity contracts 63,810 31,256 3,543 98,609 (52,482 ) 46,127 Derivatives included with inventory intermediation arrangement — 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 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. Non-qualified pension plan assets are measured at fair value using a market approach based on published net asset values of mutual funds as a practical expedient. As of December 31, 2016 and 2015 , $9,440 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 of commodity contracts categorized in Level 3 of the fair value hierarchy: Year Ended December 31, 2016 2015 Balance at beginning of period $ 3,543 $ 1,521 Purchases — — Settlements (1,149 ) (15,222 ) Unrealized (gain) loss included in earnings (2,478 ) 17,244 Transfers into Level 3 — — Transfers out of Level 3 — — Balance at end of period $ (84 ) $ 3,543 There were no transfers between levels during the years ended December 31, 2016 and 2015 , respectively. Fair value of debt The table below summarizes the fair value and carrying value as of December 31, 2016 and 2015 . December 31, 2016 December 31, 2015 Carrying value Fair value Carrying value Fair value Senior Secured Notes due 2020 (a) $ 670,867 $ 696,098 $ 669,644 $ 706,246 Senior Secured Notes due 2023 (a) 500,000 498,801 500,000 492,452 Revolving Loan (b) 350,000 350,000 — — PBF Rail Term Loan (b) 35,000 35,000 — — Rail Facility (b) — — 67,491 67,491 Catalyst leases (c) 45,969 45,969 31,802 31,802 1,601,836 1,625,868 1,268,937 1,297,991 Less - Current maturities — — — — Less - Unamortized deferred financing costs $ 25,277 n/a $ 32,217 n/a Long-term debt $ 1,576,559 $ 1,625,868 $ 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 June 30, 2017 and December 31, 2016 . 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 June 30, 2017 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 $ 14,284 $ — $ — $ 14,284 N/A $ 14,284 Commodity contracts 32,291 1,041 — 33,332 (14,002 ) 19,330 Derivatives included with inventory intermediation agreement obligations — 9,165 — 9,165 — 9,165 Liabilities: Commodity contracts 9,720 4,282 — 14,002 (14,002 ) — Catalyst lease obligations — 47,454 — 47,454 — 47,454 As of December 31, 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 $ 342,837 $ — $ — $ 342,837 N/A $ 342,837 Commodity contracts 948 35 — 983 (983 ) — Derivatives included with inventory intermediation agreement obligations — 6,058 — 6,058 — 6,058 Liabilities: Commodity contracts 859 3,548 84 4,491 (983 ) 3,508 Catalyst lease obligations — 45,969 — 45,969 — 45,969 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 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 June 30, 2017 and December 31, 2016 , $9,599 and $9,440 , 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 of commodity contracts categorized in Level 3 of the fair value hierarchy: Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 Balance at beginning of period $ — $ 1,915 $ (84 ) $ 3,543 Purchases — — — — Settlements — (746 ) 45 (1,003 ) Unrealized gain (loss) included in earnings — (676 ) 39 (2,047 ) Transfers into Level 3 — — — — Transfers out of Level 3 — — — — Balance at end of period $ — $ 493 $ — $ 493 There were no transfers between levels during the three and six months ended June 30, 2017 or 2016 . Fair value of debt The table below summarizes the fair value and carrying value of debt as of June 30, 2017 and December 31, 2016 . June 30, 2017 December 31, 2016 Carrying value Fair value Carrying value Fair value Senior secured notes due 2020 (a) $ — $ — $ 670,867 $ 696,098 Senior notes due 2023 (a) (d) 500,000 495,543 500,000 498,801 Senior notes due 2025 (a) 725,000 699,640 — — Revolving Loan (b) 350,000 350,000 350,000 350,000 PBF Rail Term Loan (b) 31,704 31,704 35,000 35,000 Catalyst leases (c) 47,454 47,454 45,969 45,969 1,654,158 1,624,341 1,601,836 1,625,868 Less - Current maturities — — — — Less - Unamortized deferred financing costs 27,415 n/a 25,277 n/a Long-term debt $ 1,626,743 $ 1,624,341 $ 1,576,559 $ 1,625,868 (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 and senior notes. (b) The estimated fair value approximates carrying value, categorized as a Level 2 measurement, as these borrowings bear interest based upon short-term floating market interest rates. (c) Catalyst 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. (d) As discussed in “Note 5 - Long-term Debt”, these notes became unsecured following the Collateral Fall-Away Event on May 30, 2017.

DERIVATIVES

DERIVATIVES	6 Months Ended
	Jun. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVES	DERIVATIVES The Company uses derivative instruments to mitigate certain exposures to commodity price risk. The Company’s expired 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, 2016 , there were no barrels ( no barrels at December 31, 2015 ) of crude oil and feedstocks 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 December 31, 2016 , there were 2,942,348 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 December 31, 2016 , there were 5,950,000 barrels of crude oil and 2,831,000 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 December 31, 2016 and December 31, 2015 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, 2016: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 6,058 December 31, 2015: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 35,511 Derivatives not designated as hedging instruments: December 31, 2016: Commodity contracts Accrued expenses $ 3,508 December 31, 2015: Commodity contracts Accounts receivable $ 46,127 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, 2016: Derivatives included with inventory supply arrangement obligations Cost of sales $ — Derivatives included with the inventory intermediation agreement obligations Cost of sales $ (29,453 ) 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 Derivatives not designated as hedging instruments: For the year ended December 31, 2016: Commodity contracts Cost of sales $ (55,557 ) 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 Hedged items designated in fair value hedges: For the year ended December 31, 2016: Crude oil and feedstock inventory Cost of sales $ — Intermediate and refined product inventory Cost of sales $ 29,453 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 ) The Company had no ineffectiveness related to the fair value hedges as of December 31, 2016 , 2015 and 2014 . DERIVATIVES The Company uses derivative instruments to mitigate certain exposures to commodity price risk. The Company entered into the A&R Intermediation Agreements that contain purchase obligations for certain volumes of intermediates and refined products. The purchase obligations related to 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 intermediates and refined products. The level of activity for these derivatives is based on the level of operating inventories. As of June 30, 2017 , there were 3,005,137 barrels of intermediates and refined products ( 2,942,348 barrels at December 31, 2016 ) outstanding under these derivative instruments designated as fair value hedges. These volumes represent the notional value of the contract. The Company also enters into economic hedges primarily consisting of commodity derivative contracts that are not designated as hedges and are used to manage price volatility in certain crude oil and feedstock inventories as well as crude oil, feedstock, and refined product sales or purchases. The objective in entering into economic hedges is consistent with the objectives discussed above for fair value hedges. As of June 30, 2017 , there were 10,566,000 barrels of crude oil and 8,732,000 barrels of refined products ( 5,950,000 and 2,831,000 , respectively, as of December 31, 2016 ), 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 June 30, 2017 and December 31, 2016 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: June 30, 2017: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 9,165 December 31, 2016: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 6,058 Derivatives not designated as hedging instruments: June 30, 2017: Commodity contracts Accounts receivable $ 19,330 December 31, 2016: Commodity contracts Accrued expenses $ 3,508 The following table provides information about the gains or losses recognized in income on these derivative instruments and the line items in the condensed consolidated statement of operations in which such gains and losses are reflected. Description Location of Gain or (Loss) Recognized in Income on Derivatives Gain or (Loss) Recognized in Income on Derivatives Derivatives designated as hedging instruments: For the three months ended June 30, 2017: Derivatives included with the inventory intermediation agreement obligations Cost of products and other $ (20,017 ) For the three months ended June 30, 2016: Derivatives included with the inventory intermediation agreement obligations Cost of products and other $ 8,973 For the six months ended June 30, 2017: Derivatives included with the inventory intermediation agreement obligations Cost of products and other $ 3,107 For the six months ended June 30, 2016: Derivatives included with the inventory intermediation agreement obligations Cost of products and other $ (26,172 ) Derivatives not designated as hedging instruments: For the three months ended June 30, 2017: Commodity contracts Cost of products and other $ 14,293 For the three months ended June 30, 2016: Commodity contracts Cost of products and other $ (19,134 ) For the six months ended June 30, 2017: Commodity contracts Cost of products and other $ 14,684 For the six months ended June 30, 2016: Commodity contracts Cost of products and other $ (39,087 ) Hedged items designated in fair value hedges: For the three months ended June 30, 2017: Intermediate and refined product inventory Cost of products and other $ 20,017 For the three months ended June 30, 2016: Intermediate and refined product inventory Cost of products and other $ (8,973 ) For the six months ended June 30, 2017: Intermediate and refined product inventory Cost of products and other $ (3,107 ) For the six months ended June 30, 2016: Intermediate and refined product inventory Cost of products and other $ 26,172 The Company had no ineffectiveness related to the Company's fair value hedges for the three and six months ended June 30, 2017 or 2016 .

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	6 Months Ended
	Jun. 30, 2017
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS Dividend Declared On February 16, 2017, PBF Energy, PBF Holding's indirect parent, announced a dividend of $0.30 per share on outstanding Class A common stock. The dividend is payable on March 13, 2017 to Class A common stockholders of record at the close of business on February 27, 2017. Contribution Agreement On February 15, 2017, PBF LLC entered into a contribution agreement with PBFX pursuant to which PBF LLC has agreed to contribute to PBFX all of the issued and outstanding limited liability company interests of Paulsboro Natural Gas Pipeline Company LLC ("PNGPC"), a wholly-owned subsidiary of PBF Holding. PNGPC owns and operates an existing interstate natural gas pipeline that originates in Delaware County, Pennsylvania, and terminates at the delivery point to PBF Holding's Paulsboro Refinery. PNGPC has Federal Energy Regulatory Commission (“FERC”) approval for, and is in the process of constructing, a new 24” pipeline (the “New Pipeline”) to replace the existing pipeline, which will be abandoned. In consideration for the PNGPC limited liability company interests, at closing, PBFX delivered (i) an intercompany promissory note in an amount to be determined based on the amounts expended through the closing date with respect to the New Pipeline and the abandonment of the existing line, (ii) an expansion rights and right of first refusal agreement in favor of PBF LLC with respect to the New Pipeline and (iii) an assignment and assumption agreement with respect to certain outstanding litigation involving PNGPC and the existing pipeline. The transaction closed on February 28, 2017. Storage Services Agreement On February 15, 2017, the Company entered into a ten -year storage services agreement (the “Chalmette Storage Agreement”) with PBFX’s wholly-owned subsidiary, PBFX Operating Company ("PBFX Op Co"), under which PBFX, through PBFX Op Co, will provide storage services to the Company upon the earlier of November 1, 2017 and the completion of construction of a new tank at the Company's Chalmette refinery. PBFX Op Co and Chalmette Refining have entered into a twenty -year lease for the premises upon which the tank will be located and a project management agreement pursuant to which Chalmette Refining will manage the construction of the tank. Services Agreement On February 28, 2017, PBFX entered into the Fifth Amended and Restated Services Agreement (as amended, the "Services Agreement") with the Company and certain of its subsidiaries in connection with PNGPC contribution agreement and the Chalmette Storage Agreement. The Services Agreement incorporates the PNGPC natural gas pipeline and the Chalmette storage tank into its provisions and increases the annual fee to be paid to PBF Holding from $6,386 to $6,700 and includes an interim monthly fee with respect to PNGPC's existing pipeline. All annual fees to be paid pursuant to the Services Agreement are indexed for inflation. SUBSEQUENT EVENTS Dividend Declared On August 3, 2017, PBF Energy, PBF Holding's indirect parent, announced a dividend of $0.30 per share on its outstanding Class A common stock. The dividend is payable on August 31, 2017 to PBF Energy Class A common stockholders of record at the close of business on August 15, 2017. If necessary, PBF Holding will make a distribution of up to approximately $34,100 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.

CONSOLIDATING FINANCIAL STATEME

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS	6 Months Ended
	Jun. 30, 2017
Condensed Financial Information of Subsidiary Disclosure [Abstract]
CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS	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., 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, TVP 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. . CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING BALANCE SHEET December 31, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 530,085 $ 56,717 $ 41,366 $ (1,463 ) $ 626,705 Accounts receivable 599,147 7,999 8,735 — 615,881 Accounts receivable - affiliate 2,432 4,504 695 — 7,631 Inventories 1,680,058 — 183,502 — 1,863,560 Prepaid expense and other current assets 27,443 12,933 160 — 40,536 Due from related parties 24,141,120 21,883,569 4,692,799 (50,717,488 ) — Total current assets 26,980,285 21,965,722 4,927,257 (50,718,951 ) 3,154,313 Property, plant and equipment, net 33,772 2,452,877 242,050 — 2,728,699 Investment in subsidiaries 705,034 440,377 — (1,145,411 ) — Investment in equity method investee — — 179,882 — 179,882 Deferred charges and other assets, net 12,317 491,673 13 — 504,003 Total assets $ 27,731,408 $ 25,350,649 $ 5,349,202 $ (51,864,362 ) $ 6,566,897 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 360,260 $ 157,277 $ 14,291 $ (1,463 ) $ 530,365 Accounts payable - affiliate 37,077 786 — — 37,863 Accrued expenses 1,094,581 201,935 166,213 — 1,462,729 Deferred revenue 10,901 1,438 1 — 12,340 Due to related parties 22,027,065 24,031,520 4,658,903 (50,717,488 ) — Total current liabilities 23,529,884 24,392,956 4,839,408 (50,718,951 ) 2,043,297 Delaware Economic Development Authority loan — — — — — Long-term debt 1,496,085 45,908 34,566 — 1,576,559 Affiliate notes payable 86,298 — — — 86,298 Deferred tax liabilities — — 45,699 — 45,699 Other long-term liabilities 30,208 192,204 3,699 — 226,111 Due to related party - long term — — — — — Total liabilities 25,142,475 24,631,068 4,923,372 (50,718,951 ) 3,977,964 Commitments and contingencies Equity: Member's equity 2,155,863 1,714,997 374,067 (2,089,064 ) 2,155,863 Retained earnings 446,519 (999,693 ) 51,763 947,930 446,519 Accumulated other comprehensive loss (25,962 ) (8,236 ) — 8,236 (25,962 ) Total PBF Holding Company LLC equity 2,576,420 707,068 425,830 (1,132,898 ) 2,576,420 Noncontrolling interest 12,513 12,513 — (12,513 ) $ 12,513 Total equity 2,588,933 719,581 425,830 (1,145,411 ) 2,588,933 Total liabilities and equity $ 27,731,408 $ 25,350,649 $ 5,349,202 $ (51,864,362 ) $ 6,566,897 22. 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 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 liabilities — — 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 CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Year Ended December 31, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 15,808,556 $ 800,647 $ 1,524,691 $ (2,225,357 ) $ 15,908,537 Costs, expenses and other Cost of sales, excluding depreciation 13,813,293 649,242 1,527,910 (2,225,357 ) 13,765,088 Operating expenses, excluding depreciation 41 1,356,572 33,969 — 1,390,582 General and administrative expenses 123,150 27,602 (1,109 ) — 149,643 Equity income in investee — — (5,679 ) — (5,679 ) Gain on sale of asset 2,392 150 8,832 — 11,374 Depreciation and amortization expense 5,836 194,701 9,303 — 209,840 Total costs, expenses and other 13,944,712 2,228,267 1,573,226 (2,225,357 ) 15,520,848 Income (loss) from operations 1,863,844 (1,427,620 ) (48,535 ) — 387,689 Other income (expense) Equity in earnings of subsidiaries (1,502,243 ) (74,507 ) — 1,576,750 — Change in fair value of catalyst lease — 1,422 — — 1,422 Interest expense, net (125,715 ) (1,538 ) (2,283 ) — (129,536 ) Income (loss) before income taxes 235,886 (1,502,243 ) (50,818 ) 1,576,750 259,575 Income tax expense — — 23,689 — 23,689 Net income (loss) 235,886 (1,502,243 ) (74,507 ) 1,576,750 235,886 Less income attributable to noncontrolling interests 269 269 — (269 ) 269 Net income (loss) attributable to PBF Holding Company LLC $ 235,617 $ (1,502,512 ) $ (74,507 ) $ 1,577,019 $ 235,617 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 233,025 $ (1,502,512 ) $ (74,507 ) $ 1,577,019 $ 233,025 22. 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, expenses and other 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 Total costs, expenses and other 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 — — 648 — 648 Net income (loss) 187,942 (1,228,631 ) 73,563 1,154,420 187,294 Less 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, expenses and other 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 on sale of assets (277 ) — (618 ) — (895 ) Depreciation and amortization expense 13,583 164,525 888 — 178,996 Total costs, expenses and other 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 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 — — — — — 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 CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF CASH FLOW Year Ended December 31, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 235,886 $ (1,502,243 ) $ (74,507 ) $ 1,576,750 $ 235,886 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 14,874 194,722 9,337 — 218,933 Stock-based compensation — 18,296 — — 18,296 Change in fair value of catalyst lease obligation — (1,422 ) — — (1,422 ) Deferred income taxes — — 19,802 — 19,802 Non-cash change in inventory repurchase obligations 29,453 — — — 29,453 Non-cash lower of cost or market inventory adjustment (521,348 ) — — — (521,348 ) Pension and other post retirement benefit costs 7,139 30,848 — — 37,987 Equity (income) loss in investee — — (5,679 ) — (5,679 ) Loss (gain) on sale of assets 2,392 150 8,832 — 11,374 Equity in earnings of subsidiaries 1,502,243 74,507 — (1,576,750 ) — Changes in operating assets and liabilities Accounts receivable (168,338 ) 3,058 4,158 — (161,122 ) Due to/from affiliates (2,031,933 ) 2,046,280 (4,626 ) — 9,721 Inventories 217,629 — 18,973 — 236,602 Prepaid expenses and other current assets (3,200 ) (2,675 ) 92 — (5,783 ) Accounts payable 163,272 41,025 7,405 1,812 213,514 Accrued expenses 531,613 (353,591 ) 49,964 — 227,986 Deferred revenue 6,858 1,438 1 — 8,297 Other assets and liabilities (5,833 ) (16,238 ) 1,193 — (20,878 ) Net cash provided by (used in) operating activities (19,293 ) 534,155 34,945 1,812 551,619 Cash flows from investing activities: Acquisition of Torrance refinery and related logistics assets (971,932 ) — — — (971,932 ) Acquisition of Chalmette refinery, net of cash acquired — (2,659 ) — — (2,659 ) Expenditures for property, plant and equipment (21,563 ) (255,434 ) (5,433 ) — (282,430 ) Expenditures for refinery turnarounds costs — (198,664 ) — — (198,664 ) Expenditures for other assets — (42,506 ) — — (42,506 ) Return on investment in subsidiaries 12,800 — — (12,800 ) — Capital contributions to subsidiaries (8,287 ) — — 8,287 — Proceeds from sale of assets 4,802 — 19,890 — 24,692 Net cash (used in) provided by investing activities (984,180 ) (499,263 ) 14,457 (4,513 ) (1,473,499 ) 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF CASH FLOW (Continued) Cash flows from financing activities: Proceeds from parent's capital contributions — — 8,287 (8,287 ) — Contributions from PBF LLC 450,300 — — — 450,300 Distribution to parent — — (12,800 ) 12,800 — Distributions to members (139,434 ) — — — (139,434 ) Proceeds from affiliate notes payable 43,396 — — — 43,396 Repayments of affiliate notes payable (53,524 ) — — — (53,524 ) Proceeds from revolver borrowings 550,000 — — — 550,000 Repayments of revolver borrowings (200,000 ) — — — (200,000 ) Repayments of Rail Facility revolver borrowings — — (67,491 ) (67,491 ) Proceeds from PBF Rail Term Loan — — 35,000 — 35,000 Additional catalyst lease — 15,589 — — 15,589 Net cash provided by financing activities 650,738 15,589 (37,004 ) 4,513 633,836 Net increase (decrease) in cash and cash equivalents (352,735 ) 50,481 12,398 1,812 (288,044 ) Cash and equivalents, beginning of period 882,820 6,236 28,968 (3,275 ) 914,749 Cash and equivalents, end of period $ 530,085 $ 56,717 $ 41,366 $ (1,463 ) $ 626,705 22. 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 cost 7,576 19,406 — — 26,982 Gain on sale of assets (249 ) (105 ) (650 ) — (1,004 ) Equity in earnings of subsidiaries 1,154,420 — — (1,154,420 ) — Changes in operating assets and liabilities: Accounts receivable 87,689 16,124 (6,177 ) — 97,636 Due to/from affiliates (1,018,176 ) 1,133,364 (103,084 ) — 12,104 Inventories (108,751 ) (116,074 ) (47,067 ) — (271,892 ) Prepaid expense and 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 Chalmette refinery, net of cash acquired (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 ) 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 from 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 Guarantors Subsidiaries Non-Guarantors Subsidiaries Combining and Consolidated 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 Pension and other post retirement benefit costs 6,426 16,174 — — 22,600 Gain on sale of assets (277 ) — (618 ) — (895 ) Equity in earnings of subsidiaries 1,131,321 — — (1,131,321 ) — Changes in operating assets and liabilities: Accounts receivable 69,887 (17,976 ) (6,533 ) — 45,378 Due to/from affiliates (1,227,851 ) 1,328,439 (92,181 ) — 8,407 Inventories (259,352 ) 20,711 (155,390 ) — (394,031 ) Prepaid expense and 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 deferred turnarounds costs — (137,688 ) — — (137,688 ) Expenditures for other assets — (17,255 ) — — (17,255 ) Capital contributions to 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: Contributions from PBF LLC 328,664 — 44,346 (44,346 ) 328,664 Distributions to members (361,352 ) — — — (361,352 ) Proceeds from affiliate 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 Repayment 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 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING PBF Services Company, Delaware City Refining Company LLC, PBF Power Marketing LLC, Paulsboro Refining Company LLC, Toledo Refining Company LLC, Chalmette Refining, L.L.C., PBF Energy 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 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 November 24, 2015 and May 30, 2017, 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, TVP 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 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 Notes. The Senior 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) June 30, 2017 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 78,302 $ 5,961 $ 29,756 $ — $ 114,019 Accounts receivable 577,813 4,498 27,449 — 609,760 Accounts receivable - affiliate 1,461 24,428 600 — 26,489 Affiliate notes receivable — 11,600 — — 11,600 Inventories 1,654,143 — 221,021 — 1,875,164 Prepaid expense and other current assets 30,759 27,443 168 — 58,370 Due from related parties 26,546,381 22,526,098 5,683,279 (54,755,758 ) — Total current assets 28,888,859 22,600,028 5,962,273 (54,755,758 ) 2,695,402 Property, plant and equipment, net 25,896 2,527,179 239,954 — 2,793,029 Investment in subsidiaries 7,524 431,662 — (439,186 ) — Investment in equity method investee — — 174,047 — 174,047 Deferred charges and other assets, net 30,571 780,710 — — 811,281 Total assets $ 28,952,850 $ 26,339,579 $ 6,376,274 $ (55,194,944 ) $ 6,473,759 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 240,234 $ 185,231 $ 12,175 $ — $ 437,640 Accounts payable - affiliate 31,347 159 (97 ) — 31,409 Accrued expenses 1,316,523 141,382 136,395 — 1,594,300 Deferred revenue 4,899 20 13 — 4,932 Due to related parties 23,277,244 25,761,022 5,717,492 (54,755,758 ) — Total current liabilities 24,870,247 26,087,814 5,865,978 (54,755,758 ) 2,068,281 Long-term debt 1,548,024 47,406 31,313 — 1,626,743 Deferred tax liabilities — — 50,822 — 50,822 Other long-term liabilities 29,772 189,189 4,145 — 223,106 Total liabilities 26,448,043 26,324,409 5,952,258 (54,755,758 ) 3,968,952 Commitments and contingencies Equity: Member’s equity 2,349,357 1,720,206 362,598 (2,082,804 ) 2,349,357 Retained earnings / (accumulated deficit) 167,868 (1,709,693 ) 61,418 1,648,275 167,868 Accumulated other comprehensive (loss) income (25,311 ) (8,236 ) — 8,236 (25,311 ) Total PBF Holding Company LLC equity 2,491,914 2,277 424,016 (426,293 ) 2,491,914 Noncontrolling interest 12,893 12,893 — (12,893 ) 12,893 Total equity 2,504,807 15,170 424,016 (439,186 ) 2,504,807 Total liabilities and equity $ 28,952,850 $ 26,339,579 $ 6,376,274 $ (55,194,944 ) $ 6,473,759 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) December 31, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 530,085 $ 56,717 $ 41,366 $ (1,463 ) $ 626,705 Accounts receivable 599,147 7,999 8,735 — 615,881 Accounts receivable - affiliate 2,432 4,504 695 — 7,631 Inventories 1,680,058 — 183,502 — 1,863,560 Prepaid expense and other current assets 27,443 12,933 160 — 40,536 Due from related parties 24,141,120 21,883,569 4,692,799 (50,717,488 ) — Total current assets 26,980,285 21,965,722 4,927,257 (50,718,951 ) 3,154,313 Property, plant and equipment, net 33,772 2,452,877 242,050 — 2,728,699 Investment in subsidiaries 705,034 440,377 — (1,145,411 ) — Investment in equity method investee — — 179,882 — 179,882 Deferred charges and other assets, net 12,317 491,673 13 — 504,003 Total assets $ 27,731,408 $ 25,350,649 $ 5,349,202 $ (51,864,362 ) $ 6,566,897 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 360,260 $ 157,277 $ 14,291 $ (1,463 ) $ 530,365 Accounts payable - affiliate 37,077 786 — — 37,863 Accrued expenses 1,094,581 201,935 166,213 — 1,462,729 Deferred revenue 10,901 1,438 1 — 12,340 Due to related parties 22,027,065 24,031,520 4,658,903 (50,717,488 ) — Total current liabilities 23,529,884 24,392,956 4,839,408 (50,718,951 ) 2,043,297 Long-term debt 1,496,085 45,908 34,566 — 1,576,559 Affiliate notes payable 86,298 — — — 86,298 Deferred tax liabilities — — 45,699 — 45,699 Other long-term liabilities 30,208 192,204 3,699 — 226,111 Total liabilities 25,142,475 24,631,068 4,923,372 (50,718,951 ) 3,977,964 Commitments and contingencies Equity: Member’s equity 2,155,863 1,714,997 374,067 (2,089,064 ) 2,155,863 Retained earnings / (accumulated deficit) 446,519 (999,693 ) 51,763 947,930 446,519 Accumulated other comprehensive (loss) income (25,962 ) (8,236 ) — 8,236 (25,962 ) Total PBF Holding Company LLC equity 2,576,420 707,068 425,830 (1,132,898 ) 2,576,420 Noncontrolling interest 12,513 12,513 — (12,513 ) 12,513 Total equity 2,588,933 719,581 425,830 (1,145,411 ) 2,588,933 Total liabilities and equity $ 27,731,408 $ 25,350,649 $ 5,349,202 $ (51,864,362 ) $ 6,566,897 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Three Months Ended June 30, 2017 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 4,928,464 $ 134,566 $ 512,262 $ (562,041 ) $ 5,013,251 Cost and expenses: Cost of products and other 4,703,574 32,288 489,012 (562,041 ) 4,662,833 Operating expenses (excluding depreciation) (326 ) 389,889 9,007 — 398,570 General and administrative expenses 28,843 6,286 (209 ) — 34,920 Equity (income) loss in investee — — (3,820 ) — (3,820 ) Loss on sale of assets — 29 — — 29 Depreciation and amortization expense 6,019 55,077 1,897 — 62,993 4,738,110 483,569 495,887 (562,041 ) 5,155,525 Income (loss) from operations 190,354 (349,003 ) 16,375 — (142,274 ) Other income (expenses): Equity in earnings (loss) of subsidiaries (338,171 ) 1,442 — 336,729 — Change in fair value of catalyst leases — 1,104 — — 1,104 Debt extinguishment costs (25,451 ) — — — (25,451 ) Interest expense, net (32,108 ) (480 ) (269 ) — (32,857 ) Income (loss) before income taxes (205,376 ) (346,937 ) 16,106 336,729 (199,478 ) Income tax expense — — 5,898 — 5,898 Net income (loss) (205,376 ) (346,937 ) 10,208 336,729 (205,376 ) Less: net income attributable to noncontrolling interests 267 267 — (267 ) 267 Net income (loss) attributable to PBF Holding Company LLC $ (205,643 ) $ (347,204 ) $ 10,208 $ 336,996 $ (205,643 ) Comprehensive income (loss) attributable to PBF Holding Company LLC $ (205,313 ) $ (347,204 ) $ 10,208 $ 336,996 $ (205,313 ) 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Three Months Ended June 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 3,834,460 $ 95,163 $ 339,721 $ (413,571 ) $ 3,855,773 Cost and expenses: Cost of products and other 3,300,539 39,483 358,297 (413,571 ) 3,284,748 Operating expenses (excluding depreciation) (28 ) 268,608 2,959 — 271,539 General and administrative expenses 28,609 9,209 273 — 38,091 Loss on sale of assets — 24 3,198 — 3,222 Depreciation and amortization expense 1,379 45,780 1,760 — 48,919 3,330,499 363,104 366,487 (413,571 ) 3,646,519 Income (loss) from operations 503,961 (267,941 ) (26,766 ) — 209,254 Other income (expenses): Equity in earnings (loss) of subsidiaries (292,212 ) — — 292,212 — Change in fair value of catalyst leases — (1,748 ) — — (1,748 ) Interest expense, net (30,245 ) (484 ) (550 ) — (31,279 ) Income (loss) before income taxes 181,504 (270,173 ) (27,316 ) 292,212 176,227 Income tax benefit — — (5,277 ) — (5,277 ) Net income (loss) 181,504 (270,173 ) (22,039 ) 292,212 181,504 Less: net income attributable to noncontrolling interests 90 90 — (90 ) 90 Net income (loss) attributable to PBF Holding Company LLC $ 181,414 $ (270,263 ) $ (22,039 ) $ 292,302 $ 181,414 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 181,829 $ (270,263 ) $ (22,039 ) $ 292,302 $ 181,829 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Six Months Ended June 30, 2017 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 9,654,243 $ 760,335 $ 1,042,167 $ (1,693,296 ) $ 9,763,449 Cost and expenses: Cost of products and other 9,064,194 530,062 1,013,627 (1,693,296 ) 8,914,587 Operating expenses (excluding depreciation) (331 ) 819,419 16,335 — 835,423 General and administrative expenses 62,538 13,451 (590 ) — 75,399 Equity (income) loss in investee — — (7,419 ) — (7,419 ) Loss on sale of assets — 912 — — 912 Depreciation and amortization expense 7,781 107,124 3,778 — 118,683 9,134,182 1,470,968 1,025,731 (1,693,296 ) 9,937,585 Income (loss) from operations 520,061 (710,633 ) 16,436 — (174,136 ) Other income (expenses): Equity in earnings (loss) of subsidiaries (703,300 ) 3,335 — 699,965 — Change in fair value of catalyst leases — (1,484 ) — — (1,484 ) Debt extinguishment costs (25,451 ) — — — (25,451 ) Interest expense, net (62,226 ) (838 ) (449 ) — (63,513 ) Income (loss) before income taxes (270,916 ) (709,620 ) 15,987 699,965 (264,584 ) Income tax expense — — 6,332 — 6,332 Net income (loss) (270,916 ) (709,620 ) 9,655 699,965 (270,916 ) Less: net income attributable to noncontrolling interests 380 380 — (380 ) 380 Net income (loss) attributable to PBF Holding Company LLC $ (271,296 ) $ (710,000 ) $ 9,655 $ 700,345 $ (271,296 ) Comprehensive income (loss) attributable to PBF Holding Company LLC $ (270,645 ) $ (710,000 ) $ 9,655 $ 700,345 $ (270,645 ) 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE IN

SUMMARY OF SIGNIFICANT ACCOUN32

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
	Jun. 30, 2017
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	2,016
Use of Estimates	Use of Estimates The preparation of the financial statements in conformity with accounting principles generally accepted in the United States ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures. Actual results could differ from those estimates.
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	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, 2016 . Following the Chalmette Acquisition on November 1, 2015, ExxonMobil Oil Corporation and its affiliates represented approximately 18% of our total trade accounts receivable as of December 31, 2015
Revenue, Deferred Revenue and Accounts Receivable	no allowance for doubtful accounts at December 31, 2016 and 2015 .
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.
Property, Plant and Equipment	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
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 tax returns for all years since 2013 and state tax returns for all years since 2012 or 2013 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	Recently Issued Accounting Pronouncements In February 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update 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 has adopted this guidance retrospectively. The adoption of this guidance did not have any impact on the Company as it does not have any variable interest entities that would be affected by this ASU. In August 2015, the FASB issued Accounting Standards Update 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. 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 modified retrospective 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 has established a working group to assess the Updated Revenue Recognition Guidance, including its impact on our business processes, accounting systems, controls and financial statement disclosures. Our preliminary expectation is that we will adopt this guidance using the modified retrospective method whereby a cumulative effect adjustment is recognized upon adoption and the Updated Revenue Recognition is applied prospectively. It is not anticipated that the Company will early adopt this new guidance. The working group is in the early stages of its implementation plan and continues to evaluate the impact of this new standard on the Company’s consolidated financial statements and related disclosures. Although our analysis of the new standard is still in process and interpretative and industry specific guidance is still developing, the Company currently does not expect the new standard to have a material impact on the amount or timing of revenues recognized for the majority of its revenue arrangements. 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 early adopted the new standard in its consolidated financial statements and related disclosures on a prospective basis. The Company did not have any current deferred tax assets or liabilities in the prior year to reclassify from current to non-current. 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 US 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 has established a working group to study and lead implementation of the new guidance in ASU 2016-02. This working group was formed during 2016 and has begun the process of compiling a central repository for all leases entered into by the Company and its subsidiaries for further analysis as the implementation project progresses. It is not anticipated that the Company will early adopt this new guidance. The working group continues to evaluate the impact of this new standard on its consolidated financial statements and related disclosures. At this time, the Company has identified that the most significant impacts of this new guidance will be to bring nearly all leases on its balance sheet with “right of use assets” and “lease obligation liabilities” as well as accelerating the interest expense component of financing leases. 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. In January 2017, the FASB issued ASU No. 2017-01, "Business Combinations (Topic 805): Clarifying the Definition of a Business" ("ASU 2017-01"), which provides guidance to assist entities with evaluating when a set of transferred assets and activities is a business. Under ASU 2017-01, it is expected that the definition of a business will be narrowed and more consistently applied. ASU 2017-01 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods. The amendments in this ASU should be applied prospectively on or after the effective date. The Company will apply the provisions of this guidance for determining if it has acquired a business or a set of assets for future acquisitions, if any, after it becomes effective. Recently Adopted Accounting Guidance Effective January 1, 2017, the Company adopted Accounting Standard Update (“ASU”) No. 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments (a consensus of the FASB Emerging Issues Task Force)” (“ASU 2016-06”). ASU 2016-6 was issued in March 2016 by the Financial Accounting Standards Board (“FASB”) 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 Company’s adoption of this guidance did not materially impact its consolidated financial statements. Effective January 1, 2017, the Company adopted ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”). ASU 2016-09 was issued by the FASB in March 2016 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 could prior to its adoption for tax withholding purposes without triggering liability accounting and to make a policy election to account for forfeitures as they occur. The Company’s adoption of this guidance did not materially impact its consolidated financial statements. Effective January 1, 2017, the Company adopted ASU No. 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control” (“ASU 2016-17”). ASU 2016-17 was issued by the FASB in October 2016 to amend 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 a reporting entity, in determining whether it satisfies the second characteristic of a primary beneficiary, 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. The Company’s adoption of this guidance did not materially impact its consolidated financial statements. In January 2017, the FASB issued ASU No. 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business” (“ASU 2017-01”), which provides guidance to assist entities with evaluating when a set of transferred assets and activities is a business. Under ASU 2017-01, it is expected that the definition of a business will be narrowed and more consistently applied. ASU 2017-01 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods. The amendments in this ASU should be applied prospectively on or after the effective date. Early adoption of ASU 2017-01 is permitted and the Company early adopted the new standard in its consolidated financial statements and related disclosures effective January 1, 2017. The Company’s adoption of this guidance did not materially impact its consolidated financial statements. Recent Accounting Pronouncements 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. 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 modified retrospective 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 has established a working group to assess the Updated Revenue Recognition Guidance, including its impact on the Company’s business processes, accounting systems, controls and financial statement disclosures. The Company’s preliminary expectation is that it will adopt this guidance using the modified retrospective method whereby a cumulative effect adjustment is recognized upon adoption and the Updated Revenue Recognition Guidance is applied prospectively. The Company will not early adopt this new guidance. The working group is progressing through its implementation plan and continues to evaluate the impact of this new standard on the Company’s consolidated financial statements and related disclosures. Although the Company’s analysis of the new standard is still in process and interpretative and industry specific guidance is still developing, the Company currently does not expect the new standard to have a material impact on the amount or timing of revenues recognized for the majority of its revenue arrangements. However, it is expected that the new standard will have some impact on presentation and disclosures in its financial statements. 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 has established a working group to study and lead implementation of the new guidance in ASU 2016-02. This working group was formed during 2016 and has begun the process of compiling a central repository for all leases entered into by the Company and its subsidiaries for further analysis as the implementation project progresses. It is not anticipated that the Company will early adopt this new guidance. The working group continues to evaluate the impact of this new standard on its consolidated financial statements and related disclosures. At this time, the Company has identified that the most significant impacts of this new guidance will be to bring nearly all leases on its balance sheet with “right of use assets” and “lease obligation liabilities” as well as accelerating the interest expense component of financing leases. While the assessment of the impacts arising from this standard is progressing, it remains in its early stages. Accordingly, the Company has not fully determined the impacts on its business processes, controls or financial statement disclosures. In March 2017, the FASB issued ASU No. 2017-07, “Compensation—Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” (“ASU 2017-07”), which provides guidance to improve the reporting of net benefit cost in the income statement and on the components eligible for capitalization in assets. Under the new guidance, employers will present the service cost component of net periodic benefit cost in the same income statement line item(s) as other employee compensation costs arising from services rendered during the period. Only the service cost component will be eligible for capitalization in assets. Additionally, under this guidance, employers will present the other components of the net periodic benefit cost separately from the line item(s) that includes the service cost and outside of any subtotal of operating income, if one is presented. These components will not be eligible for capitalization in assets. Employers will apply the guidance on the presentation of the components of net periodic benefit cost in the income statement retrospectively. The guidance limiting the capitalization of net periodic benefit cost in assets to the service cost component will be applied prospectively. The guidance includes a practical expedient allowing entities to estimate amounts for comparative periods using the information previously disclosed in their pension and other postretirement benefit plan note to the financial statements. The amendments in this ASU are effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures. In May 2017, the FASB issued ASU No. 2017-09, “Compensation—Stock Compensation (Topic 718): Scope of Modification Accounting” (“ASU 2017-09”), which provides guidance to increase clarity and reduce both diversity in practice and cost and complexity when applying the existing accounting guidance on changes to the terms or conditions of a share-based payment award. The amendments in ASU 2017-09 require an entity to account for the effects of a modification unless all the following are met: (i) the fair value of the modified award is the same as the fair value of the original award immediately before the original award is modified; (ii) the vesting conditions of the modified award are the same as the vesting conditions of the original award immediately before the original award is modified; and (iii) the classification of the modified award as an equity instrument or a liability instrument is the same as the classification of the original award immediately before the original award is modified. The guidance in ASU 2017-09 should be applied prospectively. The amendments in this ASU are effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. The Company will apply the guidance prospectively for any modifications to its stock compensation plans occurring after the effective date of the new standard.

SUMMARY OF SIGNIFICANT ACCOUN33

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	6 Months Ended
	Jun. 30, 2017
Accounting Policies [Abstract]
Useful lives of property, plant and equipment	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 $ 253,110 $ 91,256 Process units, pipelines and equipment 2,504,008 2,209,712 Buildings and leasehold improvements 49,020 34,265 Computers, furniture and fixtures 81,780 72,642 Construction in progress 289,338 150,388 3,177,256 2,558,263 Less—Accumulated depreciation (448,557 ) (347,173 ) $ 2,728,699 $ 2,211,090

ACQUISITIONS (Tables)

ACQUISITIONS (Tables)	6 Months Ended
	Jun. 30, 2017
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 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
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	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 703,443 Deferred charges and other assets, net 68,053 Accounts payable (2,688 ) Accrued expenses (64,137 ) Other long-term liabilities (138,467 ) Fair value of net assets acquired $ 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 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 interest (11,821 ) Fair value of net assets acquired $ 567,963 The following table summarizes the 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 982 Property, plant and equipment 704,633 Deferred charges and other assets, net 68,053 Accounts payable (2,688 ) Accrued expenses (64,137 ) Other long-term liabilities (139,453 ) Fair value of net assets acquired $ 971,932
Business Acquisition, Pro Forma Information	Years ended December 31, (Unaudited) 2016 2015 Pro forma revenues $ 16,987,548 $ 16,252,729 Pro forma net income (loss) attributable to PBF Holding Company LLC $ 31,565 $ (176,410 ) Year ended December 31, (Unaudited) 2015 Pro forma revenues $ 16,811,922 Pro forma net income attributable to PBF Holding Company LLC 397,108 Six Months Ended June 30, 2016 Pro forma revenues $ 7,734,969 Pro forma net loss attributable to PBF Holding Company LLC $ (121,369 )

INVENTORIES (Tables)

INVENTORIES (Tables)	6 Months Ended
	Jun. 30, 2017
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventories consisted of the following: December 31, 2016 Titled Inventory Inventory Supply and Intermediation Arrangements Total Crude oil and feedstocks $ 1,102,007 $ — $ 1,102,007 Refined products and blendstocks 915,397 352,464 1,267,861 Warehouse stock and other 89,680 — 89,680 $ 2,107,084 $ 352,464 $ 2,459,548 Lower of cost or market adjustment (492,415 ) (103,573 ) (595,988 ) Total inventories $ 1,614,669 $ 248,891 $ 1,863,560 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 adjustment (966,564 ) (150,772 ) (1,117,336 ) Total inventories $ 913,687 $ 260,585 $ 1,174,272 Inventories consisted of the following: June 30, 2017 Titled Inventory Inventory Intermediation Arrangements Total Crude oil and feedstocks $ 1,307,816 $ — $ 1,307,816 Refined products and blendstocks 935,041 300,939 1,235,980 Warehouse stock and other 94,490 — 94,490 $ 2,337,347 $ 300,939 $ 2,638,286 Lower of cost or market adjustment (650,702 ) (112,420 ) (763,122 ) Total inventories $ 1,686,645 $ 188,519 $ 1,875,164 December 31, 2016 Titled Inventory Inventory Intermediation Arrangements Total Crude oil and feedstocks $ 1,102,007 $ — $ 1,102,007 Refined products and blendstocks 915,397 352,464 1,267,861 Warehouse stock and other 89,680 — 89,680 $ 2,107,084 $ 352,464 $ 2,459,548 Lower of cost or market adjustment (492,415 ) (103,573 ) (595,988 ) Total inventories $ 1,614,669 $ 248,891 $ 1,863,560 Inventories consisted of the following: June 30, 2017 Titled Inventory Inventory Intermediation Arrangements Total Crude oil and feedstocks $ 1,307,816 $ — $ 1,307,816 Refined products and blendstocks 935,041 300,939 1,235,980 Warehouse stock and other 94,490 — 94,490 $ 2,337,347 $ 300,939 $ 2,638,286 Lower of cost or market adjustment (650,702 ) (112,420 ) (763,122 ) Total inventories $ 1,686,645 $ 188,519 $ 1,875,164 December 31, 2016 Titled Inventory Inventory Intermediation Arrangements Total Crude oil and feedstocks $ 1,102,007 $ — $ 1,102,007 Refined products and blendstocks 915,397 352,464 1,267,861 Warehouse stock and other 89,680 — 89,680 $ 2,107,084 $ 352,464 $ 2,459,548 Lower of cost or market adjustment (492,415 ) (103,573 ) (595,988 ) Total inventories $ 1,614,669 $ 248,891 $ 1,863,560

PROPERTY, PLANT AND EQUIPMENT36

PROPERTY, PLANT AND EQUIPMENT, NET (Tables)	6 Months Ended
	Jun. 30, 2017
Property, Plant and Equipment [Abstract]
Summary of property, plant and equipment	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 $ 253,110 $ 91,256 Process units, pipelines and equipment 2,504,008 2,209,712 Buildings and leasehold improvements 49,020 34,265 Computers, furniture and fixtures 81,780 72,642 Construction in progress 289,338 150,388 3,177,256 2,558,263 Less—Accumulated depreciation (448,557 ) (347,173 ) $ 2,728,699 $ 2,211,090

DEFERRED CHARGES AND OTHER AS37

DEFERRED CHARGES AND OTHER ASSETS, NET (Tables)	6 Months Ended
	Jun. 30, 2017
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: December 31, December 31, 2015 Deferred turnaround costs, net $ 302,919 $ 177,236 Catalyst 114,788 77,725 Linefill 19,485 13,504 Restricted cash — 1,500 Environmental credits 51,636 10,829 Intangible assets, net 577 219 Other 14,598 9,700 $ 504,003 $ 290,713
Intangible assets, net	Intangible assets, net was comprised of permits and emission credits as follows: December 31, December 31, 2015 Gross amount $ 3,996 $ 3,597 Accumulated amortization (3,419 ) (3,378 ) Net amount $ 577 $ 219

ACCRUED EXPENSES (Tables)

ACCRUED EXPENSES (Tables)	6 Months Ended
	Jun. 30, 2017
Payables and Accruals [Abstract]
Schedule of accrued expenses	Accrued expenses consisted of the following: December 31, December 31, 2015 Inventory-related accruals $ 810,027 $ 548,800 Inventory intermediation arrangements 225,524 252,380 Accrued transportation costs 89,830 91,546 Excise and sales tax payable 86,046 34,129 Renewable energy credit and emissions obligations 70,158 19,472 Accrued utilities 44,190 25,192 Accrued interest 28,934 22,313 Accrued construction in progress 33,610 7,400 Accrued salaries and benefits 17,466 61,011 Customer deposits 9,215 20,395 Environmental liabilities 8,882 2,178 Other 38,847 32,619 Total accrued expenses $ 1,462,729 $ 1,117,435 Accrued expenses consisted of the following: June 30, December 31, Inventory-related accruals $ 778,746 $ 810,027 Inventory intermediation arrangements 233,455 225,524 Renewable energy credit and emissions obligations 172,331 70,158 Excise and sales tax payable 100,998 86,046 Accrued transportation costs 83,312 89,830 Accrued capital expenditures 75,711 33,610 Accrued refinery maintenance and support costs 32,326 28,670 Accrued utilities 28,914 44,190 Customer deposits 23,912 9,215 Accrued salaries and benefits 15,961 17,466 Accrued interest 9,047 28,934 Environmental liabilities 8,902 8,882 Other 30,685 10,177 Total accrued expenses $ 1,594,300 $ 1,462,729

CREDIT FACILITY AND LONG-TERM39

CREDIT FACILITY AND LONG-TERM DEBT (Tables)	6 Months Ended
	Jun. 30, 2017
Debt Disclosure [Abstract]
Summary of long-term debt outstanding	December 31, 2016 December 31, 2015 2020 Senior Secured Notes $ 670,867 $ 669,644 2023 Senior Secured Notes 500,000 500,000 Revolving Loan 350,000 — PBF Rail Term Loan 35,000 — Rail Facility — 67,491 Catalyst leases 45,969 31,802 Unamortized deferred financing costs (25,277 ) (32,217 ) 1,576,559 1,236,720 Less—Current maturities — — Long-term debt $ 1,576,559 $ 1,236,720 December 31, 2016 are included in the following table: Annual lease fee Annual interest rate Expiration date Paulsboro catalyst lease $ 140 2.20 % December 2019 Delaware City catalyst lease $ 210 1.95 % October 2019 Delaware City catalyst lease - Palladium $ 30 2.05 % October 2019 Toledo catalyst lease $ 331 1.99 % June 2017* Chalmette catalyst lease $ 185 3.85 % November 2018 Chalmette catalyst lease $ 171 2.20 % November 2019 Torrance catalyst lease $ 143 1.78 % July 2019
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, 2017 $ 9,798 2018 4,941 2019 381,230 2020 670,867 2021 35,000 Thereafter 500,000 $ 1,601,836

OTHER LONG-TERM LIABILITIES (Ta

OTHER LONG-TERM LIABILITIES (Tables)	6 Months Ended
	Jun. 30, 2017
Other Liabilities Disclosure [Abstract]
Schedule of other long-term liabilities	Other long-term liabilities consisted of the following: December 31, December 31, 2015 Defined benefit pension plan liabilities $ 60,007 $ 42,509 Post-retirement medical plan liabilities 22,740 17,729 Environmental liabilities 142,935 8,189 Other 429 1,397 Total other long-term liabilities $ 226,111 $ 69,824

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	6 Months Ended
	Jun. 30, 2017
Related Party Transactions [Abstract]
Summary of revenue and expense transactions with affiliates	A summary of revenue and expense transactions with PBFX is as follows: Year Ended December 31, 2016 2015 2014 Revenues under affiliate agreements: Services Agreement $ 5,121 $ 4,533 $ 2,298 Omnibus Agreement 4,805 5,297 3,600 Total expenses under affiliate agreements 175,448 142,102 59,403 These commercial agreements (as defined in the table below) with PBFX relating to the Contributed Assets include: Service Agreements Initiation Date Initial Term Renewals (a) MVC Force Majeure Transportation and Terminaling Delaware City Rail Terminaling Services Agreement 5/8/2014 7 years, 8 months 2 x 5 85,000 bpd PBFX or PBF Holding can declare Toledo Truck Unloading & Terminaling Services Agreement 5/8/2014 7 years, 8 months 2 x 5 5,500 bpd Delaware West Ladder Rack Terminaling Services Agreement 10/1/2014 7 years, 3 months 2 x 5 40,000 bpd Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility (b) 12/12/2014 10 years 2 x 5 4,400 bpd Delaware Pipeline Services Agreement 5/15/2015 10 years, 8 months 2 x 5 50,000 bpd Delaware Pipeline Services Agreement- Magellan Connection 11/1/2016 2 years, 5 months - 14,500 bpd Delaware City Truck Loading Services Agreement- Gasoline (c) 5/15/2015 10 years, 8 months 2 x 5 30,000 bpd Delaware City Truck Loading Services Agreement- LPGs (c) 5/15/2015 10 years, 8 months 2 x 5 5,000 bpd Torrance Valley Pipeline Transportation Services Agreement- North Pipeline 8/31/2016 10 years 2 x 5 50,000 bpd Torrance Valley Pipeline Transportation Services Agreement- South Pipeline 8/31/2016 10 years 2 x 5 70,000 bpd Torrance Valley Pipeline Transportation Services Agreement- Midway Storage Tank 8/31/2016 10 years 2 x 5 55,000 barrels (d) Torrance Valley Pipeline Transportation Services Agreement- Emido Storage Tank 8/31/2016 10 years 2 x 5 900,000 barrels per month Torrance Valley Pipeline Transportation Services Agreement- Belridge Storage Tank 8/31/2016 10 years 2 x 5 770,000 barrels per month Storage Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility (b) 12/12/2014 10 years 2 x 5 3,849,271 barrels (d) PBFX or PBF Holding can declare ____________________ (a) PBF Holding has the option to extend the agreements for up to two additional five -year terms. (b) The Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility and the Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility are referred to herein collectively as the “Toledo Storage Facility Storage and Terminaling Services Agreement." (c) The Delaware City Truck Loading Services Agreement- Gasoline and the Delaware City Truck Loading Services Agreement- LPGs are referred to herein collectively as the “Delaware City Truck Loading Services Agreement." (d) Reflects the overall capacity of the storage facility. The storage MVC is subject to effective operating capacity of each tank which can be impacted by routine tank maintenance and other factors. A summary of revenue and expense transactions with PBFX is as follows: Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 Revenues under affiliate agreements: Services Agreement $ 1,661 $ 1,121 $ 3,279 $ 2,243 Omnibus Agreement 1,630 1,415 3,284 2,259 Total expenses under affiliate agreements 58,355 37,965 114,557 74,514 These commercial agreements (as defined in the table below) with PBFX include: Service Agreements Initiation Date Initial Term Renewals (a) Minimum Volume Commitments Force Majeure Transportation and Terminaling Delaware City Rail Terminaling Services Agreement 5/8/2014 7 years, 8 months 2 x 5 85,000 bpd PBFX or PBF Holding can declare Toledo Truck Unloading & Terminaling Services Agreement 5/8/2014 7 years, 8 months 2 x 5 5,500 bpd Delaware West Ladder Rack Terminaling Services Agreement 10/1/2014 7 years, 3 months 2 x 5 40,000 bpd Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility 12/12/2014 10 years 2 x 5 4,400 bpd Delaware Pipeline Services Agreement 5/15/2015 10 years, 8 months 2 x 5 50,000 bpd Delaware Pipeline Services Agreement- Magellan Connection 11/1/2016 2 years, 5 months N/A 14,500 bpd Delaware City Truck Loading Services Agreement- Gasoline 5/15/2015 10 years, 8 months 2 x 5 30,000 bpd Delaware City Truck Loading Services Agreement- LPGs 5/15/2015 10 years, 8 months 2 x 5 5,000 bpd East Coast Terminals Terminaling Services Agreements 5/1/2016 Various (f) Evergreen 15,000 bpd (e) East Coast Terminals Tank Lease Agreements 5/1/2016 Various (f) Evergreen 350,000 barrels (c) Torrance Valley Pipeline Transportation Services Agreement- North Pipeline 8/31/2016 10 years 2 x 5 50,000 bpd Torrance Valley Pipeline Transportation Services Agreement- South Pipeline 8/31/2016 10 years 2 x 5 70,000 bpd Torrance Valley Pipeline Transportation Services Agreement- Midway Storage Tank 8/31/2016 10 years 2 x 5 55,000 barrels (c) Torrance Valley Pipeline Transportation Services Agreement- Emidio Storage Tank 8/31/2016 10 years 2 x 5 900,000 barrels per month Torrance Valley Pipeline Transportation Services Agreement- Belridge Storage Tank 8/31/2016 10 years 2 x 5 770,000 barrels per month Paulsboro Natural Gas Pipeline Services Agreement (b) 9/1/2011 15 years Evergreen N/A Toledo Terminal Services Agreement (g) 5/1/2016 1 year Evergreen N/A Storage Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility 12/12/2014 10 years 2 x 5 3,849,271 barrels (c) PBFX or PBF Holding can declare Chalmette Storage Agreement (d) See note (d) 10 years 2 x 5 625,000 barrels ____________________ (a) PBF Holding has the option to extend the agreements for up to two additional five -year terms, as applicable, in the table above. (b) In connection with the PNGPC Contribution Agreement, PBFX assumed the current commercial transportation agreement between PNGPC and the Paulsboro refinery. Subsequent to the completion of the New Pipeline, PBF Holding will enter into a new transportation agreement with PBFX. (c) Reflects the overall capacity of the storage facility. The storage minimum volume commitment (“MVC”) is subject to effective operating capacity of each tank which can be impacted by routine tank maintenance and other factors. (d) The Chalmette Storage Agreement was entered into on February 15, 2017 but commences at the earlier of November 1, 2017 or the completion of the Chalmette Storage Tank construction (as defined below). (e) The East Coast Terminals terminaling service agreements have no MVCs and are billed based on actual volumes throughput, other than a terminaling services agreement between the East Coast Terminals' Paulsboro, New Jersey location and PBF Holding with a 15,000 bpd MVC. (f) The East Coast Terminal related party agreements include varying term lengths, ranging from one to five years. (g) Subsequent to the Toledo Terminal Acquisition, the Toledo Terminal was added to the East Coast Terminals Terminaling Service Agreements.

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2017 $ 156,699 2018 139,440 2019 115,482 2020 101,503 2021 59,305 Thereafter 185,875 $ 758,304

STOCK-BASED COMPENSATION (Table

STOCK-BASED COMPENSATION (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2016 2015 2014 PBF LLC Series A Unit compensatory warrants and options $ — $ — $ 522 PBF Energy options 11,020 7,528 4,343 PBF Energy restricted shares 7,276 1,690 1,230 $ 18,296 $ 9,218 $ 6,095
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, 2016 , 2015 and 2014 : 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, 2014 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 Exercised (27,833 ) 10.00 — Outstanding at December 31, 2016 612,946 $ 10.62 4.47 Exercisable and vested at December 31, 2016 612,946 $ 10.62 4.47 Exercisable and vested at December 31, 2015 640,779 $ 10.59 5.46 Exercisable and vested at December 31, 2014 753,985 $ 10.41 5.46 Expected to vest at December 31, 2016 612,946 $ 10.62 4.47 Number of Weighted Weighted Stock-based awards, outstanding at January 1, 2014 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 Granted 1,792,000 $ 26.18 10.00 Exercised (11,250 ) 25.86 — Forfeited (66,500 ) 28.74 — Outstanding at December 31, 2016 5,970,625 $ 27.37 8.02 Exercisable and vested at December 31, 2016 2,271,375 $ 27.23 7.21 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 Expected to vest at December 31, 2016 5,970,625 $ 27.37 8.02
Weighted average assumptions	The estimated fair value of PBF Energy options granted during the years ended December 31, 2016 , 2015 and 2014 was determined using the Black-Scholes pricing model with the following weighted average assumptions: December 31, 2016 December 31, 2015 December 31, 2014 Expected life (in years) 6.25 6.25 6.25 Expected volatility 39.7 % 38.4 % 52.0 % Dividend yield 4.73 % 3.96 % 4.82 % Risk-free rate of return 1.42 % 1.58 % 1.80 % Exercise price $ 26.18 $ 30.28 $ 24.78

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2016 and 2015 were as follows: Pension Plans Post-Retirement Medical Plan 2016 2015 2016 2015 Change in benefit obligation: Benefit obligation at beginning of year $ 100,011 $ 81,098 $ 17,729 $ 14,740 Service cost 36,359 24,298 1,047 967 Interest cost 3,096 2,974 528 558 Plan amendments — — 2,524 1,533 Benefit payments (3,449 ) (2,231 ) (575 ) (381 ) Actuarial loss (gain) (509 ) (6,128 ) 1,487 312 Projected benefit obligation at end of year $ 135,508 $ 100,011 $ 22,740 $ 17,729 Change in plan assets: Fair value of plan assets at beginning of year $ 57,502 $ 40,956 $ — $ — Actual return on plan assets 3,995 (13 ) — — Benefits paid (3,449 ) (2,231 ) (575 ) (381 ) Employer contributions 17,319 18,790 575 381 Fair value of plan assets at end of year $ 75,367 $ 57,502 $ — $ — Reconciliation of funded status: Fair value of plan assets at end of year $ 75,367 $ 57,502 $ — $ — Less: benefit obligations at end of year 135,508 100,011 22,740 17,729 Funded status at end of year $ (60,141 ) $ (42,509 ) $ (22,740 ) $ (17,729 )
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 2017 $ 12,307 $ 1,202 2018 8,873 1,389 2019 11,027 1,653 2020 13,067 1,910 2021 16,079 2,018 Years 2022-2026 114,382 10,438
Schedule of net periodic benefit cost	The components of net periodic benefit cost were as follows for the years ended December 31, 2016 , 2015 and 2014 : Pension Benefits Post-Retirement Medical Plan 2016 2015 2014 2016 2015 2014 Components of net period benefit cost: Service cost $ 36,359 $ 24,298 $ 19,407 $ 1,047 $ 967 $ 1,099 Interest cost 3,096 2,974 2,404 528 558 520 Expected return on plan assets (4,681 ) (3,422 ) (2,156 ) — — — Amortization of prior service cost 53 53 39 541 326 258 Amortization of actuarial loss (gain) 1,043 1,228 1,033 — — (4 ) Net periodic benefit cost $ 35,870 $ 25,131 $ 20,727 $ 2,116 $ 1,851 $ 1,873 Three Months Ended Six Months Ended Pension Benefits 2017 2016 2017 2016 Components of net periodic benefit cost: Service cost $ 10,144 $ 7,339 $ 20,287 $ 14,679 Interest cost 1,084 775 2,168 1,551 Expected return on plan assets (1,442 ) (1,107 ) (2,884 ) (2,213 ) Amortization of prior service cost 13 13 26 26 Amortization of actuarial loss (gain) 113 194 226 388 Net periodic benefit cost $ 9,912 $ 7,214 $ 19,823 $ 14,431 Three Months Ended Six Months Ended Post Retirement Medical Plan 2017 2016 2017 2016 Components of net periodic benefit cost: Service cost $ 316 $ 219 $ 632 $ 439 Interest cost 172 133 344 267 Amortization of prior service cost 161 109 322 218 Amortization of actuarial loss (gain) — — — — Net periodic benefit cost $ 649 $ 461 $ 1,298 $ 924
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, 2016 , 2015 and 2014 were as follows: Pension Benefits Post-Retirement Medical Plan 2016 2015 2014 2016 2015 2014 Prior service costs (credits) $ — $ — $ 529 $ 2,524 $ 1,533 $ 3,911 Net actuarial loss (gain) 176 (2,220 ) 8,151 1,487 312 1,201 Amortization of losses and prior service cost (1,096 ) (1,281 ) (1,072 ) (541 ) (326 ) (255 ) Total changes in other comprehensive loss (income) $ (920 ) $ (3,501 ) $ 7,608 $ 3,470 $ 1,519 $ 4,857
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, 2016 and 2015 that have not yet been recognized as components of net periodic costs were as follows: Pension Benefits Post-Retirement Medical Plan 2016 2015 2016 2015 Prior service (costs) credits $ (476 ) $ (529 ) $ (5,983 ) $ (3,999 ) Net actuarial (loss) gain (18,975 ) (19,841 ) (1,878 ) (391 ) Total $ (19,451 ) $ (20,370 ) $ (7,861 ) $ (4,390 )
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, 2016 are expected to be recognized as components of net period benefit cost during the year ended December 31, 2017 : Pension Benefits Post-Retirement Medical Plan Amortization of prior service costs (credits) $ (53 ) $ (646 ) Amortization of net actuarial loss (gain) (452 ) — Total $ (505 ) $ (646 )
Schedule of assumptions used	The weighted average assumptions used to determine the benefit obligations as of December 31, 2016 and 2015 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2016 2015 2016 2015 2016 2015 Discount rate - benefit obligations 4.07 % 4.17 % 4.08 % 4.22 % 3.68 % 3.76 % Rate of compensation increase 4.81 % 4.81 % 5.50 % 5.50 % — — The weighted average assumptions used to determine the net periodic benefit costs for the years ended December 31, 2016 , 2015 and 2014 were as follows: Qualified Plan Supplemental Plan Post-Retirement Medical Plan 2016 2015 2014 2016 2015 2014 2016 2015 2014 Discount rates: Effective rate for service cost 4.15 % 4.25 % 4.55 % 4.17 % 4.30 % 4.55 % 4.10 % 4.32 % 4.55 % Effective rate for interest cost 3.38 % 3.31 % 4.55 % 3.20 % 3.16 % 4.55 % 3.11 % 3.09 % 4.55 % Effective rate for interest on service cost 3.59 % 3.51 % 4.55 % 3.63 % 3.37 % 4.55 % 3.84 % 4.04 % 4.55 % Expected long-term rate of return on plan assets 7.00 % 7.00 % 6.70 % — — — — — — Rate of compensation increase 4.81 % 4.81 % 4.64 % 5.50 % 5.50 % 4.64 % — — —
Schedule of assumed health care cost trend rates	The assumed health care cost trend rates as of December 31, 2016 and 2015 were as follows: Post-Retirement Medical Plan 2016 2015 Health care cost trend rate assumed for next year 6.1 % 6.1 % 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 2038
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 $ 14 $ (13 ) Effect on accumulated post-retirement benefit obligation 388 (367 )
Schedule of fair value of assets of the Company's Qualified Plan	The table below presents the fair values of the assets of the Company’s Qualified Plan as of December 31, 2016 and 2015 by level of fair value hierarchy. Assets categorized in Level 2 of the hierarchy consist of collective trusts and are measured at fair value based on the closing net asset value ("NAV") as determined by the fund manager and reported daily. As noted above, the Company’s post retirement medical plan is funded on a pay-as-you-go basis and has no assets. Fair Value Measurements Using NAV as Practical Expedient (Level 2) December 31, 2016 2015 Equities: Domestic equities $ 23,451 $ 17,660 Developed international equities 10,736 8,320 Emerging market equities 5,164 4,017 Global low volatility equities 6,360 4,930 Fixed-income 29,576 22,495 Cash and cash equivalents 80 80 Total $ 75,367 $ 57,502

REVENUES (Tables)

REVENUES (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2016 2015 2014 Gasoline and distillates $ 14,017,350 $ 11,553,716 $ 17,050,096 Asphalt and blackoils 699,966 536,496 706,494 Chemicals 554,392 452,304 739,096 Feedstocks and other 376,471 315,042 922,003 Lubricants 260,358 266,371 410,466 Total Revenues $ 15,908,537 $ 13,123,929 $ 19,828,155

INCOME TAXES (Tables)

INCOME TAXES (Tables)	6 Months Ended
	Jun. 30, 2017
Income Tax Disclosure [Abstract]
Schedule of components of income tax provision (benefit)	The income tax provision (benefit) in the PBF Holding condensed consolidated financial statements of operations consists of the following: Three Months Ended Six Months Ended 2017 2016 2017 2016 Current tax expense (benefit) $ 737 $ 299 $ 1,209 $ (64 ) Deferred tax expense (benefit) 5,161 (5,576 ) 5,123 27,060 Total tax expense (benefit) $ 5,898 $ (5,277 ) $ 6,332 $ 26,996

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	6 Months Ended
	Jun. 30, 2017
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The tables below present information about the Company's financial assets and liabilities measured and recorded at fair value on a recurring basis and indicate the fair value hierarchy of the inputs utilized to determine the fair values as of December 31, 2016 and 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 December 31, 2016 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 $ 342,837 $ — $ — $ 342,837 N/A $ 342,837 Commodity contracts 948 35 — 983 (983 ) — Derivatives included with inventory intermediation agreement — 6,058 — 6,058 — 6,058 Liabilities: Commodity contracts 859 3,548 84 4,491 (983 ) 3,508 Catalyst lease obligations — 45,969 — 45,969 — 45,969 As of December 31, 2015 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 Commodity contracts 63,810 31,256 3,543 98,609 (52,482 ) 46,127 Derivatives included with inventory intermediation arrangement — 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 June 30, 2017 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 $ 14,284 $ — $ — $ 14,284 N/A $ 14,284 Commodity contracts 32,291 1,041 — 33,332 (14,002 ) 19,330 Derivatives included with inventory intermediation agreement obligations — 9,165 — 9,165 — 9,165 Liabilities: Commodity contracts 9,720 4,282 — 14,002 (14,002 ) — Catalyst lease obligations — 47,454 — 47,454 — 47,454 As of December 31, 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 $ 342,837 $ — $ — $ 342,837 N/A $ 342,837 Commodity contracts 948 35 — 983 (983 ) — Derivatives included with inventory intermediation agreement obligations — 6,058 — 6,058 — 6,058 Liabilities: Commodity contracts 859 3,548 84 4,491 (983 ) 3,508 Catalyst lease obligations — 45,969 — 45,969 — 45,969
Schedule of Effect of Significant Unobservable Inputs	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, 2016 2015 Balance at beginning of period $ 3,543 $ 1,521 Purchases — — Settlements (1,149 ) (15,222 ) Unrealized (gain) loss included in earnings (2,478 ) 17,244 Transfers into Level 3 — — Transfers out of Level 3 — — Balance at end of period $ (84 ) $ 3,543 The table below summarizes the changes in fair value measurements of commodity contracts categorized in Level 3 of the fair value hierarchy: Three Months Ended June 30, Six Months Ended June 30, 2017 2016 2017 2016 Balance at beginning of period $ — $ 1,915 $ (84 ) $ 3,543 Purchases — — — — Settlements — (746 ) 45 (1,003 ) Unrealized gain (loss) included in earnings — (676 ) 39 (2,047 ) Transfers into Level 3 — — — — Transfers out of Level 3 — — — — Balance at end of period $ — $ 493 $ — $ 493
Schedule of Fair value of Debt	The table below summarizes the fair value and carrying value as of December 31, 2016 and 2015 . December 31, 2016 December 31, 2015 Carrying value Fair value Carrying value Fair value Senior Secured Notes due 2020 (a) $ 670,867 $ 696,098 $ 669,644 $ 706,246 Senior Secured Notes due 2023 (a) 500,000 498,801 500,000 492,452 Revolving Loan (b) 350,000 350,000 — — PBF Rail Term Loan (b) 35,000 35,000 — — Rail Facility (b) — — 67,491 67,491 Catalyst leases (c) 45,969 45,969 31,802 31,802 1,601,836 1,625,868 1,268,937 1,297,991 Less - Current maturities — — — — Less - Unamortized deferred financing costs $ 25,277 n/a $ 32,217 n/a Long-term debt $ 1,576,559 $ 1,625,868 $ 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. The table below summarizes the fair value and carrying value of debt as of June 30, 2017 and December 31, 2016 . June 30, 2017 December 31, 2016 Carrying value Fair value Carrying value Fair value Senior secured notes due 2020 (a) $ — $ — $ 670,867 $ 696,098 Senior notes due 2023 (a) (d) 500,000 495,543 500,000 498,801 Senior notes due 2025 (a) 725,000 699,640 — — Revolving Loan (b) 350,000 350,000 350,000 350,000 PBF Rail Term Loan (b) 31,704 31,704 35,000 35,000 Catalyst leases (c) 47,454 47,454 45,969 45,969 1,654,158 1,624,341 1,601,836 1,625,868 Less - Current maturities — — — — Less - Unamortized deferred financing costs 27,415 n/a 25,277 n/a Long-term debt $ 1,626,743 $ 1,624,341 $ 1,576,559 $ 1,625,868

DERIVATIVES (Tables)

DERIVATIVES (Tables)	6 Months Ended
	Jun. 30, 2017
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 December 31, 2016 and December 31, 2015 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, 2016: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 6,058 December 31, 2015: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 35,511 Derivatives not designated as hedging instruments: December 31, 2016: Commodity contracts Accrued expenses $ 3,508 December 31, 2015: Commodity contracts Accounts receivable $ 46,127 The following tables provide information about the fair values of these derivative instruments as of June 30, 2017 and December 31, 2016 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: June 30, 2017: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 9,165 December 31, 2016: Derivatives included with the inventory intermediation agreement obligations Accrued expenses $ 6,058 Derivatives not designated as hedging instruments: June 30, 2017: Commodity contracts Accounts receivable $ 19,330 December 31, 2016: Commodity contracts Accrued expenses $ 3,508
Schedule of Derivative Instruments, Gain (Loss) Recognized in Income	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, 2016: Derivatives included with inventory supply arrangement obligations Cost of sales $ — Derivatives included with the inventory intermediation agreement obligations Cost of sales $ (29,453 ) 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 Derivatives not designated as hedging instruments: For the year ended December 31, 2016: Commodity contracts Cost of sales $ (55,557 ) 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 Hedged items designated in fair value hedges: For the year ended December 31, 2016: Crude oil and feedstock inventory Cost of sales $ — Intermediate and refined product inventory Cost of sales $ 29,453 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 ) The following table provides information about the gains or losses recognized in income on these derivative instruments and the line items in the condensed consolidated statement of operations in which such gains and losses are reflected. Description Location of Gain or (Loss) Recognized in Income on Derivatives Gain or (Loss) Recognized in Income on Derivatives Derivatives designated as hedging instruments: For the three months ended June 30, 2017: Derivatives included with the inventory intermediation agreement obligations Cost of products and other $ (20,017 ) For the three months ended June 30, 2016: Derivatives included with the inventory intermediation agreement obligations Cost of products and other $ 8,973 For the six months ended June 30, 2017: Derivatives included with the inventory intermediation agreement obligations Cost of products and other $ 3,107 For the six months ended June 30, 2016: Derivatives included with the inventory intermediation agreement obligations Cost of products and other $ (26,172 ) Derivatives not designated as hedging instruments: For the three months ended June 30, 2017: Commodity contracts Cost of products and other $ 14,293 For the three months ended June 30, 2016: Commodity contracts Cost of products and other $ (19,134 ) For the six months ended June 30, 2017: Commodity contracts Cost of products and other $ 14,684 For the six months ended June 30, 2016: Commodity contracts Cost of products and other $ (39,087 ) Hedged items designated in fair value hedges: For the three months ended June 30, 2017: Intermediate and refined product inventory Cost of products and other $ 20,017 For the three months ended June 30, 2016: Intermediate and refined product inventory Cost of products and other $ (8,973 ) For the six months ended June 30, 2017: Intermediate and refined product inventory Cost of products and other $ (3,107 ) For the six months ended June 30, 2016: Intermediate and refined product inventory Cost of products and other $ 26,172

CONSOLIDATING FINANCIAL STATE49

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Tables)	6 Months Ended
	Jun. 30, 2017
Condensed Financial Information of Subsidiary Disclosure [Abstract]
Condensed Consolidating Balance Sheet	December 31, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 530,085 $ 56,717 $ 41,366 $ (1,463 ) $ 626,705 Accounts receivable 599,147 7,999 8,735 — 615,881 Accounts receivable - affiliate 2,432 4,504 695 — 7,631 Inventories 1,680,058 — 183,502 — 1,863,560 Prepaid expense and other current assets 27,443 12,933 160 — 40,536 Due from related parties 24,141,120 21,883,569 4,692,799 (50,717,488 ) — Total current assets 26,980,285 21,965,722 4,927,257 (50,718,951 ) 3,154,313 Property, plant and equipment, net 33,772 2,452,877 242,050 — 2,728,699 Investment in subsidiaries 705,034 440,377 — (1,145,411 ) — Investment in equity method investee — — 179,882 — 179,882 Deferred charges and other assets, net 12,317 491,673 13 — 504,003 Total assets $ 27,731,408 $ 25,350,649 $ 5,349,202 $ (51,864,362 ) $ 6,566,897 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 360,260 $ 157,277 $ 14,291 $ (1,463 ) $ 530,365 Accounts payable - affiliate 37,077 786 — — 37,863 Accrued expenses 1,094,581 201,935 166,213 — 1,462,729 Deferred revenue 10,901 1,438 1 — 12,340 Due to related parties 22,027,065 24,031,520 4,658,903 (50,717,488 ) — Total current liabilities 23,529,884 24,392,956 4,839,408 (50,718,951 ) 2,043,297 Delaware Economic Development Authority loan — — — — — Long-term debt 1,496,085 45,908 34,566 — 1,576,559 Affiliate notes payable 86,298 — — — 86,298 Deferred tax liabilities — — 45,699 — 45,699 Other long-term liabilities 30,208 192,204 3,699 — 226,111 Due to related party - long term — — — — — Total liabilities 25,142,475 24,631,068 4,923,372 (50,718,951 ) 3,977,964 Commitments and contingencies Equity: Member's equity 2,155,863 1,714,997 374,067 (2,089,064 ) 2,155,863 Retained earnings 446,519 (999,693 ) 51,763 947,930 446,519 Accumulated other comprehensive loss (25,962 ) (8,236 ) — 8,236 (25,962 ) Total PBF Holding Company LLC equity 2,576,420 707,068 425,830 (1,132,898 ) 2,576,420 Noncontrolling interest 12,513 12,513 — (12,513 ) $ 12,513 Total equity 2,588,933 719,581 425,830 (1,145,411 ) 2,588,933 Total liabilities and equity $ 27,731,408 $ 25,350,649 $ 5,349,202 $ (51,864,362 ) $ 6,566,897 22. 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 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 liabilities — — 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 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) June 30, 2017 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 78,302 $ 5,961 $ 29,756 $ — $ 114,019 Accounts receivable 577,813 4,498 27,449 — 609,760 Accounts receivable - affiliate 1,461 24,428 600 — 26,489 Affiliate notes receivable — 11,600 — — 11,600 Inventories 1,654,143 — 221,021 — 1,875,164 Prepaid expense and other current assets 30,759 27,443 168 — 58,370 Due from related parties 26,546,381 22,526,098 5,683,279 (54,755,758 ) — Total current assets 28,888,859 22,600,028 5,962,273 (54,755,758 ) 2,695,402 Property, plant and equipment, net 25,896 2,527,179 239,954 — 2,793,029 Investment in subsidiaries 7,524 431,662 — (439,186 ) — Investment in equity method investee — — 174,047 — 174,047 Deferred charges and other assets, net 30,571 780,710 — — 811,281 Total assets $ 28,952,850 $ 26,339,579 $ 6,376,274 $ (55,194,944 ) $ 6,473,759 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 240,234 $ 185,231 $ 12,175 $ — $ 437,640 Accounts payable - affiliate 31,347 159 (97 ) — 31,409 Accrued expenses 1,316,523 141,382 136,395 — 1,594,300 Deferred revenue 4,899 20 13 — 4,932 Due to related parties 23,277,244 25,761,022 5,717,492 (54,755,758 ) — Total current liabilities 24,870,247 26,087,814 5,865,978 (54,755,758 ) 2,068,281 Long-term debt 1,548,024 47,406 31,313 — 1,626,743 Deferred tax liabilities — — 50,822 — 50,822 Other long-term liabilities 29,772 189,189 4,145 — 223,106 Total liabilities 26,448,043 26,324,409 5,952,258 (54,755,758 ) 3,968,952 Commitments and contingencies Equity: Member’s equity 2,349,357 1,720,206 362,598 (2,082,804 ) 2,349,357 Retained earnings / (accumulated deficit) 167,868 (1,709,693 ) 61,418 1,648,275 167,868 Accumulated other comprehensive (loss) income (25,311 ) (8,236 ) — 8,236 (25,311 ) Total PBF Holding Company LLC equity 2,491,914 2,277 424,016 (426,293 ) 2,491,914 Noncontrolling interest 12,893 12,893 — (12,893 ) 12,893 Total equity 2,504,807 15,170 424,016 (439,186 ) 2,504,807 Total liabilities and equity $ 28,952,850 $ 26,339,579 $ 6,376,274 $ (55,194,944 ) $ 6,473,759 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING BALANCE SHEET (UNAUDITED) December 31, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total ASSETS Current assets: Cash and cash equivalents $ 530,085 $ 56,717 $ 41,366 $ (1,463 ) $ 626,705 Accounts receivable 599,147 7,999 8,735 — 615,881 Accounts receivable - affiliate 2,432 4,504 695 — 7,631 Inventories 1,680,058 — 183,502 — 1,863,560 Prepaid expense and other current assets 27,443 12,933 160 — 40,536 Due from related parties 24,141,120 21,883,569 4,692,799 (50,717,488 ) — Total current assets 26,980,285 21,965,722 4,927,257 (50,718,951 ) 3,154,313 Property, plant and equipment, net 33,772 2,452,877 242,050 — 2,728,699 Investment in subsidiaries 705,034 440,377 — (1,145,411 ) — Investment in equity method investee — — 179,882 — 179,882 Deferred charges and other assets, net 12,317 491,673 13 — 504,003 Total assets $ 27,731,408 $ 25,350,649 $ 5,349,202 $ (51,864,362 ) $ 6,566,897 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 360,260 $ 157,277 $ 14,291 $ (1,463 ) $ 530,365 Accounts payable - affiliate 37,077 786 — — 37,863 Accrued expenses 1,094,581 201,935 166,213 — 1,462,729 Deferred revenue 10,901 1,438 1 — 12,340 Due to related parties 22,027,065 24,031,520 4,658,903 (50,717,488 ) — Total current liabilities 23,529,884 24,392,956 4,839,408 (50,718,951 ) 2,043,297 Long-term debt 1,496,085 45,908 34,566 — 1,576,559 Affiliate notes payable 86,298 — — — 86,298 Deferred tax liabilities — — 45,699 — 45,699 Other long-term liabilities 30,208 192,204 3,699 — 226,111 Total liabilities 25,142,475 24,631,068 4,923,372 (50,718,951 ) 3,977,964 Commitments and contingencies Equity: Member’s equity 2,155,863 1,714,997 374,067 (2,089,064 ) 2,155,863 Retained earnings / (accumulated deficit) 446,519 (999,693 ) 51,763 947,930 446,519 Accumulated other comprehensive (loss) income (25,962 ) (8,236 ) — 8,236 (25,962 ) Total PBF Holding Company LLC equity 2,576,420 707,068 425,830 (1,132,898 ) 2,576,420 Noncontrolling interest 12,513 12,513 — (12,513 ) 12,513 Total equity 2,588,933 719,581 425,830 (1,145,411 ) 2,588,933 Total liabilities and equity $ 27,731,408 $ 25,350,649 $ 5,349,202 $ (51,864,362 ) $ 6,566,897
Condensed Consolidating Statement of Operations and Comprehensive Income (Loss)	Year Ended December 31, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 15,808,556 $ 800,647 $ 1,524,691 $ (2,225,357 ) $ 15,908,537 Costs, expenses and other Cost of sales, excluding depreciation 13,813,293 649,242 1,527,910 (2,225,357 ) 13,765,088 Operating expenses, excluding depreciation 41 1,356,572 33,969 — 1,390,582 General and administrative expenses 123,150 27,602 (1,109 ) — 149,643 Equity income in investee — — (5,679 ) — (5,679 ) Gain on sale of asset 2,392 150 8,832 — 11,374 Depreciation and amortization expense 5,836 194,701 9,303 — 209,840 Total costs, expenses and other 13,944,712 2,228,267 1,573,226 (2,225,357 ) 15,520,848 Income (loss) from operations 1,863,844 (1,427,620 ) (48,535 ) — 387,689 Other income (expense) Equity in earnings of subsidiaries (1,502,243 ) (74,507 ) — 1,576,750 — Change in fair value of catalyst lease — 1,422 — — 1,422 Interest expense, net (125,715 ) (1,538 ) (2,283 ) — (129,536 ) Income (loss) before income taxes 235,886 (1,502,243 ) (50,818 ) 1,576,750 259,575 Income tax expense — — 23,689 — 23,689 Net income (loss) 235,886 (1,502,243 ) (74,507 ) 1,576,750 235,886 Less income attributable to noncontrolling interests 269 269 — (269 ) 269 Net income (loss) attributable to PBF Holding Company LLC $ 235,617 $ (1,502,512 ) $ (74,507 ) $ 1,577,019 $ 235,617 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 233,025 $ (1,502,512 ) $ (74,507 ) $ 1,577,019 $ 233,025 22. 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, expenses and other 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 Total costs, expenses and other 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 — — 648 — 648 Net income (loss) 187,942 (1,228,631 ) 73,563 1,154,420 187,294 Less 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, expenses and other 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 on sale of assets (277 ) — (618 ) — (895 ) Depreciation and amortization expense 13,583 164,525 888 — 178,996 Total costs, expenses and other 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 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 — — — — — 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 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Three Months Ended June 30, 2017 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 4,928,464 $ 134,566 $ 512,262 $ (562,041 ) $ 5,013,251 Cost and expenses: Cost of products and other 4,703,574 32,288 489,012 (562,041 ) 4,662,833 Operating expenses (excluding depreciation) (326 ) 389,889 9,007 — 398,570 General and administrative expenses 28,843 6,286 (209 ) — 34,920 Equity (income) loss in investee — — (3,820 ) — (3,820 ) Loss on sale of assets — 29 — — 29 Depreciation and amortization expense 6,019 55,077 1,897 — 62,993 4,738,110 483,569 495,887 (562,041 ) 5,155,525 Income (loss) from operations 190,354 (349,003 ) 16,375 — (142,274 ) Other income (expenses): Equity in earnings (loss) of subsidiaries (338,171 ) 1,442 — 336,729 — Change in fair value of catalyst leases — 1,104 — — 1,104 Debt extinguishment costs (25,451 ) — — — (25,451 ) Interest expense, net (32,108 ) (480 ) (269 ) — (32,857 ) Income (loss) before income taxes (205,376 ) (346,937 ) 16,106 336,729 (199,478 ) Income tax expense — — 5,898 — 5,898 Net income (loss) (205,376 ) (346,937 ) 10,208 336,729 (205,376 ) Less: net income attributable to noncontrolling interests 267 267 — (267 ) 267 Net income (loss) attributable to PBF Holding Company LLC $ (205,643 ) $ (347,204 ) $ 10,208 $ 336,996 $ (205,643 ) Comprehensive income (loss) attributable to PBF Holding Company LLC $ (205,313 ) $ (347,204 ) $ 10,208 $ 336,996 $ (205,313 ) 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Three Months Ended June 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 3,834,460 $ 95,163 $ 339,721 $ (413,571 ) $ 3,855,773 Cost and expenses: Cost of products and other 3,300,539 39,483 358,297 (413,571 ) 3,284,748 Operating expenses (excluding depreciation) (28 ) 268,608 2,959 — 271,539 General and administrative expenses 28,609 9,209 273 — 38,091 Loss on sale of assets — 24 3,198 — 3,222 Depreciation and amortization expense 1,379 45,780 1,760 — 48,919 3,330,499 363,104 366,487 (413,571 ) 3,646,519 Income (loss) from operations 503,961 (267,941 ) (26,766 ) — 209,254 Other income (expenses): Equity in earnings (loss) of subsidiaries (292,212 ) — — 292,212 — Change in fair value of catalyst leases — (1,748 ) — — (1,748 ) Interest expense, net (30,245 ) (484 ) (550 ) — (31,279 ) Income (loss) before income taxes 181,504 (270,173 ) (27,316 ) 292,212 176,227 Income tax benefit — — (5,277 ) — (5,277 ) Net income (loss) 181,504 (270,173 ) (22,039 ) 292,212 181,504 Less: net income attributable to noncontrolling interests 90 90 — (90 ) 90 Net income (loss) attributable to PBF Holding Company LLC $ 181,414 $ (270,263 ) $ (22,039 ) $ 292,302 $ 181,414 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 181,829 $ (270,263 ) $ (22,039 ) $ 292,302 $ 181,829 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Six Months Ended June 30, 2017 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 9,654,243 $ 760,335 $ 1,042,167 $ (1,693,296 ) $ 9,763,449 Cost and expenses: Cost of products and other 9,064,194 530,062 1,013,627 (1,693,296 ) 8,914,587 Operating expenses (excluding depreciation) (331 ) 819,419 16,335 — 835,423 General and administrative expenses 62,538 13,451 (590 ) — 75,399 Equity (income) loss in investee — — (7,419 ) — (7,419 ) Loss on sale of assets — 912 — — 912 Depreciation and amortization expense 7,781 107,124 3,778 — 118,683 9,134,182 1,470,968 1,025,731 (1,693,296 ) 9,937,585 Income (loss) from operations 520,061 (710,633 ) 16,436 — (174,136 ) Other income (expenses): Equity in earnings (loss) of subsidiaries (703,300 ) 3,335 — 699,965 — Change in fair value of catalyst leases — (1,484 ) — — (1,484 ) Debt extinguishment costs (25,451 ) — — — (25,451 ) Interest expense, net (62,226 ) (838 ) (449 ) — (63,513 ) Income (loss) before income taxes (270,916 ) (709,620 ) 15,987 699,965 (264,584 ) Income tax expense — — 6,332 — 6,332 Net income (loss) (270,916 ) (709,620 ) 9,655 699,965 (270,916 ) Less: net income attributable to noncontrolling interests 380 380 — (380 ) 380 Net income (loss) attributable to PBF Holding Company LLC $ (271,296 ) $ (710,000 ) $ 9,655 $ 700,345 $ (271,296 ) Comprehensive income (loss) attributable to PBF Holding Company LLC $ (270,645 ) $ (710,000 ) $ 9,655 $ 700,345 $ (270,645 ) 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (UNAUDITED) Six Months Ended June 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Revenues $ 6,630,376 $ 144,782 $ 660,441 $ (779,641 ) $ 6,655,958 Cost and expenses: Cost of products and other 5,739,927 103,453 666,992 (779,641 ) 5,730,731 Operating expenses (excluding depreciation) (400 ) 562,642 5,936 — 568,178 General and administrative expenses 57,306 16,060 (2,006 ) — 71,360 Loss on sale of assets — 24 3,198 — 3,222 Depreciation and amortization expense 3,076 96,522 3,614 — 103,212 5,799,909 778,701 677,734 (779,641 ) 6,476,703 Income (loss) from operations 830,467 (633,919 ) (17,293 ) — 179,255 Other income (expenses): Equity in earnings (loss) of subsidiaries (684,805 ) — — 684,805 — Change in fair value of catalyst leases — (4,633 ) — — (4,633 ) Interest expense, net (62,586 ) (842 ) (1,122 ) — (64,550 ) Income (loss) before income taxes 83,076 (639,394 ) (18,415 ) 684,805 110,072 Income tax expense — — 26,996 — 26,996 Net income (loss) 83,076 (639,394 ) (45,411 ) 684,805 83,076 Less: net income attributable to noncontrolling interests 393 393 — (393 ) 393 Net income (loss) attributable to PBF Holding Company LLC $ 82,683 $ (639,787 ) $ (45,411 ) $ 685,198 $ 82,683 Comprehensive income (loss) attributable to PBF Holding Company LLC $ 83,720 $ (639,787 ) $ (45,411 ) $ 685,198 $ 83,720
Condensed Consolidating Statement of Cash Flow	Year Ended December 31, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 235,886 $ (1,502,243 ) $ (74,507 ) $ 1,576,750 $ 235,886 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization 14,874 194,722 9,337 — 218,933 Stock-based compensation — 18,296 — — 18,296 Change in fair value of catalyst lease obligation — (1,422 ) — — (1,422 ) Deferred income taxes — — 19,802 — 19,802 Non-cash change in inventory repurchase obligations 29,453 — — — 29,453 Non-cash lower of cost or market inventory adjustment (521,348 ) — — — (521,348 ) Pension and other post retirement benefit costs 7,139 30,848 — — 37,987 Equity (income) loss in investee — — (5,679 ) — (5,679 ) Loss (gain) on sale of assets 2,392 150 8,832 — 11,374 Equity in earnings of subsidiaries 1,502,243 74,507 — (1,576,750 ) — Changes in operating assets and liabilities Accounts receivable (168,338 ) 3,058 4,158 — (161,122 ) Due to/from affiliates (2,031,933 ) 2,046,280 (4,626 ) — 9,721 Inventories 217,629 — 18,973 — 236,602 Prepaid expenses and other current assets (3,200 ) (2,675 ) 92 — (5,783 ) Accounts payable 163,272 41,025 7,405 1,812 213,514 Accrued expenses 531,613 (353,591 ) 49,964 — 227,986 Deferred revenue 6,858 1,438 1 — 8,297 Other assets and liabilities (5,833 ) (16,238 ) 1,193 — (20,878 ) Net cash provided by (used in) operating activities (19,293 ) 534,155 34,945 1,812 551,619 Cash flows from investing activities: Acquisition of Torrance refinery and related logistics assets (971,932 ) — — — (971,932 ) Acquisition of Chalmette refinery, net of cash acquired — (2,659 ) — — (2,659 ) Expenditures for property, plant and equipment (21,563 ) (255,434 ) (5,433 ) — (282,430 ) Expenditures for refinery turnarounds costs — (198,664 ) — — (198,664 ) Expenditures for other assets — (42,506 ) — — (42,506 ) Return on investment in subsidiaries 12,800 — — (12,800 ) — Capital contributions to subsidiaries (8,287 ) — — 8,287 — Proceeds from sale of assets 4,802 — 19,890 — 24,692 Net cash (used in) provided by investing activities (984,180 ) (499,263 ) 14,457 (4,513 ) (1,473,499 ) 22. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENT OF CASH FLOW (Continued) Cash flows from financing activities: Proceeds from parent's capital contributions — — 8,287 (8,287 ) — Contributions from PBF LLC 450,300 — — — 450,300 Distribution to parent — — (12,800 ) 12,800 — Distributions to members (139,434 ) — — — (139,434 ) Proceeds from affiliate notes payable 43,396 — — — 43,396 Repayments of affiliate notes payable (53,524 ) — — — (53,524 ) Proceeds from revolver borrowings 550,000 — — — 550,000 Repayments of revolver borrowings (200,000 ) — — — (200,000 ) Repayments of Rail Facility revolver borrowings — — (67,491 ) (67,491 ) Proceeds from PBF Rail Term Loan — — 35,000 — 35,000 Additional catalyst lease — 15,589 — — 15,589 Net cash provided by financing activities 650,738 15,589 (37,004 ) 4,513 633,836 Net increase (decrease) in cash and cash equivalents (352,735 ) 50,481 12,398 1,812 (288,044 ) Cash and equivalents, beginning of period 882,820 6,236 28,968 (3,275 ) 914,749 Cash and equivalents, end of period $ 530,085 $ 56,717 $ 41,366 $ (1,463 ) $ 626,705 22. 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 cost 7,576 19,406 — — 26,982 Gain on sale of assets (249 ) (105 ) (650 ) — (1,004 ) Equity in earnings of subsidiaries 1,154,420 — — (1,154,420 ) — Changes in operating assets and liabilities: Accounts receivable 87,689 16,124 (6,177 ) — 97,636 Due to/from affiliates (1,018,176 ) 1,133,364 (103,084 ) — 12,104 Inventories (108,751 ) (116,074 ) (47,067 ) — (271,892 ) Prepaid expense and 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 Chalmette refinery, net of cash acquired (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 ) 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 from 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 Guarantors Subsidiaries Non-Guarantors Subsidiaries Combining and Consolidated 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 Pension and other post retirement benefit costs 6,426 16,174 — — 22,600 Gain on sale of assets (277 ) — (618 ) — (895 ) Equity in earnings of subsidiaries 1,131,321 — — (1,131,321 ) — Changes in operating assets and liabilities: Accounts receivable 69,887 (17,976 ) (6,533 ) — 45,378 Due to/from affiliates (1,227,851 ) 1,328,439 (92,181 ) — 8,407 Inventories (259,352 ) 20,711 (155,390 ) — (394,031 ) Prepaid expense and 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 deferred turnarounds costs — (137,688 ) — — (137,688 ) Expenditures for other assets — (17,255 ) — — (17,255 ) Capital contributions to 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: Contributions from PBF LLC 328,664 — 44,346 (44,346 ) 328,664 Distributions to members (361,352 ) — — — (361,352 ) Proceeds from affiliate 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 Repayment 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 CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF CASH FLOW (UNAUDITED) Six Months Ended June 30, 2017 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ (270,916 ) $ (709,620 ) $ 9,655 $ 699,965 $ (270,916 ) Adjustments to reconcile net income (loss) to net cash (used in) provided by operations: Depreciation and amortization 11,596 107,430 3,823 — 122,849 Stock-based compensation — 10,134 — — 10,134 Change in fair value of catalyst leases — 1,484 — — 1,484 Deferred income taxes — — 5,123 — 5,123 Non-cash lower of cost or market inventory adjustment 167,134 — — — 167,134 Non-cash change in inventory repurchase obligations (3,107 ) — — — (3,107 ) Debt extinguishment costs 25,451 — — — 25,451 Pension and other post-retirement benefit costs 3,304 17,817 — — 21,121 (Income) from equity method investee — — (7,419 ) — (7,419 ) Distributions from equity method investee — — 12,254 — 12,254 Loss on sale of assets — 912 — — 912 Equity in earnings (loss) of subsidiaries 703,300 (3,335 ) — (699,965 ) — Changes in operating assets and liabilities: Accounts receivable 21,334 3,501 (18,714 ) — 6,121 Due to/from affiliates (1,111,279 ) 1,029,667 68,107 — (13,505 ) Inventories (141,219 ) — (37,519 ) — (178,738 ) Prepaid expense and other current assets (3,314 ) (14,716 ) (8 ) — (18,038 ) Accounts payable (120,026 ) (24,140 ) (2,116 ) 1,463 (144,819 ) Accrued expenses 178,794 (42,903 ) (29,818 ) — 106,073 Deferred revenue (6,002 ) (1,418 ) 12 — (7,408 ) Other assets and liabilities (15,218 ) (13,881 ) (11,426 ) — (40,525 ) Net cash (used in) provided by operations (560,168 ) 360,932 (8,046 ) 1,463 (205,819 ) Cash flows from investing activities: Expenditures for property, plant and equipment (287 ) (179,019 ) (269 ) — (179,575 ) Expenditures for deferred turnaround costs — (214,375 ) — — (214,375 ) Expenditures for other assets — (23,747 ) — — (23,747 ) Net cash used in investing activities (287 ) (417,141 ) (269 ) — (417,697 ) Cash flows from financing activities: Contributions from PBF LLC 97,000 — — — 97,000 Distribution to members (5,252 ) — — — (5,252 ) Proceeds from 2025 7.25% Senior Notes 725,000 — — — 725,000 Cash paid to extinguish 2020 8.25% Senior Secured Notes (690,209 ) — — — (690,209 ) Repayments of PBF Rail Term Loan — — (3,295 ) — (3,295 ) Proceeds from revolver borrowings 290,000 — — — 290,000 Repayments of revolver borrowings (290,000 ) — — — (290,000 ) Due to/from affiliates (5,453 ) 5,453 — — — Deferred financing costs and other (12,414 ) — — — (12,414 ) Net cash provided by (used in) financing activities 108,672 5,453 (3,295 ) — 110,830 Net (decrease) increase in cash and cash equivalents (451,783 ) (50,756 ) (11,610 ) 1,463 (512,686 ) Cash and cash equivalents, beginning of period 530,085 56,717 41,366 (1,463 ) 626,705 Cash and cash equivalents, end of period $ 78,302 $ 5,961 $ 29,756 $ — $ 114,019 14. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONDENSED CONSOLIDATING STATEMENT OF CASH FLOW (UNAUDITED) Six Months Ended June 30, 2016 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total Cash flows from operating activities: Net income (loss) $ 83,076 $ (639,394 ) $ (45,411 ) $ 684,805 $ 83,076 Adjustments to reconcile net income (loss) to net cash (used in) provided by operations: Depreciation and amortization 7,405 96,645 3,895 — 107,945 Stock-based compensation — 9,999 — — 9,999 Change in fair value of catalyst leases — 4,633 — — 4,633 Deferred income taxes — — 27,060 — 27,060 Non-cash lower of cost or market inventory adjustment (200,063 ) (16,780 ) — — (216,843 ) Non-cash change in inventory repurchase obligations — 26,172 — — 26,172 Pension and other post-retirement benefit costs 3,464 11,891 — — 15,355 Loss on sale of assets — 24 3,198 — 3,222 Equity in earnings of subsidiaries 684,805 — — (684,805 ) — Changes in operating assets and liabilities: Accounts receivable (190,245 ) 6,084 (6,484 ) — (190,645 ) Due to/from affiliates (838,988 ) 798,315 38,216 — (2,457 ) Inventories 91,094 (11,455 ) 2,940 — 82,579 Prepaid expense and other current assets (4,255 ) (12,365 ) 198 — (16,422 ) Accounts payable 80,299 (24,617 ) 1,030 1,930 58,642 Accrued expenses 175,598 (2,269 ) (9,082 ) — 164,247 Deferred revenue 3,767 — — — 3,767 Other assets and liabilities (10,304 ) (3,305 ) 1,087 — (12,522 ) Net cash (used in) provided by operations (114,347 ) 243,578 16,647 1,930 147,808 Cash flows from investing activities: Expenditures for property, plant and equipment (11,765 ) (98,259 ) (11 ) — (110,035 ) Expenditures for deferred turnaround costs — (106,649 ) — — (106,649 ) Expenditures for other assets — (21,325 ) — — (21,325 ) Investment in subsidiaries 12,800 — — (12,800 ) — Chalmette Acquisition working capital settlement — (2,659 ) — — (2,659 ) Proceeds from sale of assets — — 6,860 — 6,860 Net cash provided by (used in) investing activities 1,035 (228,892 ) 6,849 (12,800 ) (233,808 ) Cash flows from financing activities: Distributions to Parent — — (12,800 ) 12,800 — Distributions to members (61,667 ) — — — (61,667 ) Proceeds from affiliate notes payable 635 — — — 635 Repayment of affiliate notes payable (517 ) — — — (517 ) Repayment of Rail Facility revolver borrowings — — (6,970 ) — (6,970 ) Proceeds from revolver borrowings 550,000 — — — 550,000 Net cash provided by (used in) financing activities 488,451 — (19,770 ) 12,800 481,481 Net increase in cash and cash equivalents 375,139 14,686 3,726 1,930 395,481 Cash and cash equivalents, beginning of period 882,820 6,236 28,968 (3,275 ) 914,749 Cash and cash equivalents, end of period $ 1,257,959 $ 20,922 $ 32,694 $ (1,345 ) $ 1,310,230

DESCRIPTION OF THE BUSINESS A50

DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION (Details) $ in Thousands	May 14, 2014shares	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2017USD ($)segment	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)segment	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Sep. 01, 2016	Nov. 01, 2015
Business Acquisition, Contingent Consideration [Line Items]
Percentage of ownership in PBF LLC						100.00%
Less income attributable to noncontrolling interests		$ 267	$ 90	$ 380	$ 393	$ 269	$ 274	$ 0
Income tax expense		$ 5,898	$ (5,277)	$ 6,332	$ 26,996	$ 23,689	$ 648	$ 0
Number of Reportable Segments | segment				1		1
PBF Energy [Member] | Class A Common Stock [Member]
Business Acquisition, Contingent Consideration [Line Items]
Percentage of ownership in PBF LLC		96.60%		96.60%		96.50%	95.10%
PBF Energy Inc. [Member] | Class A Common Stock [Member]
Business Acquisition, Contingent Consideration [Line Items]
Percentage of ownership in PBF LLC						96.50%
PBF Logistics LP [Member] | Partnership [Member]
Business Acquisition, Contingent Consideration [Line Items]
Noncontrolling Interest, ownership Percentage by Parent									50.00%
PBF Logistics LP [Member] | IPO [Member] | Common Units [Member]
Business Acquisition, Contingent Consideration [Line Items]
Partners' capital account, units, sold in public offering | shares	15,812,500
MOEM Pipeline [Member] | Chalmette Refining [Member]
Business Acquisition, Contingent Consideration [Line Items]
Noncontrolling Interest, ownership Percentage by Parent										100.00%
T&M Terminal Company [Member] | Chalmette Refining [Member]
Business Acquisition, Contingent Consideration [Line Items]
Noncontrolling Interest, ownership Percentage by Parent						80.00%
Collins Pipeline Company [Member] | Chalmette Refining [Member]
Business Acquisition, Contingent Consideration [Line Items]
Noncontrolling Interest, ownership Percentage by Parent						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%			50.00%
Collins Pipeline Company And T&M Terminal Company [Member]
Business Acquisition, Contingent Consideration [Line Items]
Income tax expense						$ 1,378	$ 648

SUMMARY OF SIGNIFICANT ACCOUN51

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Concentration of Credit Risk) (Details) - USD ($)	2 Months Ended	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2016
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%
Customer Concentration Risk [Member] | ExxonMobil Oil Corporation [Member] | Accounts Receivables [Member]
Concentration Risk [Line Items]
Concentration risk percentage	18.00%

SUMMARY OF SIGNIFICANT ACCOUN52

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Property, Plant, and Equipment) (Details)	12 Months Ended
	Dec. 31, 2016
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 ACCOUN53

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Deferred Charges and Other Assets, Net) (Details)	12 Months Ended
	Dec. 31, 2016
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 ACCOUN54

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Recently Issued Accounting Pronouncements (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Deferred financing costs, net	$ 25,277	$ 32,217

ACQUISITIONS (Purchase Price) (

ACQUISITIONS (Purchase Price) (Details) - USD ($) $ in Thousands	Jul. 01, 2016	Nov. 01, 2015
Torrance Refinery [Member]
Business Acquisition [Line Items]
Gross purchase price	$ 537,500
Working capital	450,582
Post close purchase price adjustments	(16,150)
Total consideration	$ 971,932
Chalmette Refining L.L.C. [Member]
Business Acquisition [Line Items]
Cash acquired		$ 19,042
Total consideration		587,005
Working capital		245,963
Total consideration		$ 567,963

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	982
Property, plant and equipment	704,633
Deferred charges and other assets, net	68,053
Accounts payable	(2,688)
Accrued expenses	(64,137)
Other long-term liabilities	(139,453)
Fair value of net assets acquired	971,932
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
Accounts payable		(4,870)
Accrued expenses		(28,371)
Deferred tax liability		(25,721)
Noncontrolling interest		(11,821)
Fair value of net assets acquired		$ 567,963
Scenario, Previously Reported [Member] | Torrance Refinery [Member]
Business Acquisition [Line Items]
Inventories	404,542
Prepaid expenses and other current assets	1,186
Property, plant and equipment	703,443
Deferred charges and other assets, net	68,053
Accounts payable	(2,688)
Accrued expenses	(64,137)
Other long-term liabilities	(138,467)
Fair value of net assets acquired	$ 971,932

ACQUISITIONS (Pro Forma Informa

ACQUISITIONS (Pro Forma Information) (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015
Torrance Refinery [Member]
Business Acquisition [Line Items]
Pro forma revenues	$ 7,734,969	$ 16,987,548	$ 16,252,729
Pro forma net income attributable to PBF Holding Company LLC	$ (121,369)	31,565	$ (176,410)
Chalmette Refining L.L.C. [Member]
Business Acquisition [Line Items]
Pro forma revenues		16,811,922
Pro forma net income attributable to PBF Holding Company LLC		$ 397,108

ACQUISITIONS (Additional Inform

ACQUISITIONS (Additional Information) (Details) $ in Thousands	Jul. 01, 2016USD ($)refinery	Nov. 01, 2015USD ($)	Dec. 31, 2015USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)refinery	Jun. 30, 2017USD ($)	Dec. 31, 2016USD ($)	Jun. 30, 2016USD ($)refinery	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Business Acquisition [Line Items]
Number Of Operating Refineries | refinery	5				4			4
Net income				$ (205,376)	$ 181,504	$ (270,916)		$ 83,076	$ 235,886	$ 187,294	$ 21,117
Business Combination, Acquisition Related Costs				$ 94	$ 2,410	$ 466		$ 7,134	13,622
Torrance Refinery [Member]
Business Acquisition [Line Items]
Payments to acquire businesses	$ 521,350								971,932	$ 0	$ 0
Working capital	450,582
Deferred tax liability	$ 64,137
Revenues							$ 1,977,204
Net income							86,394
Chalmette Refining L.L.C. [Member]
Business Acquisition [Line Items]
Payments to acquire businesses		$ 322,000
Deferred tax liability		25,721
Working capital		245,963
Deferred tax liability		$ 28,371
Revenues			$ 643,267
Net income			$ 53,539
Business acquisition, transaction costs							$ 5,833		$ 5,833
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%
Chalmette Refining [Member] | MOEM Pipeline [Member]
Business Acquisition [Line Items]
Noncontrolling Interest, ownership Percentage by Parent		100.00%
Chalmette Refining [Member] | Collins Pipeline Company [Member]
Business Acquisition [Line Items]
Noncontrolling Interest, ownership Percentage by Parent							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 ($)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Mar. 31, 2017	Mar. 31, 2016
Inventory [Line Items]
Crude oil and feedstocks	$ 1,307,816,000		$ 1,307,816,000		$ 1,102,007,000	$ 1,137,605,000
Refined products and blendstocks	1,235,980,000		1,235,980,000		1,267,861,000	1,098,746,000
Warehouse stock and other	94,490,000		94,490,000		89,680,000	55,257,000
Inventory, Gross	2,638,286,000		2,638,286,000		2,459,548,000	2,291,608,000
Lower of cost or market adjustment	(763,122,000)	$ 900,493,000	(763,122,000)	$ 900,493,000	(595,988,000)	(1,117,336,000)	$ 690,110,000	$ 612,027,000	$ (1,058,273,000)
Total inventories	1,875,164,000		1,875,164,000		1,863,560,000	1,174,272,000
Operating Income (Loss)	142,274,000	(209,254,000)	174,136,000	(179,255,000)	(387,689,000)	(265,952,000)	(115,149,000)
Net income	(205,376,000)	181,504,000	(270,916,000)	83,076,000	235,886,000	187,294,000	$ 21,117,000
Inventory, LIFO Reserve, Effect on Income, Net					11,746,000	0
Titled Inventory [Member]
Inventory [Line Items]
Crude oil and feedstocks	1,307,816,000		1,307,816,000		1,102,007,000	1,137,605,000
Refined products and blendstocks	935,041,000		935,041,000		915,397,000	687,389,000
Warehouse stock and other	94,490,000		94,490,000		89,680,000	55,257,000
Inventory, Gross	2,337,347,000		2,337,347,000		2,107,084,000	1,880,251,000
Lower of cost or market adjustment	(650,702,000)		(650,702,000)		(492,415,000)	(966,564,000)
Total inventories	1,686,645,000		1,686,645,000		1,614,669,000	913,687,000
Inventory Supply and Offtake Arrangements [Member]
Inventory [Line Items]
Crude oil and feedstocks	0		0		0	0
Refined products and blendstocks	300,939,000		300,939,000		352,464,000	411,357,000
Warehouse stock and other	0		0		0	0
Inventory, Gross	300,939,000		300,939,000		352,464,000	411,357,000
Lower of cost or market adjustment	(112,420,000)		(112,420,000)		(103,573,000)	(150,772,000)
Total inventories	188,519,000		188,519,000		248,891,000	260,585,000
Scenario, Adjustment [Member]
Inventory [Line Items]
Operating Income (Loss)	151,095,000	157,780,000	167,134,000	(216,843,000)	$ (521,348,000)	$ 427,226,000
Net income	$ 151,095,000	$ 157,780,000	$ 167,134,000	$ 216,843,000

PROPERTY, PLANT AND EQUIPMENT60

PROPERTY, PLANT AND EQUIPMENT, NET (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Jun. 30, 2017
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 3,177,256	$ 2,558,263
Less - Accumulated depreciation	(448,557)	(347,173)
Property, plant and equipment, net	2,728,699	2,211,090		$ 2,793,029
Depreciation	104,293	88,474	$ 113,533
Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	253,110	91,256
Process units, pipelines and equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,504,008	2,209,712
Building and leasehold improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	49,020	34,265
Computers furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	81,780	72,642
Construction in progress [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	289,338	150,388
Capitalized interest	$ 8,333	3,529
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 AS61

DEFERRED CHARGES AND OTHER ASSETS, NET (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Deferred turnaround costs, net	$ 302,919	$ 177,236
Catalyst	114,788	77,725
Linefill	19,485	13,504
Restricted cash	0	1,500
Intangible assets, net	577	219
Other	14,598	9,700
Deferred charges and other assets	504,003	290,713
Amortization expense	105,547	102,636	$ 65,452
Intangible Assets, Net [Abstract]
Gross amount	3,996	3,597
Accumulated amortization	(3,419)	(3,378)
Net amount	577	219
Deferred financing costs, net	25,277	32,217
Environmental Credits	$ 51,636	$ 10,829

ACCRUED EXPENSES (Details)

ACCRUED EXPENSES (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2015
Accrued Expenses:
Inventory-related accruals	$ 778,746	$ 810,027	$ 548,800
Inventory intermediation arrangements	233,455	225,524	252,380
Renewable energy credit and emissions obligations	172,331	70,158	19,472
Excise and sales tax payable	100,998	86,046	34,129
Accrued transportation costs	83,312	89,830	91,546
Renewable energy credit and emissions obligations	75,711	33,610	7,400
Accrued refinery maintenance and support costs	32,326	28,670
Accrued utilities	28,914	44,190	25,192
Customer deposits	23,912	9,215	20,395
Environmental liabilities			2,178
Accrued salaries and benefits	15,961	17,466	61,011
Accrued interest	9,047	28,934	22,313
Environmental liabilities	8,902	8,882
Other	30,685	10,177	32,619
Accrued expenses	$ 1,594,300	1,462,729	$ 1,117,435
Scenario, Previously Reported [Member]
Accrued Expenses:
Inventory-related accruals		810,027
Inventory intermediation arrangements		225,524
Renewable energy credit and emissions obligations		70,158
Excise and sales tax payable		86,046
Accrued transportation costs		89,830
Renewable energy credit and emissions obligations		33,610
Accrued utilities		44,190
Customer deposits		9,215
Environmental liabilities		8,882
Accrued salaries and benefits		17,466
Accrued interest		28,934
Other		38,847
Accrued expenses		$ 1,462,729

LONG-TERM DEBT (Details)

LONG-TERM DEBT (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2017	May 30, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Long-term Debt	$ 1,654,158		$ 1,601,836
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt		$ 725,000
Debt fixed interest rate	7.25%
Proceeds from Debt, Net of Issuance Costs	$ 712,586
Redemption price as a percentage	100.00%
2020 Senior Secured Notes [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	8.25%
2023 Senior Secured Notes [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	7.00%

DELAWARE ECONOMIC DEVELOPMENT64

DELAWARE ECONOMIC DEVELOPMENT AUTHORITY LOAN (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Jun. 30, 2010
Debt Instrument [Line Items]
Delaware Economic Development Authority loan	$ 0	$ 4,000,000	$ 20,000,000
Annual conversion of loan to grant	$ 4,000,000
Term of loan conversion	5 years

CREDIT FACILITY AND LONG-TERM65

CREDIT FACILITY AND LONG-TERM DEBT (Details)

Dec. 22, 2016USD ($)

Nov. 24, 2015USD ($)

Feb. 09, 2012USD ($)

Oct. 31, 2012USD ($)

Dec. 31, 2016USD ($)

Jun. 30, 2017USD ($)

Nov. 24, 2016

Dec. 31, 2015USD ($)

Nov. 30, 2015USD ($)

Jun. 30, 2015

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

Long-term Debt, Gross

1,601,836,000

$ 1,268,937,000

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

Long-term Line of Credit

350,000,000

0

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

411,997,000

351,511,000

Line of Credit [Member] | Rail Facility [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

0

67,491,000

Notes Payable to Banks [Member]

Debt Instrument [Line Items]

Long-term Debt, Gross

35,000,000

0

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 Debt, Gross

[1]

669,644,000

Long-term Line of Credit

350,000,000

$ 350,000,000

0

2023 Senior Secured Notes [Member]

Debt Instrument [Line Items]

Debt issued

$ 500,000,000

Debt fixed interest rate

7.00%

0.25%

Interest Expense, Debt

$ 127,000

Proceeds from Debt, Net of Issuance Costs

$ 490,000,000

Long-term Debt, Gross

[2]

500,000,000

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

Debt Instrument [Line Items]

Debt fixed interest rate

2.20%

Facility fee

$ 140,000

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

Debt Instrument [Line Items]

Debt fixed interest rate

1.99%

Facility fee

$ 331,000

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

Debt Instrument [Line Items]

Debt fixed interest rate

1.95%

Facility fee

$ 210,000

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

Debt Instrument [Line Items]

Debt fixed interest rate

2.05%

Facility fee

$ 30,000

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

Debt Instrument [Line Items]

Debt fixed interest rate

3.85%

Facility fee

$ 185,000

Financing Arrangements [Member] | Chalmette Catalyst Lease 2019 [Member]

Debt Instrument [Line Items]

Debt fixed interest rate

2.20%

Facility fee

$ 171,000

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

Debt Instrument [Line Items]

Debt fixed interest rate

1.78%

Facility fee

$ 143,000

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

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 250,000,000

PBF Rail Logistics Company LLC [Member] | Notes Payable to Banks [Member]

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 35,000,000

Debt instrument, term

5 years

Long-term Debt, Gross

$ 35,000,000

Long-term Line of Credit

$ 0

PBF Logistics LP [Member] | Notes Payable to Banks [Member] | LIBOR [Member]

Debt Instrument [Line Items]

Basis spread on variable rate

2.00%

[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.

CREDIT FACILITY AND LONG-TERM66

CREDIT FACILITY AND LONG-TERM DEBT (Summary of Long-Term Debt) (Details) - USD ($)

Nov. 24, 2015

Jun. 30, 2017

Dec. 31, 2016

Dec. 22, 2016

Nov. 24, 2016

Dec. 31, 2015

Nov. 30, 2015

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

$ 1,626,743,000

1,576,559,000

$ 1,236,720,000

Long-term Debt, Gross

1,601,836,000

1,268,937,000

Deferred financing costs, net

25,277,000

32,217,000

Less—Current maturities

0

0

0

Total long-term debt

1,576,559,000

1,236,720,000

2023 Senior Secured Notes [Member]

Debt Instrument [Line Items]

Long-term debt

500,000,000

Revolving Credit Facility [Member]

Debt Instrument [Line Items]

Long-term debt

350,000,000

0

Notes Payable to Banks [Member]

Debt Instrument [Line Items]

Long-term Debt, Gross

35,000,000

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

Long-term Line of Credit

350,000,000

0

Line of Credit [Member] | Rail Facility [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

0

67,491,000

Catalyst Lease Obligation [Member]

Debt Instrument [Line Items]

Long-term debt

45,969,000

Long-term Debt, Gross

[1]

31,802,000

Capital Lease Obligations [Member]

Debt Instrument [Line Items]

Long-term debt

31,802,000

Senior Secured Notes [Member]

Debt Instrument [Line Items]

Debt Instrument, Face Amount

$ 675,500,000

Long-term debt

670,867,000

669,644,000

Long-term Debt, Gross

[2]

669,644,000

Long-term Line of Credit

350,000,000

350,000,000

0

Debt fixed interest rate

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

Long-term Debt, Gross

[3]

500,000,000

Debt fixed interest rate

7.00%

0.25%

PBF Rail Logistics Company LLC [Member] | Notes Payable to Banks [Member]

Debt Instrument [Line Items]

Line of Credit Facility, Maximum Borrowing Capacity

$ 35,000,000

Long-term Debt, Gross

35,000,000

Long-term Line of Credit

$ 0

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

Debt Instrument [Line Items]

Line of Credit Facility, Maximum Borrowing Capacity

$ 250,000,000

Paulsboro Catalyst Lease [Member] | Capital Lease Obligations [Member]

Debt Instrument [Line Items]

Debt Instrument, Fee Amount

$ 140,000

Debt fixed interest rate

2.20%

Delaware City Catalyst Lease [Member] | Capital Lease Obligations [Member]

Debt Instrument [Line Items]

Debt Instrument, Fee Amount

$ 210,000

Debt fixed interest rate

1.95%

Toledo Catalyst Lease [Member] | Capital Lease Obligations [Member]

Debt Instrument [Line Items]

Debt Instrument, Fee Amount

$ 331,000

Debt fixed interest rate

1.99%

Chalmette Catalyst Lease [Member] | Capital Lease Obligations [Member]

Debt Instrument [Line Items]

Debt Instrument, Fee Amount

$ 185,000

Debt fixed interest rate

3.85%

[1]

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.

[2]

The estimated fair value, categorized as a Level 2 measurement, was calculated based on the present value of future expected payments utilizing implied current market interest rates based on quoted prices of the Senior Secured Notes.

[3]

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.

CREDIT FACILITY AND LONG-TERM67

CREDIT FACILITY AND LONG-TERM DEBT (Debt Maturities) (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Long-term Debt, Fiscal Year Maturity [Abstract]
2,016		$ 9,798
2,017		4,941
2,018		381,230
2,019		670,867
2,020		35,000
Thereafter		500,000
Long-term Debt	$ 1,654,158	$ 1,601,836

AFFILIATE NOTES PAYABLE (Detail

AFFILIATE NOTES PAYABLE (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Affiliate notes payable	$ 0	$ 86,298	$ 470,047
Conversion of affiliate notes payable to capital contribution	$ 86,298	$ 379,947	$ 0	$ 0
Notes Payable [Member]
Debt Instrument [Line Items]
Debt fixed interest rate	2.50%
Debt instrument, term	5 years

INTERCOMPANY NOTE PAYABLE (Deta

INTERCOMPANY NOTE PAYABLE (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Affiliate notes payable	$ 0	$ 86,298	$ 470,047
Conversion of affiliate notes payable to capital contribution	$ 86,298	$ 379,947	$ 0	$ 0
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	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2015
Other Long-Term Liabilities [Abstract]
Other long-term liabilities	$ 223,106	$ 226,111	$ 69,824
PBF Holding [Member]
Other Long-Term Liabilities [Abstract]
Defined benefit pension plan liabilities		60,007	42,509
Post-retirement medical plan liabilities		22,740	17,729
Environmental liabilities		142,935	8,189
Other		429	1,397
Other long-term liabilities		$ 226,111	$ 69,824

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details)

Nov. 01, 2017bblrenewal

Feb. 28, 2017USD ($)

Feb. 15, 2017renewal

Nov. 01, 2016bbl / d

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

May 01, 2016bbl / d

Apr. 29, 2016bbl / dterminal

May 15, 2015renewal

May 14, 2015bbl / d

Dec. 11, 2014bbl / dbblrenewal

Oct. 01, 2014bbl / d

Sep. 30, 2014renewal

May 14, 2014bbl / drenewal

Jan. 24, 2013bbl

Sep. 01, 2011

Jun. 30, 2017USD ($)

Mar. 31, 2017

Jun. 30, 2016USD ($)

Jun. 30, 2017USD ($)renewal

Dec. 31, 2016USD ($)

Jun. 30, 2016USD ($)

Dec. 31, 2016USD ($)renewal

Dec. 31, 2015USD ($)

Dec. 31, 2014USD ($)

Sep. 01, 2016

Related Party Transaction [Line Items]

Number of Contract Renewals | renewal

2

2

Term of Renewal

5 years

5 years

Investment in equity method investee | $

$ 174,047,000

$ 174,047,000

$ 179,882,000

$ 179,882,000

$ 0

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

Related Party Transaction [Line Items]

Distributions to Series B Unitholders | $

6,152,000

19,592,000

$ 130,523

PBFX Operating Company LP [Member]

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction | $

11,600,000

Fuel Strategies International, Inc, [Member]

Related Party Transaction [Line Items]

Charges incurred during period | $

0

0

588,000

Executive Chairman of the Board of Directors [Member]

Related Party Transaction [Line Items]

Charges incurred during period | $

824,000

957,000

1,214,000

Consulting Agreement [Member] | Former Board of Directors Chairman [Member]

Related Party Transaction [Line Items]

Charges incurred during period | $

500,000

Related Party, Annual Fee | $

$ 900,000

900,000

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

Related Party Transaction [Line Items]

Related Party Transaction, Annual Fee | $

$ 4,000,000

6,900,000

Torrance Valley Pipeline Transportation Services Agreement [Member]

Related Party Transaction [Line Items]

Number of Contract Renewals | renewal

2

Term of Renewal

5 years

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

Related Party Transaction [Line Items]

Related Party Transaction, Notice Of Withdrawal Period

30 days

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

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

Related Party Transaction [Line Items]

Related Party Transaction, Annual Fee | $

$ 6,386,000

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

Related Party Transaction [Line Items]

Related Party Transaction, Annual Fee | $

$ 6,700,000

6,696,000

Partnership [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Noncontrolling Interest, ownership Percentage by Parent

50.00%

Toledo Tank Farm [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

4,400

Oil And Gas Plant, Maximum Storage Capacity | bbl

3,849,271

Toledo Terminaling Agreement [Member]

Related Party Transaction [Line Items]

Term of Agreement

7 years 8 months

Number of Contract Renewals | renewal

2

Term of Renewal

5 years

DCR Terminaling Agreement [Member]

Related Party Transaction [Line Items]

Term of Agreement

7 years 8 months

Number of Contract Renewals | renewal

2

Term of Renewal

5 years

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

Related Party Transaction [Line Items]

Number Of Refined Product Terminals Acquired | terminal

4

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

15,000

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

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

15,000

Oil And Gas Plant, Maximum Storage Capacity | bbl

350,000

Torrance Valley Pipeline Transportation Services Agreement [Member]

Related Party Transaction [Line Items]

Term of Agreement

10 years

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

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

50,000

Delaware City Pipeline Services Agreement [Member]

Related Party Transaction [Line Items]

Term of Agreement

10 years 8 months

Number of Contract Renewals | renewal

2

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 3 months

Number of Contract Renewals | renewal

2

Term of Renewal

5 years

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

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

5,500

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

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

85,000

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

40,000

Delaware Truck Loading Services Agreement [Member]

Related Party Transaction [Line Items]

Term of Agreement

10 years 8 months

Number of Contract Renewals | renewal

2

Term of Renewal

5 years

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

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

50,000

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

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

70,000

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

Related Party Transaction [Line Items]

Oil And Gas Plant, Maximum Storage Capacity | bbl

55,000

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

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

770,000

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

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

900,000

Chalmette Land Lease [Member]

Related Party Transaction [Line Items]

Term of Agreement

20 years

Number of Contract Renewals | renewal

2

Term of Renewal

10 years

Delaware City Products Pipeline - Magellan [Member]

Related Party Transaction [Line Items]

Term of Agreement

2 years 5 months

Delaware City Products Pipeline - Magellan [Member] | Delaware City Pipeline Services Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

14,500

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

Related Party Transaction [Line Items]

Term of Agreement

15 years

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

Related Party Transaction [Line Items]

Term of Agreement

1 year

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

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction | $

58,355,000

$ 37,965,000

114,557,000

$ 74,514,000

175,448,000

142,102,000

59,403,000

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

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction | $

1,630,000

1,415,000

3,284,000

2,259,000

5,121,000

4,533,000

2,298,000

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

Related Party Transaction [Line Items]

Related Party Transaction, Amounts of Transaction | $

$ 1,661,000

$ 1,121,000

$ 3,279,000

$ 2,243,000

$ 4,805,000

$ 5,297,000

$ 3,600,000

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

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

30,000

LPGs [Member] | Delaware City Truck Rack [Member] | Delaware City Terminaling Services Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Collaborative Agreement, Minimum Throughput Capacity

5,000

Torrance Valley Pipeline Company [Member]

Related Party Transaction [Line Items]

Noncontrolling Interest, ownership Percentage by Parent

50.00%

50.00%

50.00%

50.00%

50.00%

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

Related Party Transaction [Line Items]

Term of Agreement

1 year

3 months

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

Related Party Transaction [Line Items]

Term of Agreement

5 years

5 years

Subsequent Event [Member] | Chalmette Storage Agreement [Member]

Related Party Transaction [Line Items]

Term of Agreement

10 years

Number of Contract Renewals | renewal

2

Term of Renewal

5 years

Scenario, Forecast [Member] | Chalmette Storage Tank [Member] | Chalmette Storage Agreement [Member] | PBF Logistics LP [Member]

Related Party Transaction [Line Items]

Oil And Gas Plant, Maximum Storage Capacity | bbl

625,000

COMMITMENTS AND CONTINGENCIES72

COMMITMENTS AND CONTINGENCIES (Details) gallon in Millions

Mar. 10, 2017USD ($)

Feb. 15, 2017

Feb. 14, 2017USD ($)

Jan. 24, 2017action

Jan. 13, 2017group

Jul. 01, 2016USD ($)

Mar. 03, 2014ppm

Mar. 01, 2011

Feb. 03, 2011USD ($)

Feb. 28, 2017USD ($)

Nov. 30, 2016

Jun. 30, 2017USD ($)

Jun. 30, 2017USD ($)ppm

Dec. 31, 2016USD ($)ppm

Dec. 31, 2015USD ($)

Dec. 31, 2014USD ($)shipmentgallonlocation

Dec. 31, 2010ppm

Commitments and Contingencies Disclosure [Abstract]

Rent expense

$ 129,768,000

$ 126,060,000

$ 98,473,000

Inventory purchases

53,364,000

36,139,000

$ 40,444,000

Loss Contingencies [Line Items]

Non-cancelable operating lease term

20 years

Environmental Matters

Environmental liabilities

2,178,000

Restricted cash for environmental liabilities

$ 0

$ 1,500,000

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%

Number Of Days Barge Shipments Made

15 days

PBF Energy [Member] | Class A Common Stock [Member]

Environmental Matters

Percentage of ownership in PBF LLC

96.60%

96.60%

96.50%

95.10%

Environmental Issue [Member]

Environmental Matters

Environmental liabilities

$ 11,117,000

$ 11,117,000

$ 10,792,000

$ 10,367,000

Discount rate used for environmental liability assessment

8.00%

8.00%

8.00%

Undiscounted liability

$ 16,655,000

Expected future payments

$ 6,591,000

Expected payment period

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

Loss Contingency, Number Of Environmental Groups Appealing Permits | group

2

Environmental Issue [Member] | PBF Energy and Valero [Member]

Environmental Matters

Term of insurance policies

10 years

10 years

Site Contingency, Loss Exposure Not Accrued, Best Estimate

$ 75,000,000

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 liabilities

$ 139,827,000

139,827,000

142,456,000

Expected future payments

$ 35,677,000

Site Contingency, Loss Exposure in Excess of Accrual, Best Estimate

$ 100,000

Term of insurance policies

10 years

Site Contingency, Loss Exposure Not Accrued, Best Estimate

100,000,000

Cellulosic Standard [Member]

Environmental Matters

Renewable Fuels Standard Requirements Increase

135.00%

Advanced Renewable Identification Number Requirements [Member]

Environmental Matters

Renewable Fuels Standard Requirements Increase

7.00%

Total Renewable Identification Number Requirements [Member]

Environmental Matters

Renewable Fuels Standard Requirements Increase

3.00%

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

Maximum [Member] | Environmental Issue [Member] | Valero [Member]

Environmental Matters

Site Contingency, Loss Exposure Not Accrued, Best Estimate

$ 20,000,000

$ 20,000,000

Maximum [Member] | Environmental Issue [Member] | Torrance Refinery [Member]

Environmental Matters

Litigation Settlement, Amount

$ 100,000

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

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

Torrance Refinery [Member] | Environmental Issue [Member]

Environmental Matters

Payments to acquire environmental insurance policies

$ 100,000,000

Pending Litigation [Member] | New Jersey Department Of Environmental Protection Vs. Paulsboro refinery [Member] | Environmental Remediation Contingency [Domain] | Paulsboro Refining Company LLC [Member]

Environmental Matters

Loss Contingency, Damages Sought, Value

$ 313,000

Pending Litigation [Member] | New Jersey Department Of Environmental Protection Vs. Paulsboro refinery [Member] | Supplemental Environmental Project [Member] | Paulsboro Refining Company LLC [Member]

Environmental Matters

Loss Contingency, Damages Sought, Value

153,000

Pending Litigation [Member] | New Jersey Department Of Environmental Protection Vs. Paulsboro refinery [Member] | Balance Payable Upon Unfavorable Regulatory Action [Member] | Paulsboro Refining Company LLC [Member]

Environmental Matters

Loss Contingency, Damages Sought, Value

160,000

Pending Litigation [Member] | Louisiana Department of Environmental Quality [Member] | Environmental Remediation Contingency [Domain]

Environmental Matters

Loss Contingency, Damages Sought, Value

$ 700,000

Pending Litigation [Member] | DNREC [Member] | Environmental Remediation Contingency [Domain]

Environmental Matters

Loss Contingency, Damages Sought, Value

$ 150

Number Of Barge Shipments | shipment

17

Number Of Violated Locations | location

3

Number Of Gallons Of Crude Oil | gallon

35.7

Pending Litigation [Member] | Clean Air Act [Member] | Environmental Remediation Contingency [Domain]

Environmental Matters

Loss Contingency, Damages Sought, Value

$ 180,000

Subsequent Event [Member] | Environmental Issue [Member]

Environmental Matters

Loss Contingency, Number Of Environmental Groups Appealing Permits | group

2

Loss Contingency, Number Of Enforcement Actions Taken | action

2

Subsequent Event [Member] | Chalmette Refinery [Member] | Environmental Issue [Member]

Environmental Matters

Environmental Exit Costs, Anticipated Cost

$ 700,000

Subsequent Event [Member] | Pending Litigation [Member] | New Jersey Department Of Environmental Protection Vs. Paulsboro refinery [Member] | Environmental Remediation Contingency [Domain] | Paulsboro Refining Company LLC [Member]

Environmental Matters

Loss Contingency, Damages Sought, Value

313,000

Subsequent Event [Member] | Pending Litigation [Member] | New Jersey Department Of Environmental Protection Vs. Paulsboro refinery [Member] | Supplemental Environmental Project [Member] | Paulsboro Refining Company LLC [Member]

Environmental Matters

Loss Contingency, Damages Sought, Value

153,000

Subsequent Event [Member] | Pending Litigation [Member] | New Jersey Department Of Environmental Protection Vs. Paulsboro refinery [Member] | Balance Payable Upon Unfavorable Regulatory Action [Member] | Paulsboro Refining Company LLC [Member]

Environmental Matters

Loss Contingency, Damages Sought, Value

$ 160,000

COMMITMENTS AND CONTINGENCIES73

COMMITMENTS AND CONTINGENCIES (Future Minimum Rental Payments) (Details) $ in Thousands	Dec. 31, 2016USD ($)
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2,016	$ 156,699
2,017	139,440
2,018	115,482
2,019	101,503
2,020	59,305
Thereafter	185,875
Total future obligation payments due	$ 758,304

EQUITY STRUCTURE (Additional In

EQUITY STRUCTURE (Additional Information) (Details)	12 Months Ended
	Dec. 31, 2016USD ($)vote / sharesshares	Dec. 31, 2015USD ($)
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%
T&M Terminal Company [Member] | Chalmette Refining [Member]
Class of Stock [Line Items]
Noncontrolling Interest, ownership Percentage by Parent	80.00%
Noncontrolling Interest [Member]
Class of Stock [Line Items]
Net income | $	$ 269,000	$ 274,000

STOCK-BASED COMPENSATION (Share

STOCK-BASED COMPENSATION (Share-Based Compensation Expense) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
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	$ 10,577
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	32,719
General and Administrative Expense [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated share-based compensation expense	$ 18,296	$ 9,218	$ 6,095
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	0	522
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	11,020	7,528	4,343
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	7,276	$ 1,690	$ 1,230
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	11,676
Total intrinsic value of stock options exercisable	$ 3,914

STOCK-BASED COMPENSATION (Sha76

STOCK-BASED COMPENSATION (Share-Based Compensation Activity) (Details) - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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	0	24,000
Options
Options, beginning balance	640,779	801,479	841,079
Exercised	(27,833)	(160,700)	(32,934)
Forfeited			(6,666)
Options, ending balance	612,946	640,779	801,479	841,079
Weighted Average Exercise Price
Weighted average exercise price, beginning balance	$ 10.59	$ 10.53	$ 10.52
Exercised	10	10.28	10
Forfeited			11.59
Weighted average exercise price, ending balance	$ 10.62	$ 10.59	$ 10.53	$ 10.52
Weighted average remaining contractual term, outstanding	4 years 5 months 20 days	5 years 5 months 15 days	6 years 4 months 28 days	7 years 4 months 24 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	612,946	640,779	753,985
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price	$ 10.62	$ 10.59	$ 10.41
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Term	4 years 5 months 20 days	5 years 5 months 15 days	5 years 5 months 15 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Number	612,946
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price	$ 10.62
Weighted average remaining contractual term, expected to vest	4 years 5 months 20 days
PBF Energy Inc. [Member]
Options
Options, beginning balance	4,256,375	2,401,875	1,320,000
Granted	1,792,000	1,899,500	1,135,000
Exercised	(11,250)	(30,000)	0
Forfeited	(66,500)	(15,000)	(53,125)
Options, ending balance	5,970,625	4,256,375	2,401,875	1,320,000
Weighted Average Exercise Price
Weighted average exercise price, beginning balance	$ 27.89	$ 25.97	$ 26.97
Granted	26.18	30.28	24.78
Exercised	25.86	25.79	0
Forfeited	28.74	26.38	25.44
Weighted average exercise price, ending balance	$ 27.37	$ 27.89	$ 25.97	$ 26.97
Weighted average remaining contractual term, outstanding	8 years 7 days	8 years 3 months 25 days	8 years 8 months 2 days	9 years 3 months 29 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	2,271,375	1,136,250	485,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price	$ 27.23	$ 26.22	$ 26.66
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Term	7 years 2 months 15 days	7 years 7 months 11 days	8 years 2 months 16 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Number	5,970,625
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price	$ 27.37
Weighted average remaining contractual term, expected to vest	8 years 7 days

STOCK-BASED COMPENSATION (Weigh

STOCK-BASED COMPENSATION (Weighted Average Assumptions) (Details) - PBF Energy Inc. [Member] - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
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	39.70%	38.40%	52.00%
Dividend yield	4.73%	3.96%	4.82%
Risk-free rate of return	1.42%	1.58%	1.80%
Exercise price	$ 26.18	$ 30.28	$ 24.78

STOCK-BASED COMPENSATION (Addit

STOCK-BASED COMPENSATION (Additional Information) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
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	$ 10,577,000
Total intrinsic value of stock options exercised during period	461,000	$ 3,452,000	$ 618,000
Unrecognized compensation expense	$ 0	$ 0
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	0	24,000
Non-compensatory warrants outstanding	32,719	32,719
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]
Vesting rights percentage	33.30%
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	$ 5,000	$ 133,000
Parent Company [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted in period	360,820	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	1,792,000	1,899,500	1,135,000
Expiration period	10 years
PBF Energy Inc. [Member] | Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total estimated fair value, granted in period	$ 11,346,000	$ 14,512,000
Weighted average fair value per unit	$ 6.33	$ 7.64
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value	$ 11,676,000
Total intrinsic value of stock options exercisable	3,914,000
Unrecognized compensation expense	$ 21,323,000

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		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Accumulated Benefit Obligation								$ 108,838	$ 80,897
Pension Benefits [Member]
Change in benefit obligation:
Benefit obligation at beginning of year			$ 135,508	$ 100,011	$ 100,011	$ 81,098
Service cost	$ 10,144	$ 7,339	20,287	14,679	36,359	24,298	$ 19,407
Interest cost	1,084	775	2,168	1,551	3,096	2,974	2,404
Plan amendments					0	0
Benefit payments					(3,449)	(2,231)
Actuarial loss (gain)					(509)	(6,128)
Projected benefit obligation at end of year					135,508	100,011	81,098
Change in plan assets:
Fair value of plan assets at beginning of year			75,367	57,502	57,502	40,956
Actual return on plan assets					3,995	(13)
Benefits paid					(3,449)	(2,231)
Employer contributions					17,319	18,790
Fair value of plan assets at end of year					75,367	57,502	40,956
Reconciliation of funded status:
Fair value of plan assets at end of year			75,367	57,502	57,502	40,956	40,956	75,367	57,502
Less benefit obligation at end of year			135,508	100,011	100,011	81,098	81,098	135,508	100,011
Funded status at end of year								(60,141)	(42,509)
Post Retirement Medical Plan [Member]
Change in benefit obligation:
Benefit obligation at beginning of year			22,740	17,729	17,729	14,740
Service cost	316	219	632	439	1,047	967	1,099
Interest cost	$ 172	$ 133	344	267	528	558	520
Plan amendments					2,524	1,533
Benefit payments					(575)	(381)
Actuarial loss (gain)					1,487	312
Projected benefit obligation at end of year					22,740	17,729	14,740
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					(575)	(381)
Employer contributions					575	381
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			$ 22,740	$ 17,729	$ 17,729	$ 14,740	$ 14,740	22,740	17,729
Funded status at end of year								$ (22,740)	$ (17,729)

EMPLOYEE BENEFIT PLANS (Expecte

EMPLOYEE BENEFIT PLANS (Expected Benefit Payments) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	$ 36,300
2,016	12,307
2,017	8,873
2,018	11,027
2,019	13,067
2,020	16,079
Year 2021 - 2024	114,382
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
2,016	1,202
2,017	1,389
2,018	1,653
2,019	1,910
2,020	2,018
Year 2021 - 2024	$ 10,438

EMPLOYEE BENEFIT PLANS (Net Per

EMPLOYEE BENEFIT PLANS (Net Periodic Benefit Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year					$ 36,300
Service cost	$ 10,144	$ 7,339	$ 20,287	$ 14,679	36,359	$ 24,298	$ 19,407
Interest cost	1,084	775	2,168	1,551	3,096	2,974	2,404
Expected return on plan assets	(1,442)	(1,107)	(2,884)	(2,213)	(4,681)	(3,422)	(2,156)
Amortization of prior service costs	13	13	26	26	53	53	39
Amortization of loss	113	194	226	388	1,043	1,228	1,033
Net periodic benefit cost	9,912	7,214	19,823	14,431	35,870	25,131	20,727
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	316	219	632	439	1,047	967	1,099
Interest cost	172	133	344	267	528	558	520
Expected return on plan assets					0	0	0
Amortization of prior service costs	161	109	322	218	541	326	258
Amortization of loss	0	0	0	0	0	0	(4)
Net periodic benefit cost	$ 649	$ 461	$ 1,298	$ 924	$ 2,116	$ 1,851	$ 1,873

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, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service costs (credits)	$ 0	$ 0	$ 529
Net actuarial loss (gain)	176	(2,220)	8,151
Amortization of loss	(1,096)	(1,281)	(1,072)
Total changes in other comprehensive loss (income)	(920)	(3,501)	7,608
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service costs (credits)	2,524	1,533	3,911
Net actuarial loss (gain)	1,487	312	1,201
Amortization of loss	(541)	(326)	(255)
Total changes in other comprehensive loss (income)	$ 3,470	$ 1,519	$ 4,857

EMPLOYEE BENEFIT PLANS (Pre-t83

EMPLOYEE BENEFIT PLANS (Pre-tax Amounts in AOCI Not Yet Recognized as Components of Net Periodic Costs) (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service (costs) credits	$ (476)	$ (529)
Net actuarial (loss) gain	(18,975)	(19,841)
Total	(19,451)	(20,370)
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service (costs) credits	(5,983)	(3,999)
Net actuarial (loss) gain	(1,878)	(391)
Total	$ (7,861)	$ (4,390)

EMPLOYEE BENEFIT PLANS (Pre-t84

EMPLOYEE BENEFIT PLANS (Pre-tax Amounts in AOCI to be Recognized Over Next Fiscal Year) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service costs (credits)	$ (53)
Amortization of net actuarial loss (gain)	(452)
Total	(505)
Post Retirement Medical Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service costs (credits)	(646)
Amortization of net actuarial loss (gain)	0
Total	$ (646)

EMPLOYEE BENEFIT PLANS (Assumpt

EMPLOYEE BENEFIT PLANS (Assumptions Used) (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits [Member]
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate	4.07%	4.17%
Rate of compensation increase	4.81%	4.81%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Expected long-term rate of return on plan assets	7.00%	7.00%	6.70%
Rate of compensation increase	4.81%	4.81%	4.64%
Supplemental Employee Retirement Plan [Member]
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate	4.08%	4.22%
Rate of compensation increase	5.50%	5.50%
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Rate of compensation increase	5.50%	5.50%	4.64%
Post Retirement Medical Plan [Member]
Weighted Average Assumptions Used to Determine Benefit Obligations
Discount rate	3.68%	3.76%
Rate of compensation increase	0.00%	0.00%
Service Cost [Member] | Pension Benefits [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	4.15%	4.25%	4.55%
Service Cost [Member] | Supplemental Employee Retirement Plan [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	4.17%	4.30%	4.55%
Service Cost [Member] | Post Retirement Medical Plan [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	4.10%	4.32%	4.55%
Effective rate for interest cost [Member] | Pension Benefits [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	3.38%	3.31%	4.55%
Effective rate for interest cost [Member] | Supplemental Employee Retirement Plan [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	3.20%	3.16%	4.55%
Effective rate for interest cost [Member] | Post Retirement Medical Plan [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	3.11%	3.09%	4.55%
Effective rate for interest on service cost [Member] | Pension Benefits [Member]
Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Discount rate	3.59%	3.51%	4.55%
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	3.63%	3.37%	4.55%
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	3.84%	4.04%	4.55%

EMPLOYEE BENEFIT PLANS (Assumed

EMPLOYEE BENEFIT PLANS (Assumed Health Care Cost Trend Rates) (Details) - Post Retirement Medical Plan [Member]	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	6.10%	6.10%
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	2,038

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, 2016USD ($)
Defined Benefit Plan Disclosure [Line Items]
Effect on total of service and interest cost components, 1% increase	$ 14
Effect on total of service and interest cost components, 1% decrease	(13)
Effect on accumulated postretirement benefit obligation, 1% increase	388
Effect on accumulated postretirement benefit obligation, 1% decrease	$ (367)

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, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$ 75,367	$ 57,502	$ 40,956
Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	75,367	57,502
Level 1 [Member] | Domestic Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	23,451	17,660
Level 1 [Member] | Developed International Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	10,736	8,320
Level 1 [Member] | Emerging Market Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	5,164	4,017
Level 1 [Member] | Global Low Volatility Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	6,360	4,930
Level 1 [Member] | Fixed-Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	29,576	22,495
Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$ 80	$ 80

EMPLOYEE BENEFIT PLANS (Additio

EMPLOYEE BENEFIT PLANS (Additional Information) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Maximum age to receive health care coverage	65 years
Defined Benefit Plan, Accumulated Benefit Obligation	$ 108,838	$ 80,897
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	$ 19,746	$ 12,753	$ 11,364
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	$ 36,300
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		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Product Information [Line Items]
Revenues	$ 5,013,251	$ 3,855,773	$ 9,763,449	$ 6,655,958	$ 15,908,537	$ 13,123,929	$ 19,828,155
Gasoline and Distillates [Member]
Product Information [Line Items]
Revenues					14,017,350	11,553,716	17,050,096
Asphalt and blackoils [Member]
Product Information [Line Items]
Revenues					699,966	536,496	706,494
Chemicals [Member]
Product Information [Line Items]
Revenues					554,392	452,304	739,096
Other [Member]
Product Information [Line Items]
Revenues					376,471	315,042	922,003
Lubricants [Member]
Product Information [Line Items]
Revenues					$ 260,358	$ 266,371	$ 410,466

INCOME TAXES Income Tax (Detail

INCOME TAXES Income Tax (Details) $ in Thousands	3 Months Ended				6 Months Ended		12 Months Ended
	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015subsidiary	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Income Tax [Line Items]
Number Of Subsidiaries Acquired | subsidiary				2
Current tax expense (benefit)	$ 737	$ 299			$ 1,209	$ (64)
Deferred income taxes	5,161	(5,576)			5,123	27,060	$ 19,802	$ 0	$ 0
Total tax expense (benefit)	$ 5,898	$ (5,277)			$ 6,332	26,996	23,689	648	$ 0
Collins Pipeline Company And T&M Terminal Company [Member]
Income Tax [Line Items]
Total tax expense (benefit)							1,378	$ 648
PBF Energy Limited [Member]
Income Tax [Line Items]
Deferred income taxes							$ 8,412
Restatement Adjustment [Member] | Prior Period Error Correction [Member] | PBF Energy Limited [Member]
Income Tax [Line Items]
Current tax expense (benefit)			$ 30,602			30,602
Deferred income taxes			121			$ 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	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2015
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$ 9,599	$ 9,440	$ 9,325
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		6,058
Derivative, Collateral, Obligation to Return Cash		0
Derivative Asset		6,058
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
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		6,058
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
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	14,002	4,491	52,482
Derivative, Collateral, Right to Reclaim Cash	(14,002)	(983)	(52,482)
Derivative Liability	0	3,508	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	9,720	859	49,960
Derivative Liability		859
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	4,282	3,548	2,522
Derivative Liability		3,548
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	84	0
Derivative Liability		84
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	47,454	45,969	31,802
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	47,454	45,969	31,802
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	14,284	342,837	631,280
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	14,284	342,837	631,280
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	33,332	983	98,609
Derivative, Collateral, Obligation to Return Cash	(14,002)	(983)	(52,482)
Derivative Asset	19,330	0	46,127
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	32,291	948	63,810
Derivative Asset		948
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	1,041	35	31,256
Derivative Asset		35
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	0	0	3,543
Derivative Asset		0
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	9,165	6,058	35,511
Derivative, Collateral, Obligation to Return Cash	0	0	0
Derivative Asset	9,165	6,058	35,511
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	9,165		35,511
Derivative Asset		6,058
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				6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Mar. 31, 2016	Mar. 31, 2015	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015
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	0	1,915,000	3,543,000	$ 1,521,000	(84,000)	3,543,000	$ 3,543,000	$ 1,521,000
Purchases	0	0			0	0	0	0
Settlements	0	(746,000)			45,000	(1,003,000)	(1,149,000)	(15,222,000)
Unrealized (gain) loss included in earnings	0	(676,000)			39,000	(2,047,000)	(2,478,000)	17,244,000
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	$ 0	$ 493,000	$ 1,915,000		$ 0	$ 493,000	$ (84,000)	$ 3,543,000

FAIR VALUE MEASUREMENTS (Fair V

FAIR VALUE MEASUREMENTS (Fair Value and Carrying Value of Debt) (Details) - USD ($)		Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		$ 1,654,158,000	$ 1,601,836,000
Long-term Debt, Gross			1,601,836,000	$ 1,268,937,000
Long-term debt, Fair value		1,624,341,000	1,625,868,000	1,297,991,000
Less - Current maturities		0	0	0
Less - Current maturities, Fair value		0	0	0
Unamortized Debt Issuance Expense		27,415,000	25,277,000	32,217,000
Long-term debt		1,626,743,000	1,576,559,000	1,236,720,000
Long-term debt, Fair value		1,624,341,000	1,625,868,000	1,297,991,000
Senior secured notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		0	670,867,000
Long-term Debt, Gross	[1]			669,644,000
Long-term debt, Fair value		0	696,098,000	706,246,000	[1]
Long-term Line of Credit		350,000,000	350,000,000	0
Lines of Credit, Fair Value Disclosure		350,000,000	350,000,000	0
Long-term debt			670,867,000	669,644,000
Notes Payable to Banks [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Gross			35,000,000	0
2023 Senior Secured Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Gross	[2]			500,000,000
Long-term debt, Fair value		495,543,000	498,801,000	492,452,000
Long-term debt		500,000,000	500,000,000
2025 Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, Fair value		699,640,000	0
Long-term debt		725,000,000	0
Rail Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Line of Credit		31,704,000	35,000,000
Lines of Credit, Fair Value Disclosure		31,704,000	35,000,000
Catalyst lease [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt		47,454,000	45,969,000
Long-term Debt, Gross	[3]			31,802,000
Long-term debt, Fair value		47,454,000	45,969,000	31,802,000	[3]
Long-term debt			45,969,000
Revolving Credit Facility [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt			350,000,000	0
Revolving Credit Facility [Member] | Line of Credit [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Line of Credit			350,000,000	0
Rail Facility [Member] | Line of Credit [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Line of Credit			0	67,491,000
Lines of Credit, Fair Value Disclosure			0	67,491,000
Catalyst lease [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Obligations, Fair Value Disclosure		47,454,000	45,969,000	31,802,000
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		$ 47,454,000	45,969,000	31,802,000
PBF Rail Logistics Company LLC [Member] | Notes Payable to Banks [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Gross			35,000,000
Long-term Line of Credit				0
Lines of Credit, Fair Value Disclosure			$ 35,000,000	$ 0
[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		6 Months Ended		12 Months Ended
	Jun. 30, 2017USD ($)bbl	Jun. 30, 2016USD ($)	Jun. 30, 2017USD ($)bbl	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)bbl	Dec. 31, 2015USD ($)bbl
Derivative [Line Items]
Gain (loss) on fair value hedge ineffectiveness | $	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0
Crude Oil and Feedstock Inventory [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume					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
Intermediates and Refined Products Inventory [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume					0	0
Intermediates and Refined Products Inventory [Member] | Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, notional amount, volume	3,005,137		3,005,137		2,942,348
Intermediates and Refined Products Inventory [Member] | Fair Value Hedging [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume					2,942,348	3,776,011
Crude Oil Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	10,566,000		10,566,000		5,950,000	39,577,000
Refined Product Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, notional amount, volume	8,732,000		8,732,000		2,831,000	4,599,136

DERIVATIVES (Fair Value of Deri

DERIVATIVES (Fair Value of Derivative Instruments) (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2015
Designated as Hedging Instrument [Member] | Inventory Intermediation Agreement Obligation [Member] | Accrued Expenses [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	$ 9,165	$ 6,058	$ 35,511
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Accrued Expenses [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)			$ 46,127
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Accounts Receivable [Member]
Derivatives, Fair Value [Line Items]
Fair Value Asset/(Liability)	$ 19,330	$ 3,508

DERIVATIVES (Gain (Loss) Recogn

DERIVATIVES (Gain (Loss) Recognized in Income) (Details) - Cost of Sales [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Designated as Hedging Instrument [Member] | Inventory Supply Arrangement Obligation [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives					$ 0	$ (4,251)	$ 4,428
Designated as Hedging Instrument [Member] | Inventory Intermediation Agreement Obligation [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	$ (20,017)	$ 8,973	$ 3,107	$ (26,172)	(29,453)	(59,323)	88,818
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					0	4,251	(4,428)
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	20,017	(8,973)	(3,107)	26,172	29,453	59,323	(88,818)
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain or (Loss) Recognized in Income on Derivatives	$ 14,293	$ (19,134)	$ 14,684	$ (39,087)	$ (55,557)	$ 32,416	$ 146,016

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - USD ($) $ / shares in Units, $ in Thousands	Feb. 28, 2017	Feb. 15, 2017	Oct. 28, 2016	Aug. 31, 2016	Feb. 11, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Subsequent Event [Line Items]
Storage Service Agreement, Term		10 years
Payments of Capital Distribution						$ 5,252	$ 61,667	$ 139,434	$ 350,658	$ 361,352
Non-cancelable operating lease term		20 years
Stockholders' Equity, Capital Distributions								$ 139,434	$ 350,658	$ 361,352
PBF Energy Inc. [Member] | Class A Common Stock [Member]
Subsequent Event [Line Items]
Dividends declared per share					$ 0.30
Subsequent Event [Member] | PBF Energy [Member] | Class A Common Stock [Member]
Subsequent Event [Line Items]
Dividends declared per share			$ 0.3
Stockholders' Equity, Capital Distributions			$ 34,100
PBF LLC [Member] | Fourth Amended and Restated O&M Agreement [Member]
Subsequent Event [Line Items]
Related Party Transaction, Annual Fee				$ 6,386
PBF LLC [Member] | Fifth Amended and Restated O&M Agreement [Member]
Subsequent Event [Line Items]
Related Party Transaction, Annual Fee	$ 6,700					$ 6,696

CONSOLIDATING FINANCIAL STATE99

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Narrative) (Details)	6 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2016	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%	50.00%

CONSOLIDATING FINANCIAL STAT100

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Balance Sheet) (Details) - USD ($)	Jun. 30, 2017	Dec. 31, 2016	Jun. 30, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Jun. 30, 2010
Current assets:
Cash and cash equivalents	$ 114,019,000	$ 626,705,000	$ 1,310,230,000	$ 914,749,000	$ 218,403,000	$ 76,970,000
Accounts receivable	609,760,000	615,881,000		454,759,000
Accounts receivable - affiliate	26,489,000	7,631,000		3,438,000
Affiliate notes receivable	11,600,000	0
Inventories	1,875,164,000	1,863,560,000		1,174,272,000
Prepaid expense and other current assets	58,370,000	40,536,000		33,701,000
Due from related parties	0	0		0
Total current assets	2,695,402,000	3,154,313,000		2,580,919,000
Property, plant and equipment, net	2,793,029,000	2,728,699,000		2,211,090,000
Investment in subsidiaries	0	0		0
Investment in equity method investee	174,047,000	179,882,000		0
Deferred charges and other assets, net	811,281,000	504,003,000		290,713,000
Due from related party - long term				0
Total assets	6,473,759,000	6,566,897,000		5,082,722,000
Current liabilities:
Accounts payable	437,640,000	530,365,000		314,843,000
Accounts payable - affiliate		37,863,000		23,949,000
Accounts payable	31,409,000	37,863,000		23,949,000
Accrued expenses	1,594,300,000	1,462,729,000		1,117,435,000
Current portion of long-term debt	0	0		0
Deferred revenue	4,932,000	12,340,000		4,043,000
Due to related parties	0	0		0
Total current liabilities	2,068,281,000	2,043,297,000		1,460,270,000
Delaware Economic Development Authority loan		0		4,000,000			$ 20,000,000
Long-term debt	1,626,743,000	1,576,559,000		1,236,720,000
Affiliate notes payable	0	86,298,000		470,047,000
Deferred tax liabilities	50,822,000	45,699,000		20,577,000
Other long-term liabilities	223,106,000	226,111,000		69,824,000
Due to related party - long term		0		0
Total liabilities	3,968,952,000	3,977,964,000		3,261,438,000
Commitments and contingencies
Equity:
Member's equity	2,349,357,000	2,155,863,000		1,479,175,000
Retained earnings	167,868,000	446,519,000		349,654,000
Accumulated other comprehensive loss	(25,311,000)	(25,962,000)		(24,770,000)
Total PBF Holding Company LLC equity	2,491,914,000	2,576,420,000		1,804,059,000
Noncontrolling interest	12,893,000	12,513,000		17,225,000
Total equity	2,504,807,000	2,588,933,000		1,821,284,000	1,630,516,000	1,772,153,000
Total liabilities and equity	6,473,759,000	6,566,897,000		5,082,722,000
Issuer [Member]
Current assets:
Cash and cash equivalents	78,302,000	530,085,000	1,257,959,000	882,820,000	185,381,000	76,179,000
Accounts receivable	577,813,000	599,147,000		430,809,000
Accounts receivable - affiliate	1,461,000	2,432,000		917,000
Affiliate notes receivable	0
Inventories	1,654,143,000	1,680,058,000		608,646,000
Prepaid expense and other current assets	30,759,000	27,443,000		24,243,000
Due from related parties	26,546,381,000	24,141,120,000		20,236,649,000
Total current assets	28,888,859,000	26,980,285,000		22,184,084,000
Property, plant and equipment, net	25,896,000	33,772,000		25,240,000
Investment in subsidiaries	7,524,000	705,034,000		1,740,111,000
Investment in equity method investee	0	0
Deferred charges and other assets, net	30,571,000	12,317,000		23,973,000
Due from related party - long term				0
Total assets	28,952,850,000	27,731,408,000		23,973,408,000
Current liabilities:
Accounts payable	240,234,000	360,260,000		196,988,000
Accounts payable - affiliate				23,949,000
Accounts payable	31,347,000	37,077,000
Accrued expenses	1,316,523,000	1,094,581,000		503,179,000
Deferred revenue	4,899,000	10,901,000		4,043,000
Due to related parties	23,277,244,000	22,027,065,000		19,787,807,000
Total current liabilities	24,870,247,000	23,529,884,000		20,515,966,000
Delaware Economic Development Authority loan		0		0
Long-term debt	1,548,024,000	1,496,085,000		1,137,980,000
Affiliate notes payable		86,298,000		470,047,000
Deferred tax liabilities	0	0		0
Other long-term liabilities	29,772,000	30,208,000		28,131,000
Due to related party - long term		0		0
Total liabilities	26,448,043,000	25,142,475,000		22,152,124,000
Commitments and contingencies
Equity:
Member's equity	2,349,357,000	2,155,863,000		1,479,175,000
Retained earnings	167,868,000	446,519,000		349,654,000
Accumulated other comprehensive loss	(25,311,000)	(25,962,000)		(24,770,000)
Total PBF Holding Company LLC equity	2,491,914,000	2,576,420,000		1,804,059,000
Noncontrolling interest	12,893,000	12,513,000		17,225,000
Total equity	2,504,807,000	2,588,933,000		1,821,284,000
Total liabilities and equity	28,952,850,000	27,731,408,000		23,973,408,000
Guarantors Subsidiaries [Member]
Current assets:
Cash and cash equivalents	5,961,000	56,717,000	20,922,000	6,236,000	704,000	791,000
Accounts receivable	4,498,000	7,999,000		11,057,000
Accounts receivable - affiliate	24,428,000	4,504,000		2,521,000
Affiliate notes receivable	11,600,000
Inventories	0	0		363,151,000
Prepaid expense and other current assets	27,443,000	12,933,000		9,074,000
Due from related parties	22,526,098,000	21,883,569,000		20,547,503,000
Total current assets	22,600,028,000	21,965,722,000		20,939,542,000
Property, plant and equipment, net	2,527,179,000	2,452,877,000		1,960,066,000
Investment in subsidiaries	431,662,000	440,377,000		143,349,000
Investment in equity method investee	0	0
Deferred charges and other assets, net	780,710,000	491,673,000		265,240,000
Due from related party - long term				0
Total assets	26,339,579,000	25,350,649,000		23,308,197,000
Current liabilities:
Accounts payable	185,231,000	157,277,000		113,564,000
Accounts payable - affiliate				0
Accounts payable	159,000	786,000
Accrued expenses	141,382,000	201,935,000		495,842,000
Deferred revenue	20,000	1,438,000		0
Due to related parties	25,761,022,000	24,031,520,000		21,026,310,000
Total current liabilities	26,087,814,000	24,392,956,000		21,635,716,000
Delaware Economic Development Authority loan		0		4,000,000
Long-term debt	47,406,000	45,908,000		31,717,000
Affiliate notes payable		0		0
Deferred tax liabilities	0	0		0
Other long-term liabilities	189,189,000	192,204,000		41,693,000
Due to related party - long term		0		20,577,000
Total liabilities	26,324,409,000	24,631,068,000		21,733,703,000
Commitments and contingencies
Equity:
Member's equity	1,720,206,000	1,714,997,000		1,062,717,000
Retained earnings	(1,709,693,000)	(999,693,000)		502,788,000
Accumulated other comprehensive loss	(8,236,000)	(8,236,000)		(8,236,000)
Total PBF Holding Company LLC equity	2,277,000	707,068,000		1,557,269,000
Noncontrolling interest	12,893,000	12,513,000		17,225,000
Total equity	15,170,000	719,581,000		1,574,494,000
Total liabilities and equity	26,339,579,000	25,350,649,000		23,308,197,000
Non-Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	29,756,000	41,366,000	32,694,000	28,968,000	34,334,000	0
Accounts receivable	27,449,000	8,735,000		12,893,000
Accounts receivable - affiliate	600,000	695,000		0
Affiliate notes receivable	0
Inventories	221,021,000	183,502,000		202,475,000
Prepaid expense and other current assets	168,000	160,000		384,000
Due from related parties	5,683,279,000	4,692,799,000		3,262,382,000
Total current assets	5,962,273,000	4,927,257,000		3,507,102,000
Property, plant and equipment, net	239,954,000	242,050,000		225,784,000
Investment in subsidiaries	0	0		0
Investment in equity method investee	174,047,000	179,882,000
Deferred charges and other assets, net	0	13,000		1,500,000
Due from related party - long term				20,577,000
Total assets	6,376,274,000	5,349,202,000		3,754,963,000
Current liabilities:
Accounts payable	12,175,000	14,291,000		7,566,000
Accounts payable - affiliate				0
Accounts payable	(97,000)	0
Accrued expenses	136,395,000	166,213,000		118,414,000
Deferred revenue	13,000	1,000		0
Due to related parties	5,717,492,000	4,658,903,000		3,232,417,000
Total current liabilities	5,865,978,000	4,839,408,000		3,358,397,000
Delaware Economic Development Authority loan		0		0
Long-term debt	31,313,000	34,566,000		67,023,000
Affiliate notes payable		0		0
Deferred tax liabilities	50,822,000	45,699,000		20,577,000
Other long-term liabilities	4,145,000	3,699,000		0
Due to related party - long term		0		0
Total liabilities	5,952,258,000	4,923,372,000		3,445,997,000
Commitments and contingencies
Equity:
Member's equity	362,598,000	374,067,000		182,696,000
Retained earnings	61,418,000	51,763,000		126,270,000
Accumulated other comprehensive loss	0	0		0
Total PBF Holding Company LLC equity	424,016,000	425,830,000		308,966,000
Noncontrolling interest	0	0		0
Total equity	424,016,000	425,830,000		308,966,000
Total liabilities and equity	6,376,274,000	5,349,202,000		3,754,963,000
Combining and Consolidated Adjustments [Member]
Current assets:
Cash and cash equivalents	0	(1,463,000)	$ (1,345,000)	(3,275,000)	$ (2,016,000)	$ 0
Accounts receivable	0	0		0
Accounts receivable - affiliate	0	0		0
Affiliate notes receivable	0
Inventories	0	0		0
Prepaid expense and other current assets	0	0		0
Due from related parties	(54,755,758,000)	(50,717,488,000)		(44,046,534,000)
Total current assets	(54,755,758,000)	(50,718,951,000)		(44,049,809,000)
Property, plant and equipment, net	0	0		0
Investment in subsidiaries	(439,186,000)	(1,145,411,000)		(1,883,460,000)
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	(55,194,944,000)	(51,864,362,000)		(45,953,846,000)
Current liabilities:
Accounts payable	0	(1,463,000)		(3,275,000)
Accounts payable - affiliate				0
Accounts payable	0	0
Accrued expenses	0	0		0
Deferred revenue	0	0		0
Due to related parties	(54,755,758,000)	(50,717,488,000)		(44,046,534,000)
Total current liabilities	(54,755,758,000)	(50,718,951,000)		(44,049,809,000)
Delaware Economic Development Authority loan		0		0
Long-term debt	0	0		0
Affiliate notes payable		0		0
Deferred tax liabilities	0	0		0
Other long-term liabilities	0	0		0
Due to related party - long term		0		(20,577,000)
Total liabilities	(54,755,758,000)	(50,718,951,000)		(44,070,386,000)
Commitments and contingencies
Equity:
Member's equity	(2,082,804,000)	(2,089,064,000)		(1,245,413,000)
Retained earnings	1,648,275,000	947,930,000		(629,058,000)
Accumulated other comprehensive loss	8,236,000	8,236,000		8,236,000
Total PBF Holding Company LLC equity	(426,293,000)	(1,132,898,000)		(1,866,235,000)
Noncontrolling interest	(12,893,000)	(12,513,000)		(17,225,000)
Total equity	(439,186,000)	(1,145,411,000)		(1,883,460,000)
Total liabilities and equity	$ (55,194,944,000)	$ (51,864,362,000)		$ (45,953,846,000)

CONSOLIDATING FINANCIAL STAT101

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Statement of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Income Statements, Captions [Line Items]
Revenues	$ 5,013,251	$ 3,855,773	$ 9,763,449	$ 6,655,958	$ 15,908,537	$ 13,123,929	$ 19,828,155
Cost, expenses and other
Cost of sales, excluding depreciation	4,662,833	3,284,748	8,914,587	5,730,731	13,765,088	11,611,599	18,514,054
Operating expenses, excluding depreciation	398,570	271,539	835,423	568,178	1,390,582	889,368	880,701
General and administrative expenses	34,920	38,091	75,399	71,360	149,643	166,904	140,150
Equity (income) loss in investee	(3,820)	0	(7,419)	0	(5,679)	0	0
Loss on sale of assets	29	3,222	912	3,222	11,374	(1,004)	(895)
Depreciation and amortization expense	62,993	48,919	118,683	103,212	209,840	191,110	178,996
Total cost and expenses	5,155,525	3,646,519	9,937,585	6,476,703	15,520,848	12,857,977	19,713,006
Income from operations	(142,274)	209,254	(174,136)	179,255	387,689	265,952	115,149
Other income (expense)
Equity in earnings (loss) of subsidiaries	0	0	0	0	0	0	0
Change in fair value of catalyst leases	1,104	(1,748)	(1,484)	(4,633)	1,422	10,184	3,969
Interest expense, net	(32,857)	(31,279)	(63,513)	(64,550)	(129,536)	(88,194)	(98,001)
Debt extinguishment costs	(25,451)	0	(25,451)	0
Acquisition related costs							3,969
Income before income taxes	(199,478)	176,227	(264,584)	110,072	259,575	187,942	21,117
Income tax expense	5,898	(5,277)	6,332	26,996	23,689	648	0
Net income	(205,376)	181,504	(270,916)	83,076	235,886	187,294	21,117
Less income attributable to noncontrolling interests	267	90	380	393	269	274	0
Net income attributable to PBF Holding Company LLC	(205,643)	181,414	(271,296)	82,683	235,617	187,020	21,117
Comprehensive income (loss) attributable to PBF Holding Company LLC	(205,313)	181,829	(270,645)	83,720	233,025	189,126	8,779
Issuer [Member]
Condensed Income Statements, Captions [Line Items]
Revenues	4,928,464	3,834,460	9,654,243	6,630,376	15,808,556	13,085,122	19,847,045
Cost, expenses and other
Cost of sales, excluding depreciation	4,703,574	3,300,539	9,064,194	5,739,927	13,813,293	11,514,115	18,467,533
Operating expenses, excluding depreciation	(326)	(28)	(331)	(400)	41	(3,683)	218
General and administrative expenses	28,843	28,609	62,538	57,306	123,150	143,580	123,692
Equity (income) loss in investee	0		0		0
Loss on sale of assets	0	0	0	0	2,392	(249)	(277)
Depreciation and amortization expense	6,019	1,379	7,781	3,076	5,836	9,687	13,583
Total cost and expenses	4,738,110	3,330,499	9,134,182	5,799,909	13,944,712	11,663,450	18,604,749
Income from operations	190,354	503,961	520,061	830,467	1,863,844	1,421,672	1,242,296
Other income (expense)
Equity in earnings (loss) of subsidiaries	(338,171)	(292,212)	(703,300)	(684,805)	(1,502,243)	(1,154,420)	(1,131,321)
Change in fair value of catalyst leases	0	0	0	0	0	0
Interest expense, net	(32,108)	(30,245)	(62,226)	(62,586)	(125,715)	(79,310)	(89,858)
Debt extinguishment costs	(25,451)		(25,451)
Acquisition related costs							0
Income before income taxes	(205,376)	181,504	(270,916)	83,076	235,886	187,942	21,117
Income tax expense	0	0	0	0	0	0	0
Net income	(205,376)	181,504	(270,916)	83,076	235,886	187,942	21,117
Less income attributable to noncontrolling interests	267	90	380	393	269	274	0
Net income attributable to PBF Holding Company LLC	(205,643)	181,414	(271,296)	82,683	235,617	187,668	21,117
Comprehensive income (loss) attributable to PBF Holding Company LLC	(205,313)	181,829	(270,645)	83,720	233,025	189,774	8,779
Guarantors Subsidiaries [Member]
Condensed Income Statements, Captions [Line Items]
Revenues	134,566	95,163	760,335	144,782	800,647	884,930	1,402,253
Cost, expenses and other
Cost of sales, excluding depreciation	32,288	39,483	530,062	103,453	649,242	1,026,846	1,522,901
Operating expenses, excluding depreciation	389,889	268,608	819,419	562,642	1,356,572	891,534	880,339
General and administrative expenses	6,286	9,209	13,451	16,060	27,602	21,016	16,259
Equity (income) loss in investee	0		0		0
Loss on sale of assets	29	24	912	24	150	(105)	0
Depreciation and amortization expense	55,077	45,780	107,124	96,522	194,701	178,578	164,525
Total cost and expenses	483,569	363,104	1,470,968	778,701	2,228,267	2,117,869	2,584,024
Income from operations	(349,003)	(267,941)	(710,633)	(633,919)	(1,427,620)	(1,232,939)	(1,181,771)
Other income (expense)
Equity in earnings (loss) of subsidiaries	1,442	0	3,335	0	(74,507)	0	0
Change in fair value of catalyst leases	1,104	(1,748)	(1,484)	(4,633)	1,422	10,184	3,969
Interest expense, net	(480)	(484)	(838)	(842)	(1,538)	(5,876)	(6,225)
Debt extinguishment costs	0		0
Income before income taxes	(346,937)	(270,173)	(709,620)	(639,394)	(1,502,243)	(1,228,631)	(1,184,027)
Income tax expense	0	0	0	0	0	0	0
Net income	(346,937)	(270,173)	(709,620)	(639,394)	(1,502,243)	(1,228,631)	(1,184,027)
Less income attributable to noncontrolling interests	267	90	380	393	269	274	0
Net income attributable to PBF Holding Company LLC	(347,204)	(270,263)	(710,000)	(639,787)	(1,502,512)	(1,228,905)	(1,184,027)
Comprehensive income (loss) attributable to PBF Holding Company LLC	(347,204)	(270,263)	(710,000)	(639,787)	(1,502,512)	(1,228,905)	(1,194,031)
Non-Guarantor Subsidiaries [Member]
Condensed Income Statements, Captions [Line Items]
Revenues	512,262	339,721	1,042,167	660,441	1,524,691	1,633,818	1,007,407
Cost, expenses and other
Cost of sales, excluding depreciation	489,012	358,297	1,013,627	666,992	1,527,910	1,550,579	952,170
Operating expenses, excluding depreciation	9,007	2,959	16,335	5,936	33,969	1,517	144
General and administrative expenses	(209)	273	(590)	(2,006)	(1,109)	2,308	199
Equity (income) loss in investee	(3,820)		(7,419)		(5,679)
Loss on sale of assets	0	3,198	0	3,198	8,832	(650)	(618)
Depreciation and amortization expense	1,897	1,760	3,778	3,614	9,303	2,845	888
Total cost and expenses	495,887	366,487	1,025,731	677,734	1,573,226	1,556,599	952,783
Income from operations	16,375	(26,766)	16,436	(17,293)	(48,535)	77,219	54,624
Other income (expense)
Equity in earnings (loss) of subsidiaries	0	0	0	0	0	0	0
Change in fair value of catalyst leases	0	0	0	0	0	0
Interest expense, net	(269)	(550)	(449)	(1,122)	(2,283)	(3,008)	(1,918)
Debt extinguishment costs	0		0
Acquisition related costs							0
Income before income taxes	16,106	(27,316)	15,987	(18,415)	(50,818)	74,211	52,706
Income tax expense	5,898	(5,277)	6,332	26,996	23,689	648	0
Net income	10,208	(22,039)	9,655	(45,411)	(74,507)	73,563	52,706
Less income attributable to noncontrolling interests	0	0	0	0	0	0	0
Net income attributable to PBF Holding Company LLC	10,208	(22,039)	9,655	(45,411)	(74,507)	73,563	52,706
Comprehensive income (loss) attributable to PBF Holding Company LLC	10,208	(22,039)	9,655	(45,411)	(74,507)	73,563	52,706
Combining and Consolidated Adjustments [Member]
Condensed Income Statements, Captions [Line Items]
Revenues	(562,041)	(413,571)	(1,693,296)	(779,641)	(2,225,357)	(2,479,941)	(2,428,550)
Cost, expenses and other
Cost of sales, excluding depreciation	(562,041)	(413,571)	(1,693,296)	(779,641)	(2,225,357)	(2,479,941)	(2,428,550)
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
Loss 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	(562,041)	(413,571)	(1,693,296)	(779,641)	(2,225,357)	(2,479,941)	(2,428,550)
Income from operations	0	0	0	0	0	0	0
Other income (expense)
Equity in earnings (loss) of subsidiaries	336,729	292,212	699,965	684,805	1,576,750	1,154,420	1,131,321
Change in fair value of catalyst leases	0	0	0	0	0	0
Interest expense, net	0	0	0	0	0	0	0
Debt extinguishment costs	0		0
Acquisition related costs							0
Income before income taxes	336,729	292,212	699,965	684,805	1,576,750	1,154,420	1,131,321
Income tax expense	0	0	0	0	0	0	0
Net income	336,729	292,212	699,965	684,805	1,576,750	1,154,420	1,131,321
Less income attributable to noncontrolling interests	(267)	(90)	(380)	(393)	(269)	(274)	0
Net income attributable to PBF Holding Company LLC	336,996	292,302	700,345	685,198	1,577,019	1,154,694	1,131,321
Comprehensive income (loss) attributable to PBF Holding Company LLC	$ 336,996	$ 292,302	$ 700,345	$ 685,198	$ 1,577,019	$ 1,154,694	$ 1,141,325

CONSOLIDATING FINANCIAL STAT102

CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDINGS (Statement of Cash Flows) (Details) - USD ($) $ in Thousands	Jul. 01, 2016	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Dec. 31, 2016	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash flows from operating activities:
Net income		$ (205,376)	$ 181,504	$ (270,916)		$ 83,076	$ 235,886	$ 187,294	$ 21,117
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization				122,849		107,945	218,933	199,383	186,412
Stock-based compensation				10,134		9,999	18,296	9,218	6,095
Change in fair value of catalyst lease obligation				1,484		4,633	(1,422)	(10,184)	(3,969)
Deferred income taxes		5,161	(5,576)	5,123		27,060	19,802	0	0
Non-cash lower of cost or market inventory adjustment				167,134		(216,843)	(521,348)	427,226	690,110
Non-cash change inventory repurchase obligations				(3,107)		26,172	29,453	63,389	(93,246)
Debt extinguishment costs		25,451	0	25,451		0
Pension and other post retirement benefits costs				21,121		15,355	37,987	26,982	22,600
Equity (income) loss in investee		(3,820)	0	(7,419)		0	(5,679)	0	0
Distributions from equity method investee				12,254		0
Loss (gain) on sale of assets				912		3,222	11,374	(1,004)	(895)
Loss (gain) on sale of assets		29	3,222	912		3,222	11,374	(1,004)	(895)
Equity in earnings (loss) of subsidiaries		0	0	0		0	0	0	0
Changes in operating assets and liabilities:
Accounts receivable				6,121		(190,645)	(161,122)	97,636	45,378
Due to/from affiliates							9,721	12,104	8,407
Due to/from affiliates				(13,505)		(2,457)
Inventories				(178,738)		82,579	236,602	(271,892)	(394,031)
Prepaid expense and other current assets				(18,038)		(16,422)	(5,783)	(631)	23,686
Accounts payable				(144,819)		58,642	213,514	(25,015)	(67,111)
Accrued expenses				106,073		164,247	227,986	(37,737)	59,899
Deferred revenue				(7,408)		3,767	8,297	2,816	(6,539)
Other assets and liabilities				(40,525)		(12,522)	(20,878)	(27,182)	(2,225)
Net cash provided by operations				(205,819)		147,808	551,619	652,403	495,688
Cash flows from investing activities:
Expenditures for property, plant and equipment				(179,575)		(110,035)	(282,430)	(352,365)	(470,460)
Expenditures for deferred turnaround costs				(214,375)		(106,649)	(198,664)	(53,576)	(137,688)
Expenditures for other assets				(23,747)		(21,325)	(42,506)	(8,236)	(17,255)
Investment in subsidiaries						0			0
Capital contributions to subsidiaries								0
Chalmette Acquisition working capital settlement				0		(2,659)
Proceeds from sale of assets				0		6,860	24,692	168,270	202,654
Net cash used in investing activities				(417,697)		(233,808)	(1,473,499)	(811,211)	(422,749)
Cash flows from financing activities:
Additional catalyst lease							15,589	0	0
Contributions from PBF LLC				(97,000)		0	(450,300)		(328,664)
Distribution to Parent						0	0	0
Distribution to members				(5,252)		(61,667)	(139,434)	(350,658)	(361,352)
Proceeds from affiliate notes payable				0		635	43,396	347,783	90,631
Repayments of affiliate notes payable				0		(517)	(53,524)	0	0
Proceeds from revolver borrowings				290,000		550,000	550,000	170,000	395,000
Contributions from PBF LLC							450,300	345,000	328,664
Repayments of revolver borrowings				(290,000)		0	(200,000)	(170,000)	(410,000)
Payment of Financing and Stock Issuance Costs				(12,414)
Business Combination, Payment of Contingent Consideration						(6,970)
Proceeds from Rail Facility revolver borrowings							0	102,075	83,095
Repayments of Rail Facility revolver borrowings							(67,491)	(71,938)	(45,825)
Proceeds from 2023 Senior Secured Notes							0	500,000	0
Deferred financing costs				(12,414)		0	0	(17,108)	(11,719)
Net cash provided by financing activities				110,830		481,481	633,836	855,154	68,494
Net increase (decrease) in cash and cash equivalents				(512,686)		395,481	(288,044)	696,346	141,433
Cash and equivalents, beginning of period	$ 1,310,230			626,705	$ 1,310,230	914,749	914,749	218,403	76,970
Cash and equivalents, end of period		114,019	1,310,230	114,019	626,705	1,310,230	626,705	914,749	218,403
PBF Holding [Member]
Cash flows from operating activities:
Net income							235,886	187,294
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization							218,933	199,383
Stock-based compensation							18,296	9,218
Change in fair value of catalyst lease obligation							(1,422)	(10,184)
Non-cash lower of cost or market inventory adjustment							(521,348)	427,226
Non-cash change inventory repurchase obligations							29,453	63,389
Pension and other post retirement benefits costs							37,987	26,982
Loss (gain) on sale of assets							11,374	(1,004)
Equity in earnings (loss) of subsidiaries							0	0
Changes in operating assets and liabilities:
Accounts receivable							(161,122)	97,636
Due to/from affiliates							9,721	12,104
Inventories							236,602	(271,892)
Prepaid expense and other current assets							(5,783)	(631)
Accounts payable							213,514	(25,015)
Accrued expenses							227,986	(37,737)
Deferred revenue							8,297	2,816
Other assets and liabilities							(20,878)	(27,182)
Net cash provided by operations							551,619	652,403
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired							(2,659)
Expenditures for property, plant and equipment							(282,430)	(352,365)
Expenditures for deferred turnaround costs							(198,664)	(53,576)
Expenditures for other assets							(42,506)	(8,236)
Investment in subsidiaries							0	0
Capital contributions to subsidiaries							0
Proceeds from sale of assets							24,692	168,270
Net cash used in investing activities							(1,473,499)	(811,211)
Cash flows from financing activities:
Distribution to members							(139,434)	(350,658)
Proceeds from affiliate notes payable							43,396	347,783
Proceeds from revolver borrowings							550,000	170,000
Contributions from PBF LLC							0	345,000
Repayments of revolver borrowings							(200,000)	(170,000)
Increase (Decrease) in Due to Other Related Parties				0
Proceeds from Rail Facility revolver borrowings								102,075
Repayments of Rail Facility revolver borrowings							(67,491)	(71,938)
Deferred financing costs								(17,108)
Net cash provided by financing activities							633,836	855,154
Net increase (decrease) in cash and cash equivalents							(288,044)	696,346
Cash and equivalents, beginning of period				626,705		914,749	914,749	218,403
Cash and equivalents, end of period					626,705		626,705	914,749	218,403
Issuer [Member]
Cash flows from operating activities:
Net income		(205,376)	181,504	(270,916)		83,076	235,886	187,942	21,117
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization				11,596		7,405	14,874	17,063	20,334
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		0	0
Non-cash lower of cost or market inventory adjustment				167,134		(200,063)	(521,348)	279,785	566,412
Non-cash change inventory repurchase obligations				(3,107)		0	29,453	0	0
Debt extinguishment costs		25,451		25,451
Pension and other post retirement benefits costs				3,304		3,464	7,139	7,576	6,426
Equity (income) loss in investee		0		0			0
Distributions from equity method investee				0
Loss (gain) on sale of assets				0		0	2,392	(249)	(277)
Loss (gain) on sale of assets		0	0	0		0	2,392	(249)	(277)
Equity in earnings (loss) of subsidiaries		338,171	292,212	703,300		684,805	1,502,243	1,154,420	1,131,321
Changes in operating assets and liabilities:
Accounts receivable				21,334		(190,245)	(168,338)	87,689	69,887
Due to/from affiliates							(2,031,933)	(1,018,176)	(1,227,851)
Due to/from affiliates				(1,111,279)		(838,988)
Inventories				(141,219)		91,094	217,629	(108,751)	(259,352)
Prepaid expense and other current assets				(3,314)		(4,255)	(3,200)	2,721	22,287
Accounts payable				(120,026)		80,299	163,272	(38,609)	(71,821)
Accrued expenses				178,794		175,598	531,613	27,925	(131,903)
Deferred revenue				(6,002)		3,767	6,858	2,816	(6,539)
Other assets and liabilities				(15,218)		(10,304)	(5,833)	(423)	(1,966)
Net cash provided by operations				(560,168)		(114,347)	(19,293)	601,729	138,075
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired							0
Expenditures for property, plant and equipment				(287)		(11,765)	(21,563)	(193,898)	(152,814)
Expenditures for deferred turnaround costs				0		0	0	0	0
Expenditures for other assets				0		0	0	0	0
Investment in subsidiaries						12,800	12,800	(10,000)	(44,346)
Capital contributions to subsidiaries							(8,287)	(5,000)
Chalmette Acquisition working capital settlement						0
Proceeds from sale of assets						0	4,802	60,902	133,845
Net cash used in investing activities				(287)		1,035	(984,180)	(729,307)	(63,315)
Cash flows from financing activities:
Additional catalyst lease							0
Contributions from PBF LLC				(97,000)			(450,300)		(328,664)
Distribution to Parent						0	0	0
Distribution to members				(5,252)		(61,667)	(139,434)	(350,658)	(361,352)
Proceeds from affiliate notes payable						635	43,396	347,783	90,631
Repayments of affiliate notes payable						(517)	(53,524)
Proceeds from revolver borrowings				290,000		550,000	550,000	170,000	395,000
Contributions from PBF LLC							0	345,000
Repayments of revolver borrowings				(290,000)			(200,000)	(170,000)	(410,000)
Increase (Decrease) in Due to Other Related Parties				(5,453)
Payment of Financing and Stock Issuance Costs				(12,414)
Business Combination, Payment of Contingent Consideration						0
Proceeds from Rail Facility revolver borrowings								0
Repayments of Rail Facility revolver borrowings							0
Deferred financing costs								(17,108)	(8,501)
Net cash provided by financing activities				108,672		488,451	650,738	825,017	34,442
Net increase (decrease) in cash and cash equivalents				(451,783)		375,139	(352,735)	697,439	109,202
Cash and equivalents, beginning of period	1,257,959			530,085	1,257,959	882,820	882,820	185,381	76,179
Cash and equivalents, end of period		78,302	1,257,959	78,302	530,085	1,257,959	530,085	882,820	185,381
Guarantors Subsidiaries [Member]
Cash flows from operating activities:
Net income		(346,937)	(270,173)	(709,620)		(639,394)	(1,502,243)	(1,228,631)	(1,184,027)
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization				107,430		96,645	194,722	178,601	164,550
Stock-based compensation				10,134		9,999	18,296	9,218	6,095
Change in fair value of catalyst lease obligation				1,484		4,633	(1,422)	(10,184)	(3,969)
Deferred income taxes				0		0	0
Non-cash lower of cost or market inventory adjustment				0		(16,780)	0	147,441	123,698
Non-cash change inventory repurchase obligations				0		26,172	0	63,389	(93,246)
Debt extinguishment costs		0		0
Pension and other post retirement benefits costs				17,817		11,891	30,848	19,406	16,174
Equity (income) loss in investee		0		0			0
Distributions from equity method investee				0
Loss (gain) on sale of assets				912		24	150	(105)	0
Loss (gain) on sale of assets		29	24	912		24	150	(105)	0
Equity in earnings (loss) of subsidiaries		(1,442)	0	(3,335)		0	74,507	0	0
Changes in operating assets and liabilities:
Accounts receivable				3,501		6,084	3,058	16,124	(17,976)
Due to/from affiliates							2,046,280	1,133,364	1,328,439
Due to/from affiliates				1,029,667		798,315
Inventories				0		(11,455)	0	(116,074)	20,711
Prepaid expense and other current assets				(14,716)		(12,365)	(2,675)	(2,999)	1,399
Accounts payable				(24,140)		(24,617)	41,025	15,710	(1,697)
Accrued expenses				(42,903)		(2,269)	(353,591)	8,172	471
Deferred revenue				(1,418)		0	1,438	0	0
Other assets and liabilities				(13,881)		(3,305)	(16,238)	(26,769)	(258)
Net cash provided by operations				360,932		243,578	534,155	206,663	360,364
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired							(2,659)
Expenditures for property, plant and equipment				(179,019)		(98,259)	(255,434)	(158,361)	(205,508)
Expenditures for deferred turnaround costs				(214,375)		(106,649)	(198,664)	(53,576)	(137,688)
Expenditures for other assets				(23,747)		(21,325)	(42,506)	(8,236)	(17,255)
Investment in subsidiaries						0	0	0	0
Capital contributions to subsidiaries							0	0
Chalmette Acquisition working capital settlement						(2,659)
Proceeds from sale of assets						0	0	0	0
Net cash used in investing activities				(417,141)		(228,892)	(499,263)	(201,131)	(360,451)
Cash flows from financing activities:
Additional catalyst lease							15,589
Contributions from PBF LLC				0			0		0
Distribution to Parent						0	0	0
Distribution to members				0		0	0	0	0
Proceeds from affiliate notes payable						0	0	0	0
Repayments of affiliate notes payable						0	0
Proceeds from revolver borrowings				0		0	0	0	0
Contributions from PBF LLC							0	0
Repayments of revolver borrowings				0			0	0	0
Increase (Decrease) in Due to Other Related Parties				5,453
Payment of Financing and Stock Issuance Costs				0
Business Combination, Payment of Contingent Consideration						0
Proceeds from Rail Facility revolver borrowings								0
Repayments of Rail Facility revolver borrowings							0	0
Deferred financing costs								0	0
Net cash provided by financing activities				5,453		0	15,589	0	0
Net increase (decrease) in cash and cash equivalents				(50,756)		14,686	50,481	5,532	(87)
Cash and equivalents, beginning of period	20,922			56,717	20,922	6,236	6,236	704	791
Cash and equivalents, end of period		5,961	20,922	5,961	56,717	20,922	56,717	6,236	704
Non-Guarantor Subsidiaries [Member]
Cash flows from operating activities:
Net income		10,208	(22,039)	9,655		(45,411)	(74,507)	73,563	52,706
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization				3,823		3,895	9,337	3,719	1,528
Stock-based compensation				0		0	0	0	0
Change in fair value of catalyst lease obligation				0		0	0	0	0
Deferred income taxes				5,123		27,060	19,802
Non-cash lower of cost or market inventory adjustment				0		0	0	0	0
Non-cash change inventory repurchase obligations				0		0			0
Debt extinguishment costs		0		0
Pension and other post retirement benefits costs				0		0	0	0	0
Equity (income) loss in investee		(3,820)		(7,419)			(5,679)
Distributions from equity method investee				12,254
Loss (gain) on sale of assets				0		3,198	8,832	(650)	(618)
Loss (gain) on sale of assets		0	3,198	0		3,198	8,832	(650)	(618)
Equity in earnings (loss) of subsidiaries		0	0	0		0	0	0	0
Changes in operating assets and liabilities:
Accounts receivable				(18,714)		(6,484)	4,158	(6,177)	(6,533)
Due to/from affiliates							(4,626)	(103,084)	(92,181)
Due to/from affiliates				68,107		38,216
Inventories				(37,519)		2,940	18,973	(47,067)	(155,390)
Prepaid expense and other current assets				(8)		198	92	(353)	0
Accounts payable				(2,116)		1,030	7,405	(857)	8,423
Accrued expenses				(29,818)		(9,082)	49,964	(73,834)	191,331
Deferred revenue				12		0	1	0	0
Other assets and liabilities				(11,426)		1,087	1,193	10	(1)
Net cash provided by operations				(8,046)		16,647	34,945	(154,730)	(735)
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired							0
Expenditures for property, plant and equipment				(269)		(11)	(5,433)	(106)	(112,138)
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 contributions to subsidiaries							0	0
Chalmette Acquisition working capital settlement						0
Proceeds from sale of assets						6,860	19,890	107,368	68,809
Net cash used in investing activities				(269)		6,849	14,457	124,227	(43,329)
Cash flows from financing activities:
Additional catalyst lease							0
Contributions from PBF LLC				0			0		(44,346)
Distribution to Parent						(12,800)	(12,800)	(10,000)
Distribution to members				0		0	0	0	0
Proceeds from affiliate notes payable						0	0	0	0
Repayments of affiliate notes payable						0	0
Proceeds from revolver borrowings				0		0	0	0	0
Contributions from PBF LLC							8,287	5,000
Repayments of revolver borrowings				0			0	0	0
Increase (Decrease) in Due to Other Related Parties				0
Payment of Financing and Stock Issuance Costs				0
Business Combination, Payment of Contingent Consideration						(6,970)
Proceeds from Rail Facility revolver borrowings								102,075
Repayments of Rail Facility revolver borrowings							(67,491)	(71,938)
Deferred financing costs								0	(3,218)
Net cash provided by financing activities				(3,295)		(19,770)	(37,004)	25,137	78,398
Net increase (decrease) in cash and cash equivalents				(11,610)		3,726	12,398	(5,366)	34,334
Cash and equivalents, beginning of period	32,694			41,366	32,694	28,968	28,968	34,334	0
Cash and equivalents, end of period		29,756	32,694	29,756	41,366	32,694	41,366	28,968	34,334
Combining and Consolidated Adjustments [Member]
Cash flows from operating activities:
Net income		336,729	292,212	699,965		684,805	1,576,750	1,154,420	1,131,321
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		0	0
Non-cash lower of cost or market inventory adjustment				0		0	0	0	0
Non-cash change inventory repurchase obligations				0		0			0
Debt extinguishment costs		0		0
Pension and other post retirement benefits costs				0		0	0	0	0
Equity (income) loss in investee		0		0			0
Distributions from equity method investee				0
Loss (gain) on sale of assets				0		0	0	0	0
Loss (gain) on sale of assets		0	0	0		0	0	0	0
Equity in earnings (loss) of subsidiaries		(336,729)	(292,212)	(699,965)		(684,805)	(1,576,750)	(1,154,420)	(1,131,321)
Changes in operating assets and 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				1,463		1,930	1,812	(1,259)	(2,016)
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				1,463		1,930	1,812	(1,259)	(2,016)
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired							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)	(12,800)	10,000	44,346
Capital contributions to subsidiaries							8,287	5,000
Chalmette Acquisition working capital settlement						0
Proceeds from sale of assets						0	0	0	0
Net cash used in investing activities				0		(12,800)	(4,513)	(5,000)	44,346
Cash flows from financing activities:
Additional catalyst lease							0
Contributions from PBF LLC				0			0		44,346
Distribution to Parent						12,800	12,800	10,000
Distribution to members				0		0	0	0	0
Proceeds from affiliate notes payable						0	0	0	0
Repayments of affiliate notes payable						0	0
Proceeds from revolver borrowings				0		0	0	0	0
Contributions from PBF LLC							(8,287)	(5,000)
Repayments of revolver borrowings				0			0	0	0
Increase (Decrease) in Due to Other Related Parties				0
Payment of Financing and Stock Issuance Costs				0
Business Combination, Payment of Contingent Consideration						0
Proceeds from Rail Facility revolver borrowings								0
Repayments of Rail Facility revolver borrowings								0
Deferred financing costs								0	0
Net cash provided by financing activities				0		12,800	4,513	5,000	(44,346)
Net increase (decrease) in cash and cash equivalents				1,463		1,930	1,812	(1,259)	(2,016)
Cash and equivalents, beginning of period	(1,345)			(1,463)	(1,345)	(3,275)	(3,275)	(2,016)	0
Cash and equivalents, end of period		$ 0	$ (1,345)	0	(1,463)	(1,345)	(1,463)	(3,275)	(2,016)
Rail Facility [Member]
Cash flows from financing activities:
Proceeds from revolver borrowings									83,095
Repayments of revolver borrowings				0		(6,970)			(45,825)
Rail Facility [Member] | Issuer [Member]
Cash flows from financing activities:
Proceeds from revolver borrowings									0
Repayments of revolver borrowings									0
Rail Facility [Member] | Guarantors Subsidiaries [Member]
Cash flows from financing activities:
Proceeds from revolver borrowings									0
Repayments of revolver borrowings									0
Rail Facility [Member] | Non-Guarantor Subsidiaries [Member]
Cash flows from financing activities:
Proceeds from revolver borrowings									83,095
Repayments of revolver borrowings									(45,825)
Rail Facility [Member] | Combining and Consolidated Adjustments [Member]
Cash flows from financing activities:
Proceeds from revolver borrowings									0
Repayments of revolver borrowings									0
2023 Senior Secured Notes [Member]
Cash flows from financing activities:
Proceeds from 2023 Senior Secured Notes								500,000
2023 Senior Secured Notes [Member] | Issuer [Member]
Cash flows from financing activities:
Proceeds from 2023 Senior Secured Notes								500,000
2023 Senior Secured Notes [Member] | Guarantors Subsidiaries [Member]
Cash flows from financing activities:
Proceeds from 2023 Senior Secured Notes								0
2023 Senior Secured Notes [Member] | Non-Guarantor Subsidiaries [Member]
Cash flows from financing activities:
Proceeds from 2023 Senior Secured Notes								0
2023 Senior Secured Notes [Member] | Combining and Consolidated Adjustments [Member]
Cash flows from financing activities:
Proceeds from 2023 Senior Secured Notes								0
2025 Senior Notes [Member]
Cash flows from financing activities:
Proceeds from 2025 7.25% Senior Notes				725,000		0
Proceeds from 2023 Senior Secured Notes				725,000
2025 Senior Notes [Member] | Issuer [Member]
Cash flows from financing activities:
Proceeds from 2023 Senior Secured Notes				725,000
2025 Senior Notes [Member] | Guarantors Subsidiaries [Member]
Cash flows from financing activities:
Proceeds from 2023 Senior Secured Notes				0
2025 Senior Notes [Member] | Non-Guarantor Subsidiaries [Member]
Cash flows from financing activities:
Proceeds from 2023 Senior Secured Notes				0
2025 Senior Notes [Member] | Combining and Consolidated Adjustments [Member]
Cash flows from financing activities:
Proceeds from 2023 Senior Secured Notes				0
2020 Senior Secured Notes [Member]
Cash flows from financing activities:
Repayments of Long-term Debt				(690,209)		0
2020 Senior Secured Notes [Member] | Issuer [Member]
Cash flows from financing activities:
Repayments of Long-term Debt				(690,209)
2020 Senior Secured Notes [Member] | Guarantors Subsidiaries [Member]
Cash flows from financing activities:
Repayments of Long-term Debt				0
2020 Senior Secured Notes [Member] | Non-Guarantor Subsidiaries [Member]
Cash flows from financing activities:
Repayments of Long-term Debt				0
2020 Senior Secured Notes [Member] | Combining and Consolidated Adjustments [Member]
Cash flows from financing activities:
Repayments of Long-term Debt				0
Rail Term Loan [Member]
Cash flows from financing activities:
Repayments of Debt				(3,295)
Proceeds from 2025 7.25% Senior Notes							35,000	0	0
Repayments of Long-term Debt				(3,295)		$ 0
Rail Term Loan [Member] | Issuer [Member]
Cash flows from financing activities:
Repayments of Debt				0
Proceeds from 2025 7.25% Senior Notes							0
Rail Term Loan [Member] | Guarantors Subsidiaries [Member]
Cash flows from financing activities:
Repayments of Debt				0
Proceeds from 2025 7.25% Senior Notes							0
Rail Term Loan [Member] | Non-Guarantor Subsidiaries [Member]
Cash flows from financing activities:
Repayments of Debt				(3,295)
Proceeds from 2025 7.25% Senior Notes							35,000
Rail Term Loan [Member] | Combining and Consolidated Adjustments [Member]
Cash flows from financing activities:
Repayments of Debt				$ 0
Proceeds from 2025 7.25% Senior Notes							0
Chalmette Refinery [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired							(2,659)	(565,304)	0
Chalmette Refinery [Member] | Issuer [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired								(601,311)
Chalmette Refinery [Member] | Guarantors Subsidiaries [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired								19,042
Chalmette Refinery [Member] | Non-Guarantor Subsidiaries [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired								16,965
Chalmette Refinery [Member] | Combining and Consolidated Adjustments [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired								0
Torrance Refinery [Member]
Cash flows from operating activities:
Net income					$ 86,394
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired	$ (521,350)						(971,932)	$ 0	$ 0
Torrance Refinery [Member] | Issuer [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired							(971,932)
Torrance Refinery [Member] | Guarantors Subsidiaries [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired							0
Torrance Refinery [Member] | Non-Guarantor Subsidiaries [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired							0
Torrance Refinery [Member] | Combining and Consolidated Adjustments [Member]
Cash flows from investing activities:
Acquisition of businesses, net of cash acquired							$ 0