UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
FORM 10-K
 
(Mark one)
x
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended: December 31, 20152018
Or
¨
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from            to             
Commission File Number: 001-35764
 
PBF HOLDING COMPANY LLC
PBF FINANCE CORPORATION
(Exact name of registrant as specified in its charter)
 
DELAWARE 27-2198168
DELAWARE 45-2685067
   
(State or other jurisdiction of
incorporation or organization)
 
(I.R.S. Employer
Identification No.)
  
One Sylvan Way, Second Floor
Parsippany, New Jersey
 07054
(Address of principal executive offices) (Zip Code)
Registrants’ telephone number, including area code: (973) 455-7500
Securities registered pursuant to Section 12(b) of the Act: None.
Securities registered pursuant to Section 12(g) of the Act: None.
 


Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. 
PBF Holding Company LLC¨Yes xNo
PBF Finance Corporation    ¨ Yes x No
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the ActAct. 
PBF Holding Company LLCxYes ¨No
PBF Finance Corporation    x Yes ¨ No
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports); and (2) has been subject to such filing requirements for the past 90 days.
PBF Holding Company LLC¨ ¨Yes xNo
PBF Finance Corporation    ¨ Yes x No
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
PBF Holding Company LLCx xYes o¨ No
PBF Finance Corporation    x Yes ¨ No
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.   
PBF Holding Company LLCx
PBF Finance Corporation    x
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company” and “smaller reporting“emerging growth company” in Rule 12b-2 of the Exchange Act.
 Large accelerated
filer
 Accelerated filer Non-accelerated filer
(Do not check if a
smaller reporting
company)
 Smaller reporting
company
 
¨

Emerging growth company
PBF Holding Company LLC ¨ 
¨
x

¨¨
PBF Finance Corporation¨¨x¨ ¨
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
PBF Holding Company LLC¨ Yes ¨ No
PBF Finance Corporation    ¨ Yes ¨ No
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
PBF Holding Company LLC¨ ¨Yes xNo
PBF Finance Corporation    ¨ Yes x No
There is no trading in the membership interests of PBF Holding LLC or the common stock of PBF Finance Corporation and therefore an aggregate market value based on such is not determinable.
PBF Holding Company LLC has no common stock outstanding. As of March 24, 20166, 2019, 100% of the membership interests of PBF Holding Company LLC were owned by PBF Energy Company LLC, and PBF Finance Corporation had 100 shares of common stock outstanding, all of which were held by PBF Holding Company LLC.
PBF Finance Corporation meets the conditions set forth in General Instruction (I)(1)(a) and (b) of Form 10-K and is therefore filing this form with the reduced disclosure format.
DOCUMENTS INCORPORATED BY REFERENCE
PBF Energy Inc., the managing member of our direct parent PBF Energy Company LLC, filedwill file with the Securities and Exchange Commission a definitive Proxy Statement for its 2019 Annual Meeting of Stockholders on March 22, 2016.Stockholders. Portions of the Proxy Statement of PBF Energy Inc. are incorporated by reference in Part III of this Form 10-K to the extent stated herein.
 




PBF HOLDING COMPANY LLC
TABLE OF CONTENTS
 
    
 
 
 
 
 
 
    
 
 
 
 
 
 
 
 
 
  
 
    
 
 
 
 
 
    
 
 
 

Explanatory Note

This Form 10-K is filed by PBF Holding Company LLC (“PBF Holding”) and PBF Finance Corporation (“PBF Finance”). PBF Holding is a wholly-owned subsidiary of PBF Energy Company LLC (“PBF LLC”) and is the parent company for PBF LLC's refinery operating subsidiaries. PBF Finance is a wholly-owned subsidiary of PBF Holding. PBF Holding is an indirect subsidiary of PBF Energy Inc. (“PBF Energy”), which is the sole managing member of, and owner of an equity interest representing approximately 95.1%99.0% of the outstanding economic interests in PBF LLC as of December 31, 2015.2018. PBF Energy operates and controls all of the business and affairs and consolidates the financial results of PBF LLC and its subsidiaries. PBF Holding, together with its consolidated subsidiaries, owns and operates oil refineries and related facilities in North America.

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GLOSSARY OF SELECTED TERMS
Unless otherwise noted or indicated by context, the following terms used in this Annual Report on Form 10-K have the following meanings:
“AB32” refers to the greenhouse gas emission control regulations in the state of California to comply with Assembly Bill 32.
“ASCI” refers to the Argus Sour Crude Index, a pricing index used to approximate market prices for sour, heavy crude oil.
“Bakken” refers to both a crude oil production region generally covering North Dakota, Montana and Western Canada, and the crude oil that is produced in that region.
“barrel” refers to a common unit of measure in the oil industry, which equates to 42 gallons.
“blendstocks” refers to various compounds that are combined with gasoline or diesel from the crude oil refining process to make finished gasoline and diesel; these may include natural gasoline, FCC unit gasoline, ethanol, reformate or butane, among others.
“bpd” refers to an abbreviation for barrels per day.
“CAA” refers to the Clean Air Act.
“CAM Pipeline” or “CAM Connection Pipeline” refers to the Clovelly-Alliance-Meraux pipeline in Louisiana.
“CARB”refers to the California Air Resources Board; gasoline and diesel fuel sold in the state of California are regulated by CARB and require stricter quality and emissions reduction performance than required by other states.
“catalyst” refers to a substance that alters, accelerates, or instigates chemical changes, but is not produced as a product of the refining process.
“coke” refers to a coal-like substance that is produced from heavier crude oil fractions during the refining process.
“complexity” refers to the number, type and capacity of processing units at a refinery, measured by the Nelson Complexity Index, which is often used as a measure of a refinery’s ability to process lower quality crude in an economic manner.
“crack spread” refers to a simplified calculation that measures the difference between the price for light products and crude oil. For example, we reference (a) the 2-1-1 crack spread, which is a general industry standard utilized by our Delaware City, Paulsboro and Chalmette refineries that approximates the per barrel refining margin resulting from processing two barrels of crude oil to produce one barrel of gasoline and one barrel of heating oil or ULSD, and (b) the 4-3-1 crack spread, which is a benchmark utilized by our Toledo and Torrance refineries that approximates the per barrel refining margin resulting from processing four barrels of crude oil to produce three barrels of gasoline and one-half barrel of jet fuel and one-half barrel of ULSD.
“Dated Brent” refers to Brent blend oil, a light, sweet North Sea crude oil, characterized by an API gravity of 38° and a sulfur content of approximately 0.4 weight percent, that is used as a benchmark for other crude oils.
“distillates” refers primarily to diesel, heating oil, kerosene and jet fuel.
“DNREC” refers to the Delaware Department of Natural Resources and Environmental Control.
“downstream” refers to the downstream sector of the energy industry generally describing oil refineries, marketing and distribution companies that refine crude oil and sell and distribute refined products. The opposite of the downstream sector is the upstream sector, which refers to exploration and production companies that search for and/or produce crude oil and natural gas underground or through drilling or exploratory wells.


“EPA” refers to the United States Environmental Protection Agency.
“Ethanol Permit” refers to a Coastal Zone Act permit for ethanol.
“ethanol” refers to a clear, colorless, flammable oxygenated liquid. Ethanol is typically produced chemically from ethylene, or biologically from fermentation of various sugars from carbohydrates found in agricultural crops. It is used in the United States as a gasoline octane enhancer and oxygenate.
“feedstocks” refers to crude oil and partially refined petroleum products that are processed and blended into refined products.
“FASB” refers to the Financial Accounting Standards Board which develops U.S. generally accepted accounting principles.
“FCC” refers to fluid catalytic cracking.
“FCU” refers to fluid coking unit.
“FERC” refers to the Federal Energy Regulatory Commission.
“GAAP” refers to U.S. generally accepted accounting principles developed by the Financial Accounting Standards Board for nongovernmental entities.
“GHG” refers to the greenhouse gas carbon dioxide.
“Group I base oils or lubricants” refers to conventionally refined products characterized by sulfur content less than 0.03% with a viscosity index between 80 and 120. Typically, these products are used in a variety of automotive and industrial applications.
“heavy crude oil” refers to a relatively inexpensive crude oil with a low API gravity characterized by high relative density and viscosity. Heavy crude oils require greater levels of processing to produce high value products such as gasoline and diesel.
“IPO” refers to the initial public offering of PBF Energy Class A common stock which closed on December 18, 2012.
“J. Aron” refers to J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc.
“KV” refers to Kilovolts.
“LCM” refers to a GAAP requirement for inventory to be valued at the lower of cost or market.
“light crude oil” refers to a relatively expensive crude oil with a high API gravity characterized by low relative density and viscosity. Light crude oils require lower levels of processing to produce high value products such as gasoline and diesel.
“light products” refers to the group of refined products with lower boiling temperatures, including gasoline and distillates.
“light-heavy differential” refers to the price difference between light crude oil and heavy crude oil.
“LLS” refers to Light Louisiana Sweet benchmark for crude oil reflective of Gulf coast economics for light sweet domestic and foreign crudes.
“LPG” refers to liquefied petroleum gas.
“Maya” refers to Maya crude oil, a heavy, sour crude oil characterized by an API gravity of approximately 22° and a sulfur content of approximately 3.3 weight percent that is used as a benchmark for other heavy crude oils.


“MLP” refers to the master limited partnership.
“MMBTU” refers to million British thermal units.
“MMSCFD” refers to million standard cubic feet per day.
“MOEM Pipeline” refers to a pipeline that originates at a terminal in Empire, Louisiana approximately 30 miles north of the mouth of the Mississippi River. The MOEM Pipeline is 14 inches in diameter, 54 miles long and transports crude from South Louisiana to the Chalmette refinery and transports Heavy Louisiana Sweet (HLS) and South Louisiana Intermediate (SLI) crude.
“MW” refers to Megawatt.
“Nelson Complexity Index” refers to the complexity of an oil refinery as measured by the Nelson Complexity Index, which is calculated on an annual basis by the Oil and Gas Journal. The Nelson Complexity Index assigns a complexity factor to each major piece of refinery equipment based on its complexity and cost in comparison to crude distillation, which is assigned a complexity factor of 1.0. The complexity of each piece of refinery equipment is then calculated by multiplying its complexity factor by its throughput ratio as a percentage of crude distillation capacity. Adding up the complexity values assigned to each piece of equipment, including crude distillation, determines a refinery’s complexity on the Nelson Complexity Index. A refinery with a complexity of 10.0 on the Nelson Complexity Index is considered ten times more complex than crude distillation for the same amount of throughput.
“NYH” refers to the New York Harbor market value of petroleum products.
“NYMEX” refers to the New York Mercantile Exchange.
“NYSE” refers to the New York Stock Exchange.
“PADD” refers to Petroleum Administration for Defense Districts.
“Platts” refers to Platts, a division of The McGraw-Hill Companies.
“PPM” refers to parts per million.
“RINS” refers to renewable fuel credits required for compliance with the Renewable Fuel Standard.
“refined products” refers to petroleum products, such as gasoline, diesel and jet fuel, that are produced by a refinery.
“sour crude oil” refers to a crude oil that is relatively high in sulfur content, requiring additional processing to remove the sulfur. Sour crude oil is typically less expensive than sweet crude oil.
“Saudi Aramco” refers to Saudi Arabian Oil Company.
“SEC” refers to the United States Securities and Exchange Commission.
“Sunoco” refers to Sunoco, LLC.
“sweet crude oil” refers to a crude oil that is relatively low in sulfur content, requiring less processing to remove the sulfur than sour crude oil. Sweet crude oil is typically more expensive than sour crude oil.
“Syncrude” refers to a blend of Canadian synthetic oil, a light, sweet crude oil, typically characterized by API gravity between 30° and 32° and a sulfur content of approximately 0.1-0.2 weight percent.
“TCJA” refers to the U.S. government comprehensive tax legislation enacted on December 22, 2017 and commonly referred to as the Tax Cuts and Jobs Act.


“throughput” refers to the volume processed through a unit or refinery.
“turnaround” refers to a periodically required shutdown and comprehensive maintenance event to refurbish and maintain a refinery unit or units that involves the inspection of such units and occurs generally on a periodic cycle.
“ULSD” refers to ultra-low-sulfur diesel.
“Valero” refers to Valero Energy Corporation.
“WCS” refers to Western Canadian Select, a heavy, sour crude oil blend typically characterized by API gravity between 20° and 22° and a sulfur content of approximately 3.5 weight percent that is used as a benchmark for heavy Western Canadian crude oil.
“WTI” refers to West Texas Intermediate crude oil, a light, sweet crude oil, typically characterized by API gravity between 38° and 40° and a sulfur content of approximately 0.3 weight percent that is used as a benchmark for other crude oils.
“WTS” refers to West Texas Sour crude oil, a sour crude oil characterized by API gravity between 30° and 33° and a sulfur content of approximately 1.28 weight percent that is used as a benchmark for other sour crude oils.
“yield” refers to the percentage of refined products that is produced from crude oil and other feedstocks.



PART I
In this Annual Report on Form 10-K, unless the context otherwise requires, references to the “Company,” “we,” “our” or “us” refer to PBF Holding, and, in each case, unless the context otherwise requires, its consolidated subsidiaries. References to “subsidiary guarantors” refer to PBF Services Company LLC, PBF Power Marketing LLC, Paulsboro Natural Gas Pipeline Company LLC, Paulsboro Refining Company LLC (“Paulsboro Refining”), Toledo Refining Company LLC (“Toledo Refining” or “TRC”), Delaware City Refining Company LLC (“Delaware City Refining” or “DCR”), PBF Investments LLC (“PBF Investments”), andPBF International Inc., Chalmette Refining, L.L.C. (“Chalmette Refining”), PBF Energy Western Region LLC (“PBF Western Region”), Torrance Refining Company LLC (“Torrance Refining”) and Torrance Logistics Company LLC (“Torrance Logistics”), which are the subsidiaries of PBF Holding that guarantee PBF Holding's 8.25% Senior Secured Notes due 2020 (the “2020 Senior Secured Notes”) and 7.0% Senior Secured NotesHolding’s 7.00% senior notes due 2023 (the “2023 Senior SecuredNotes”) and 7.25% senior notes due 2025 (the “2025 Senior Notes”, and together with the 20202023 Senior Secured Notes, the “Senior Secured Notes”) on a joint and several basis.
In this Annual Report on Form 10-K, we make certain forward-looking statements, including statements regarding our plans, strategies, objectives, expectations, intentions, and resources, under the safe harbor provisions of the Private Securities Litigation Reform Act of 1995.resources. You should read our forward-looking statements together with our disclosures under the heading: “Cautionary Statement for the Purpose of Safe Harbor Provisions of the Private Securities Litigation Reform Act of 1995.Regarding Forward-Looking Statements.” When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements set forth in this Annual Report on Form 10-K under “Risk Factors” in Item 1A.

ITEM. 1 BUSINESS
Overview and Corporate Structure
We are one of the largest independent petroleum refiners and suppliers of unbranded transportation fuels, heating oil, petrochemical feedstocks, lubricants and other petroleum products in the United States. We sell our products throughout the Northeast, Midwest, Gulf Coast and GulfWest Coast of the United States, as well as in other regions of the United States, Canada and Canada,Mexico and are able to ship products to other international destinations. We were formed in 2008 to pursue acquisitions of crude oil refineries and downstream assets in North America. We currentlyAs of December 31, 2018, we own and operate fourfive domestic oil refineries and related assets, which we acquired in 2010, 2011, 2015 and November 2015.2016. Our refineries have a combined processing capacity, known as throughput, of approximately 730,000 bpd,900,000 barrels per day (“bpd”), and a weighted-average Nelson Complexity Index of 11.7.12.2. The Company’s fourfive oil refineries are aggregated into one reportable segment.
Our four refineries are located in Toledo, Ohio, Delaware City, Delaware, Paulsboro, New Jersey and New Orleans, Louisiana. Our Mid-Continent refinery at Toledo processes light, sweet crude and has a throughput capacity of 170,000 bpd and a Nelson Complexity Index of 9.2. The majority of Toledo’s WTI-based crude is delivered via pipelines that originate in both Canada and the United States. Since our acquisition of Toledo in 2011, we have added additional truck and rail crude unloading capabilities that provide feedstock sourcing flexibility for the refinery and enables Toledo to run a more cost-advantaged crude slate. Our East Coast refineries at Delaware City and Paulsboro have a combined refining capacity of 370,000 bpd and Nelson Complexity Indices of 11.3 and 13.2, respectively. These high-conversion refineries process primarily medium and heavy, sour crudes and have the flexibility to receive crude and feedstock via both water and rail. We have expanded and upgraded existing on-site railroad infrastructure at our Delaware City refinery, including the expansion of the crude rail unloading facilities that was completed in February 2013. The Delaware City rail unloading facility, which was transferred to our affiliate, PBF Logistics LP (“PBFX” or the “Partnership”), in 2014, allows our East Coast refineries the flexibility to source WTI-based crudes from Western Canada and the Mid-Continent, when doing so provides cost advantages versus traditional Brent-based international crudes. We believe this sourcing optionality is critical to the profitability of our East Coast refining system. The Chalmette Refinery, located outside of New Orleans, Louisiana, is a 189,000 bpd, dual-train coking refinery with a Nelson Complexity of 12.7 and is capable of processing both light and heavy crude oil. The facility is strategically positioned on the Gulf Coast with strong logistics connectivity that offers flexible raw material sourcing and product distribution opportunities, including the potential to export products.
On November 1, 2015, we closed our acquisition of the Chalmette refinery and related logistics assets (the “Chalmette Acquisition”). The Chalmette Acquisition included acquisition of 100% ownership of the MOEM Pipeline, providing

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access to the Empire Terminal, as well as the CAM Connection Pipeline, providing access to the Louisiana Offshore oil Port (“LOOP”) facility through a third party pipeline. We also acquired an 80% ownership in 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 via the Plantation and Colonial Pipelines. The purchase price was $322.0 million, plus estimated inventory and working capital of $243.3 million, which is subject to final valuation upon agreement of both parties. The transaction was financed through a combination of cash on hand and borrowings under our Revolving Loan (as defined below).
The Chalmette Acquisition represents our entry into the Gulf Coast market and we believe the acquisition offers numerous opportunities for us to potentially enhance earnings through exercising our commercial flexibility. The Gulf Coast is a product exporting region and this should be an opportunity for us to participate in the international as well as domestic market. Additionally, the Chalmette refinery currently distributes products to the product-short Northeastern United States through access to the Colonial pipeline and we believe there is an opportunity for the Chalmette refinery to increase its profitability by penetrating further into the local products market. We also entered into a market-based crude supply agreement with Petróleos de Venezuela S.A. (“PDVSA”) in connection with the acquisition. By being flexible in supplying products to the international market, exporting to Petroleum Administration for Defense District 3 (“PADD 3”) and increasing local sales, we believe the overall profitability of the refinery can be enhanced.
The acquisition of the Chalmette refinery gives us a broader more diversified asset base and increases the number of operating refineries from three to four, and our combined crude oil throughput capacity from 540,000 bpd to approximately 730,000 bpd. The acquisition provides us with a presence in the attractive PADD 3 market. The Chalmette refinery has excellent conversion capabilities and increases our ability to process low cost heavy sour and high acid crude oils.
PBF Holding is a wholly-owned subsidiary of PBF LLC and an indirect subsidiary of PBF Energy. PBF Finance is a wholly-owned subsidiary of PBF Holding. PBF Holding is the parent company for PBF LLC's refinery operating subsidiaries.
PBF Energy Inc.'s Public OfferingsOwnership Structure
We are a Delaware limited liability company and a holding company for our operating subsidiaries. PBF Finance is a wholly-owned subsidiary of PBF Holding. We are a wholly-owned subsidiary of PBF LLC, and PBF Energy is the sole managing member of, and owner of an equity interest as of December 31, 20152018 representing approximately 95.1%99.0% of the outstanding economic interests in PBF LLC.
On December 18, 2012, our indirect parent, PBF Energy completed its initial public offering. PBF Energy used the net proceeds of the offering to acquire approximately 24.4% of the membership interests in PBF LLC from certain of its existing members. As a result of the PBF Energy'sEnergy’s initial public offering and related organization transactions, PBF Energy became the sole managing member of PBF LLC and operates and controls all of its business and affairs and consolidates the financial results of PBF LLC and its subsidiaries, including PBF Holding and PBF Finance. PBF Energy completed secondary offerings of its Class A common stock in 2013, 2014, and 2015. Additionally, on October 13, 2015, PBF Energy completed a public offering of an aggregate of 11,500,000 shares of Class A common stock (the “October 2015 Equity Offering”). As of December 31, 2015,2018, PBF Energy held 97,781,933119,895,422 PBF LLC Series C Units and its current and former executive officers and directors and certain employees and others beneficially held 4,985,3581,206,325 PBF LLC Series A Units, and the holders of PBF Energy'sEnergy’s issued and outstanding shares of its Class A common stock have 95.1%approximately 99.0% of the voting power in PBF Energy and the members of PBF LLC other than PBF Energy through their holdings of Class B common stock have the remaining 4.9%1.0% of the voting power.


PBF Holding Refineries
Our five refineries are located in Delaware City, Delaware, Paulsboro, New Jersey, Toledo, Ohio, New Orleans, Louisiana and Torrance, California. Each refinery is briefly described in the table below:
RefineryRegion
Nelson Complexity
Index
Throughput Capacity (in barrels per day)PADD
Crude Processed (1)
Source (1)
Delaware CityEast Coast11.3190,0001light sweet through heavy sourwater, rail
PaulsboroEast Coast13.2180,0001light sweet through heavy sourwater
ToledoMid-Continent9.2170,0002light sweetpipeline, truck, rail
ChalmetteGulf Coast12.7189,0003light sweet through heavy sourwater, pipeline
TorranceWest Coast14.9155,0005medium and heavypipeline, water, truck
________
Initial(1) Reflects the typical crude and feedstocks and related sources utilized under normal operating conditions and prevailing market environments.
Public OfferingOfferings of PBFXPBF Logistics LP and Subsequent Drop-Down Transactions
PBF Logistics LP (“PBFX” or the “Partnership”) is an affiliate of ours. PBFX is a fee-based, growth-oriented, publicly tradedpublicly-traded Delaware master limited partnership formed by PBF Energy to own or lease, operate, develop and acquire crude oil and refined petroleum products terminals, pipelines, storage facilities and similar logistics assets. PBFX engages in the receiving, handling, storing and transferring of crude oil, and the receipt, storage and delivery of crude oil, refined products, natural gas and intermediates from sources located throughout the United States and Canada for PBF HoldingEnergy in support of certain of its refineries. Allrefineries, as well as for third-party customers. As of December 31, 2018, a substantial majority of PBFX’s revenue is derived from long-term, fee-based commercial agreements with PBF Holding,us, which include minimum volume commitments, for receiving, handling, storing and transferring crude oil, refined products, and refined products.natural gas. PBF Energy also has agreements with PBFX that establish fees for certain general and administrative services and operational and maintenance services provided by PBF Holdingus to PBFX.
PBF Logistics GP LLC (“PBF GP”) serves as the general partner of PBFX. PBF GP is wholly-owned by PBF LLC. On May 14, 2014, PBFX completed its initial public offering (the “PBFX Offering”). In connection with the PBFX Offering,

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we distributed to PBF HoldingLLC, which in turn contributed to PBFX, the assets and liabilities of certain crude oil terminaling assets. The assets were owned and operated by PBF Holding’s subsidiaries Delaware City Refining and Toledo Refining. The initial assets distributed consisted of the Delaware City Rail Unloading Terminal (“DCR Rail Terminal”), which was part of DCR, and the Toledo Truck Unloading Terminal (“Toledo Truck Terminal”), which was part of TRC. In a series of additional transactions in 2014 and 2015, PBF Holdingsubsequent to the PBFX Offering, we distributed certain additional assets to PBF LLC, which in turn contributed those assets to PBFX. These transactions included the Delaware City heavy crude unloading rack (the “DCR West Rack”) on September 30, 2014, a tank farm and related facilities, including a propane storage and loading facility at TRC (the “Toledo Storage Facility”) on December 11, 2014, and the Delaware City Products Pipeline and Truck Rack at DCR on May 14, 2015 (as described below).See “Agreements with PBFX” below as well as “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements for additional information.
See “Item 1A. Risk Factors” and “Item 13. Certain Relationships and Related Transactions, and Director Independence.”
Recent Developments
Pending Torrance Acquisition
On September 29, 2015, PBF Holding entered into a definitive Sale and Purchase Agreement (the “Torrance Sale and Purchase Agreement”) with ExxonMobil Oil Corporation (“ExxonMobil”) and its subsidiary, Mobil Pacific Pipeline Company (together, the “Torrance Sellers”), to purchase the Torrance refinery, and related logistics assets (collectively, the “Torrance Acquisition”). The Torrance refinery, located on 750 acres in Torrance, California, is a high-conversion 155,000 bpd, delayed-coking refinery with a Nelson Complexity of 14.9. 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 is expected to further increase the Company's total throughput capacity to approximately 900,000 bpd.
In addition to refining assets, the Torrance Acquisition 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 171-mile 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 Torrance refinery also has crude and product storage facilities with approximately 8.6 million barrels of shell capacity.
The purchase price for the Torrance Acquisition is $537.5 million, plus inventory and working capital to be valued at closing. The purchase price is also subject to other customary purchase price adjustments. The Torrance Acquisition is expected to close in the second quarter of 2016, subject to satisfaction of customary closing conditions. Additionally, as a condition of closing, the Torrance refinery is to be restored to full working order with respect to the event that occurred on February 18, 2015 resulting in damage to the electrostatic precipitator and related systems, and shall have operated as required under the Torrance Sale and Purchase Agreement for a period of at least fifteen days after such restoration. PBF Energy expects to finance the transaction with a combination of cash on hand, and proceeds from the October 2015 Equity Offering and the offering of the 2023 Senior Secured Notes (the “2023 Senior Secured Notes Offering”). Following the expected completion of the Torrance Acquisition, our weighted average Nelson Complexity Index will increase to 12.2.
Available Information
Our website address is www.pbfenergy.com. Information contained on our website is not part of this Annual Report on Form 10-K. Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any other materials filed with (or furnished to) the U.S. Securities and Exchange Commission (SEC)(“SEC”) by us are available on our website (under “Investors”) free of charge, soon after we file or furnish such material.


The diagram below depicts our organizational structure as of December 31, 2015:2018:

5pbfhstructurechart2018.gif




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Refining Operations
We own and operate fourfive refineries in PADDs 1, 2 and 3 providing geographic and market diversity. We produce a variety of products at each of our refineries, including gasoline, ULSD, heating oil, jet fuel, lubricants, petrochemicals and asphalt. We sell our products throughout the Northeast, Midwest, Gulf Coast and GulfWest Coast of the United States, as well as in other regions of the United States, Canada and Canada,Mexico, and are able to ship products to other international destinations.
Delaware City Refinery
Acquisition and Re-Start. Through our subsidiaries, we acquired the idle Delaware City refinery and its related assets, including a petroleum product terminal, a petroleum products pipeline and an electric generation facility, on June 1, 2010 from affiliates of Valero for approximately $220.0 million in cash, consisting of approximately $170.0 million for the refinery, terminal and pipeline assets and $50.0 million for the power plant complex located on the property.
At the time of acquisition, we reached an agreement with the State of Delaware that provided for a five-year operating permit and up to approximately $45.0 million of economic support to re-start the facility, and negotiated a new long-term contract with the relevant union at the refinery. As of December 31, 2015, we had received $41.4 million in economic support from the State of Delaware under this agreement. We believe that the refinery’s ability to process lower quality crudes allows us to capture a higher margin as these lower quality crudes are typically priced at discounts to benchmark crudes, and to compete effectively in a region where product demand currently significantly exceeds refining capacity.
We completed the restart of the Delaware City Refinery in October 2011. Since our acquisition through December 31, 2015, we have invested in turnaround and re-start projects at Delaware City, as well as in the strategic development of crude rail unloading facilities. Crude delivered by rail to Delaware City can also be transported via barge to our Paulsboro refinery of other third party destinations. The Delaware City rail unloading facility, which was transferred to PBFX in 2014, allows our East Coast refineries to source WTI-based crudes from Western Canada and the Mid-Continent, which we believe, at times, may provide cost advantages versus traditional Brent-based international crudes.
Overview. The Delaware City refinery is located on an approximately 5,000-acre site, with access to waterborne cargoes and an extensive distribution network of pipelines, barges and tankers, truck and rail. Delaware City is a fully integrated operation that receives crude via rail at its crude unloading facilities, or ship or barge at its docks located on the Delaware River. The crude and other feedstocks are transported, via pipes, tostored in an extensive tank farm where they are stored untilprior to processing. In addition, there is a 17-bay, 50,00015-lane, 76,000 bpd capacity truck loading rack located adjacent to the refinery and a 23-mile interstate pipeline that are used to distribute clean products, which were transferredsold to PBFX in connectionconjunction with its acquisition of the Delaware CityDCR Products Pipeline and Truck Rack (as defined in “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements) in May 2015.
The Delaware City refinery has a throughput capacity of 190,000 bpd and a Nelson Complexity Index of 11.3. As a result of its configuration and process units, Delaware City has the capability of processing a slate of heavy crudes with a high concentration of high sulfur crudes and is one of the largest and most complex refineries on the East Coast. The Delaware City refinery is one of two heavy crude coking refineries, the other being our Paulsboro refinery, on the East Coast of the United States with coking capacity equal to approximately 25% of crude capacity.
The Delaware City refinery primarily processes a variety of medium to heavy, sour crude oils, but can run light, sweet crude oils as well. The refinery has large conversion capacity with its 82,000 bpd fluid catalytic cracking unit (“FCC unit,unit”), 47,000 bpd FCUfluid coking unit and 18,000 bpd hydrocracking unit with vacuum distillation. Hydrogen is provided via the refinery’s steam methane reformer and continuous catalytic reformer. The Delaware City refinery predominantly produces gasoline, diesel fuels and heating oil as well as certain lower value products such as petroleum coke and LPGs.

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The following table approximates the Delaware City refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Unit190,000
Vacuum Distillation Unit102,000
Fluid Catalytic Cracking Unit (FCC)82,000
Hydrotreating Units160,000
Hydrocracking Unit18,000
Catalytic Reforming Unit (CCR)43,000
Benzene / Toluene Extraction Unit15,000
Butane Isomerization Unit (ISOM)6,000
Alkylation Unit (Alky)11,000
Polymerization Unit (Poly)16,000
Fluid Coking Unit (FCU/ Fluid Coker)47,000
Feedstocks and Supply Arrangements. In April 2011, we entered into aWe source our crude and feedstock supply agreement with Statoil that expired on December 31, 2015. Pursuant to the agreement as amended in October 2012, we directed Statoil to purchase waterborne crude and other feedstocksoil needs for Delaware City primarily through short-term and Statoil purchased these products on the spot market or through term agreements. Accordingly, Statoil entered into, on our behalf, hedging arrangements to protect against changes in prices between the time of purchase and the time of processing the feedstocks. In addition to procurement, Statoil arranged transportation and insurance for these waterborne deliveries of crude and feedstock supply and we paid Statoil a per barrel fee for their procurement and logistics services. Subsequent to the termination of Statoil supply agreement, we purchase all of our crude and feedstock needs independently from a variety of suppliers on the spot market or through term agreements.
Refined Product Offtake.Yield and Distribution. The Delaware City refinery predominantly produces gasoline, jet fuel, ULSD and ultra-low sulfur heating oil as well as certain other products. We currently market and sell all of our refined products independently to a variety of customers on the spot market or through term agreements. Prior to June 30, 2013, we sold the bulk of Delaware City’s clean products to MSCG through an offtake agreement. Under the offtake agreement, MSCG purchased 100% of our finished clean products at Delaware City, which included gasoline, heating oil and jet fuel, as well as our intermediates. During the term of the offtake agreement, we sold the remainder of our refined products directly to a variety of customers on the spot market or through term agreements.


Inventory Intermediation Agreement.On June 26, 2013, we entered into an Inventory Intermediation Agreement (the “Inventory Intermediation Agreement”) with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. (“Inventory Intermediation Agreement”J. Aron”) to support the operations of the Delaware City refinery, which commenced upon the termination of the previous product offtake agreement with MSCG.agreement. Pursuant to thesuch Inventory Intermediation Agreement, J. Aron purchased certain of the finished and intermediate products (collectively the “Products”) located at the refinery upon termination of the MSCG product offtake agreement. J. Aron purchases the Products (as defined in “Item 1A - Risk Factors”) produced and delivered into the refinery'srefinery’s storage tanks on a daily basis. J. Aron further agrees to sell to us on a daily basis the Products delivered out of the refinery'srefinery’s storage tanks. On May 29, 2015,certain dates subsequent to the inception of the Inventory Intermediation Agreement, we and our subsidiary, DCR, entered into amendments to the amended and restated inventory intermediation agreements for bothagreement (as amended, the “Amended Delaware City and Paulsboro refineries (the “A&R Intermediation Agreements”Agreement”) with J. Aron pursuant to which certain terms of the existing Inventory Intermediation AgreementsAgreement were amended, including, among other things, pricing and an extension of the term. The most recent of these amendments was executed on September 8, 2017 which extended the term for a period of two years from the original expiry date ofto July 1, 2015, subject to certain early termination rights. In addition, the A&R Intermediation Agreements include one-year renewal clauses2019, which term may be further extended by mutual consent of both parties.the parties to July 1, 2020. At expiration, we will have to repurchase the inventories outstanding under the Amended Delaware Intermediation Agreement at that time.
Tankage Capacity. The Delaware City refinery has total storage capacity of approximately 10.0 million barrels. Of the total, 18 tanks with approximately 3.6 million barrels of storage capacity are dedicated to crude oil and other feedstock storage with the remaining approximately 6.4 million barrels allocated to finished products, intermediates and other products.
Energy and Other Utilities. Under normal operating conditions, the Delaware City refinery consumes approximately 65,000 MMBTU per day of natural gas.gas supplied via pipeline from third parties. The Delaware City refinery has a 280 MW power plant located on-siteon site that consists of two natural gas-fueled turbines with combined capacity of approximately 140 MW and four turbo-generatorsturbo generators with combined nameplate capacity of approximately 140 MW. Collectively, this power plant produces electricity in excess of Delaware City’s refinery load of approximately 90 MW. Excess electricity is sold into the Pennsylvania-New Jersey-

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Maryland,Jersey-Maryland, or PJM, grid. Steam is primarily produced by a combination of three dedicated boilers, two heat recovery steam generators on the gas turbines, and is supplemented by secondary boilers at the FCC and coker.Coker. Hydrogen is provided via the refinery’s steam methane reformer and continuous catalytic reformer. During 2018, we signed an agreement with a third-party for the construction and subsequent lease of a new 25 million cubic feet per day hydrogen facility (the “Hydrogen Facility”) which is expected to be completed in the first quarter of 2020. Upon completion, the Hydrogen Facility will provide us with additional complex crude processing capabilities.
Paulsboro Refinery
Acquisition. We acquired the entities that owned the Paulsboro refinery (including an associated natural gas pipeline) on December 17, 2010, from Valero for approximately $357.7 million, excluding working capital. The purchase price excluded inventory purchased on our behalf by MSCG and Statoil.
Overview. Paulsboro has a throughput capacity of 180,000 bpd and a Nelson Complexity Index of 13.2. The Paulsboro refinery is located on approximately 950 acres on the Delaware River in Paulsboro, New Jersey, just south ofnear Philadelphia and approximately 30 miles away from Delaware City. Paulsboro receives crude and feedstocks via its marine terminal on the Delaware River. Paulsboro is one of two operating refineries on the East Coast with coking capacity, the other being our Delaware City. Major units at the Paulsboro refinery include crude distillation units, vacuum distillation units, an FCC unit, an Alkylation unit, a delayed coking unit, lube oil processing units and a propane deasphalting unit.
City refinery. The Paulsboro refinery primarily processes a variety of medium and heavy, sour crude oils but can run light, sweet crude oils as well. The Paulsboro refinery predominantly produces gasoline, diesel fuels and jet fuel and also manufactures Group I base oils or lubricants. In addition to its finished clean products slate, Paulsboro produces asphalt and petroleum coke.


The following table approximates the Paulsboro refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day. 
Refinery Units
Nameplate
Capacity

Crude Distillation Units168,000
Vacuum Distillation Units83,000
Fluid Catalytic Cracking Unit (FCC)55,000
Hydrotreating Units141,000
Catalytic Reforming Unit (CCR)32,000
Alkylation Unit (Alky)11,000
Lube Oil Processing Unit12,000
Delayed Coking Unit (Coker)27,000
Propane Deasphalting Unit11,000
Feedstocks and Supply Arrangements. We have a contract with Saudi Aramco pursuant to which we have been purchasingpurchased up to approximately 100,000 bpd of crude oil from Saudi Aramco that is processed at Paulsboro. The crude purchased under this contract is priced off the ASCI.
Refined Product Offtake.Yield and Distribution. Prior to June 30, 2013, we sold the bulk of Paulsboro’s clean products to MSCG through an offtake agreement. With the exception of certainThe Paulsboro refinery predominantly produces gasoline, diesel fuels and jet fuel and lubricant sales, MSCG purchased 100% of our finished clean productsalso manufactures Group I base oils or lubricants and intermediates under the offtake agreement. During the term of the offtake agreement, we sold the remainder of our refined products directly to a variety of customers on the spot market or through term agreements. Subsequent to the termination of the offtake agreement, weasphalt. We market and sell all of our refined products independently to a variety of customers on the spot market or through term agreements under which we sell approximately 35% of our Paulsboro refinery'srefinery’s gasoline production.
Inventory Intermediation Agreement. On June 26, 2013, the Companywe entered into an Inventory Intermediation Agreement with J. Aron to support the operations of the Paulsboro refinery, which commenced upon the termination of the previous product offtake agreement with MSCG.agreement. Pursuant to thesuch Inventory Intermediation Agreement, J. Aron purchases the Products produced and delivered into the refinery'srefinery’s storage tanks on a daily basis. J. Aron further agrees to sell to us on a daily basis the Products delivered out of the refinery'srefinery’s storage tanks. On May 29, 2015,certain dates subsequent to the Company and J. Aron amendedinception of the Inventory Intermediation Agreement, we and our subsidiary, PRC, entered into amendments to the amended and restated inventory intermediation agreement (as amended, the “Amended Paulsboro Intermediation Agreement”, and collectively with the Amended Delaware Intermediation Agreement, referred to as the “Inventory Intermediation Agreements”) with J. Aron pursuant to which certain terms of the existing inventory intermediation agreementsInventory Intermediation Agreements were amended, including, among other things, pricing and an extension of the term. The most recent of these amendments was executed on September 8, 2017 which extended 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 clausesDecember 31, 2019, which may be further extended by mutual consent of both parties.the parties to December 31, 2020. At expiration, we will be required to repurchase the inventories outstanding under the Amended Paulsboro Intermediation Agreement at that time.

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Tankage Capacity. The Paulsboro refinery has total storage capacity of approximately 7.5 million barrels. Of the total, approximately 2.1 million barrels are dedicated to crude oil storage with the remaining 5.4 million barrels allocated to finished products, intermediates and other products.
Energy and Other Utilities.Under normal operating conditions, the Paulsboro refinery consumes approximately 30,00040,000 MMBTU per day of natural gas.gas supplied via pipeline from third parties. The Paulsboro refinery is virtuallymostly self-sufficient for its electrical power requirements.through a mix of gas and steam turbine generators. The Paulsboro refinery generation typically supplies approximately 90%about 57 MW of itsthe total 63 MW total refinery load. There are circumstances where available generation is greater than the total refinery load, through a combination of four generators with a nameplate capacity of 78 MW, in addition to a 30 MW gas turbine generator and two 15 MW steam turbine generators located atbut the Paulsboro refinery does not typically export power to the utility plant. In the event that Paulsboro requires additional electricity to operate the refinery,grid. If necessary, supplemental electrical power is available throughon a guaranteed basis from the local utility. The Paulsboro refinery is connected to the grid via three separate 69 KV69KV aerial feeders and has the ability to run entirely on imported power. Steam is primarily produced byin three boilers each with continuous rated capacity of 300,000-lb/hr at 900-psi. In addition, Paulsboro hasand a heat recovery steam generator andfed by the exhaust from the gas turbine. In addition, there are a number of waste heat boilers and furnace stack economizers throughout the refinery that supplement the steam generation capacity. Paulsboro’sBackup capability is


provided by package boilers. The Paulsboro refinery’s current hydrogen needs are met by the hydrogen supply from the reformer. In addition, the refinery employs a standalone steam methane reformer that is capable of producing 10 MMSCFD of 99% pure hydrogen.reformer. This ancillary hydrogen plant is utilized as a back-up source of hydrogen for the refinery’s process units.
Toledo Refinery
Acquisition. Through our subsidiary, Toledo Refining, we acquired the Toledo refinery on March 1, 2011, from Sunoco for approximately $400.0 million, excluding working capital. We also purchased refined and certain intermediate products inventory for approximately $299.6 million, and MSCG purchased the refinery’s crude oil inventory on our behalf. Additionally, included in the terms of the sale was a five-year participation payment of up to $125.0 million payable to Sunoco based upon post-acquisition earnings of the refinery, which was paid in full.
Overview. The Toledo has a throughput capacity of approximately 170,000 bpd and a Nelson Complexity Index of 9.2. Toledorefinery primarily processes a slate of light, sweet crudes from Canada, the Mid-Continent, the Bakken region and the U.S. Gulf Coast. Toledo produces finished products including gasoline and ULSD, in addition to a variety of high-value petrochemicals including benzene, toluene, xylene, nonene and tetramer.
The Toledo refinery is located on a 282-acre site near Toledo, Ohio, approximately 60 miles from Detroit. Major units at the Toledo refinery include a crude unit, an FCC unit, an alkylation unit, a hydrocracker and a UDEX unit. Crude is delivered to the Toledo refinery through three primary pipelines: (1) Enbridge from the north, (2) Capline from the south and (3) Mid-Valley from the south. Crude is also delivered to a nearby terminal by rail and from local sources by truck to a truck unloading facility within the refinery.
The following table approximates the Toledo refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Unit170,000
Fluid Catalytic Cracking Unit (FCC)79,000
Hydrotreating Units95,000
Hydrocracking Unit (HCC)45,000
Catalytic Reforming Units45,000
Alkylation Unit (Alky)10,000
Polymerization Unit (Poly)7,000
UDEX Unit (BTX)16,300
Feedstocks and Supply Arrangements. We currently fully source our own crude oil needs for Toledo. Prior to July 31, 2014, we had a crude oil acquisition agreement with MSCG pursuant to which we directed MSCG to purchase crudeToledo primarily through short-term and other feedstocks for Toledo. MSCG purchased crudespot market agreements.
Refined Product Yield and feedstocks on the spot market. Accordingly, MSCG entered into, on our behalf, hedging arrangements to protect against changesDistribution. Toledo produces finished products including gasoline and ULSD, in prices between the time of purchase and the time of processing the feedstocks. In addition to procurement, MSCG arranged transportationa variety of high-value petrochemicals including benzene, toluene, xylene, nonene and insurance for the crude and feedstock supply and we paid MSCG a per barrel fee for their procurement and logistics services. We paid MSCG on a daily basis for the corresponding volume of crude or feedstocks two days after they were consumed in conjunction with the refining process.

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Product Offtake.tetramer. Toledo is connected, via pipelines, to an extensive distribution network throughout Ohio, Illinois, Indiana, Kentucky, Michigan, Pennsylvania and West Virginia. The finished products are transported on pipelines owned by Sunoco Logistics Partners L.P. and Buckeye Partners. In addition, we have proprietary connections to a variety of smaller pipelines and spurs that help us optimize our clean products distribution. A significant portion of Toledo’s gasoline and ULSD are distributed through the approximately 2836 terminals in this network.
In March 2011, we entered intoWe have an agreement with Sunoco whereby Sunoco purchases gasoline and distillate products representing approximately one-third of the Toledo refinery’s gasoline and distillates production. The agreement had a three yearan initial three-year term, subject to certain early termination rights. In March 2014,2017, the agreement was renewed and extended for another three yeara two-year term. We are currently in the process of negotiating a renewal of this agreement. We sell the bulk of the petrochemicals produced at the Toledo refinery through short-term contracts or on the spot market and the majority of the petrochemical distribution is done via rail.
Tankage Capacity. The Toledo refinery has total storage capacity of approximately 4.5 million barrels. The Toledo refinery receives its crude through pipeline connections and a truck rack. Of the total, approximately 1.3 million barrels are dedicated to crude oil storage with the remaining 3.2 million barrels allocated to intermediates and products. A portion of storage capacity dedicated to crude oil and finished products was transferredsold to PBFX in conjunction with its acquisition of the Toledo Storage Facility (as defined in “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements) in December 2014.


Energy and Other Utilities. Under normal operating conditions, the Toledo refinery consumes approximately 17,00020,000 MMBTU per day of natural gas.gas supplied via pipeline from third parties. The Toledo refinery purchases its electricity from a local utilitythe PJM grid and has a long-term contract to purchase hydrogen and steam from a local third partythird-party supplier. In addition to the third partythird-party steam supplier, Toledo consumes a portion of the steam that is generated by its various process units.
Chalmette Refinery
Acquisition. On November 1, 2015, we acquired from ExxonMobil, Mobil Pipe Line Company and PDV Chalmette, L.L.C. (collectively, the “Chalmette Sellers”), the ownership interests of Chalmette Refining, which owns the Chalmette refinery and related logistics assets. Subsequent to the closing of the Chalmette Acquisition, Chalmette Refining is a wholly-owned subsidiary of PBF Holding. The aggregate purchase price for the Chalmette Acquisition was $322.0 million in cash, plus estimated inventory and working capital of $243.3 million, which is subject to final valuation upon agreement by both parties.
Overview. The Chalmette refinery is located on a 400-acre site outside ofnear New Orleans, Louisiana. It is a dual-train coking refinery with a Nelson Complexity Index of 12.7 and is capable of processing both light and heavy crude oil through its 189,000 bpd crude unitunits and downstream Coker, FCC and alkylation units. 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 LOOPLouisiana Offshore Oil Port facility through a third partythird-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 areIn addition, there is also 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 with approximately 7.5 million barrels of shell capacity.facility.
The Chalmette refinery primarily processes a variety of light and heavy crude oils. The Chalmette refinery predominantly produces gasoline, diesel fuels and jet fuel and also manufactures high-value petrochemicals including benzene and xylene.
The following table approximates the Chalmette refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery UnitsNameplate
Capacity

Crude Distillation Unit189,000
Fluid Catalytic Cracking Unit (FCC)72,000
Hydrotreating Units158,000186,000
Delayed Coker29,000
Catalytic Reforming UnitsUnit22,00040,000
Alkylation Unit (Alky)15,000


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Feedstocks and Supply Arrangements. In connection withWe source our crude oil and feedstock needs for Chalmette through connections to the Chalmette Acquisition onCAM and MOEM pipelines as well as our marine terminal. On November 1, 2015, we assumedentered into a market-based crude supply arrangementagreement with PDVSAPetróleos de Venezuela S.A. (“PDVSA”) that has a ten yearten-year term with a renewal option for an additional five years, subject to certain early termination rights. The pricing for the crude supply is market based and is agreed upon on a quarterly basis by both parties. Additionally, we obtainWe have not sourced crude and feedstocks from other sources through connectionsoil under this agreement since the third quarter of 2017 as PDVSA has suspended deliveries due to the CAM and MOEM Pipelines as well as ship docks and truck racks.parties’ inability to agree to mutually acceptable payment terms.
Refined Product OfftakeYield and Distribution.. The Chalmette refinery predominantly produces gasoline and diesel fuels and also manufactures high-value petrochemicals including benzene and xylene. Products produced at the Chalmette refinery are transferred to customers through pipelines, the marine terminal and truck rack. The majority of theirour clean products are delivered to customers via pipelines. The Chalmette refinery'sOur ownership of the Collins Pipeline and T&M Terminal provide itprovides Chalmette with strategic access to Southeast and East Coast markets through third partythird-party logistics. The Chalmette refinery has an offtake agreement for its truck rack whereby ExxonMobil purchases approximately 50% of the 14,000 barrel per day capacity.
Tankage CapacityCapacity.. Chalmette has a total tankage capacity of approximately 7.58.1 million barrels. Of this total, approximately 2.12.6 million barrels are allocated to crude oil storage with the remaining 5.45.5 million barrels allocated to intermediates and products.
Energy and Other UtilitiesUtilities.. Under normal operating conditions, the Chalmette refinery consumes approximately 30,000 MMBTU per day of natural gas.gas supplied via pipeline from third parties. The Chalmette refinery purchases its electricity from a local utility and has a long-term contract to purchase hydrogen and steam from third-party suppliers.


Coker Project: The Chalmette refinery is currently in the process of restarting its idled 12,000 barrel per day coker unit to increase the refinery’s long-term feedstock flexibility and be positioned to benefit from potential dislocations in the price for heavy and high-sulfur feedstocks. The unit is expected to be in service by the end of 2019 and is expected to increase the refinery’s total coking capacity to approximately 42,000 barrels per day.
Torrance Refinery
Acquisition. On July 1, 2016, we acquired from ExxonMobil and its subsidiary, Mobil Pacific Pipe Line Company, the Torrance refinery and related logistics assets (collectively, the “Torrance Acquisition”).
Overview. The Torrance refinery is located on 750 acres in Torrance, California. It is a high-conversion crude, delayed-coking refinery. It is capable of processing both heavy and medium crude oil through its crude unit and downstream units. In addition to refining assets, the Torrance Acquisition 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 logistics asset 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 that supplies jet fuel to the Los Angeles airport.
The following table approximates the Torrance refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Unit155,000
Vacuum Distillation Unit102,000
Fluid Catalytic Cracking Unit88,000
Hydrotreating Units151,000
Hydrocracking Unit23,000
Alkylation Unit27,000
Delayed Coker53,000
Feedstocks and Supply Arrangements. The Torrance refinery primarily processes a variety of medium and heavy crude oils. In connection with the closing of the Torrance Acquisition, we entered into a crude supply agreement with ExxonMobil for approximately 60,000 bpd of crude oil that can be processed at our Torrance refinery. This crude supply agreement has a five-year term with an automatic renewal feature unless either party gives thirty-six months prior written notice. Additionally, we obtain crude and feedstocks from other sources through connections to third-party pipelines as well as ship docks and truck racks.
Refined Product Yield and Distribution. The Torrance refinery predominantly produces gasoline, jet fuel and diesel fuels. Products produced at the Torrance refinery are transferred to customers through pipelines, the marine terminal and truck rack. The majority of clean products are delivered to customers via pipelines. Concurrently with the acquisition of the refinery on July 1, 2016, we entered into an offtake agreement with ExxonMobil pursuant to which ExxonMobil purchases up to 50% of our gasoline production. This offtake agreement had an initial term of three years and was scheduled to automatically renew for another three-year term unless either party provided six-months written notice of its intent to terminate the agreement. This contract has been terminated and will not be renewed upon expiration on July 1, 2019. On a prospective basis, we will market and sell all of our refined products independently to a variety of customers either on the spot market or through term agreements.


Tankage Capacity. Torrance has a total tankage capacity of approximately 8.6 million barrels. Of this total, approximately 2.1 million barrels are allocated to crude oil storage with the remaining 6.5 million barrels allocated to intermediates and products.
Energy and Other Utilities. Under normal operating conditions, the Torrance refinery consumes approximately 45,000 MMBTU per day of natural gas supplied via pipeline from third partyparties. The Torrance refinery generates some power internally using a combination of steam and gas turbines and purchases any additional needed power from the local utility. The Torrance refinery has a long-term contract to purchase hydrogen from a third-party supplier.
Principal Products
Our refineries make various grades of gasoline, distillates (including diesel fuel, jet fuel, and ULSD) and other products from crude oil, other feedstocks, and blending components. We sell these products through our commercial accounts, and sales with major oil companies. For the years ended December 31, 2015, 20142018, 2017 and 2013,2016, gasoline and distillates accounted for 88.0%84.8%, 86.0%84.1% and 88.6%88.1% of our revenues, respectively.
Customers
We sell a variety of refined products to a diverse customer base. The majority of our refined products are primarily sold through short-term contracts or on the spot market. However, we do have product offtake arrangements for a portion of our clean products. For the years ended December 31, 20152018, 2017 and 2014,2016, no single customer accounted for 10% or more of our revenues, respectively. Following the Chalmette Acquisition on November 1, 2015, ExxonMobil and its affiliates represented approximately 18% of our total trade accounts receivable as of December 31, 2015. As of December 31, 2014,2018 and 2017, no single customer accounted for 10% or more of our total trade accounts receivable.
For the year ended December 31, 2013, MSCG and Sunoco accounted for 29% and 10% of our revenues, respectively.
Seasonality
Demand for gasoline and diesel is generally higher during the summer months than during the winter months due to seasonal increases in highway traffic and construction work. Decreased demand during the winter months can lower gasoline and diesel prices. As a result, our operating results for the first and fourth calendar quarters may be lower than those for the second and third calendar quarters of each year. Refining margins remain volatile and our results of operations may not reflect these historical seasonal trends. Additionally, the degree of seasonality may differ by the geographic areas in which we operate.
Competition
The refining business is very competitive. We compete directly with various other refining companies on the East, Gulf and GulfWest Coasts and in the Mid-Continent, with integrated oil companies, with foreign refiners that import products into the United States and with producers and marketers in other industries supplying alternative forms of energy and fuels to satisfy the requirements of industrial, commercial and individual consumers. Some of our competitors have expanded the capacity of their refineries and internationally new refineries are coming on line which could also affect our competitive position.
Profitability in the refining industry depends largely on refined product margins, which can fluctuate significantly, as well as crude oil prices and differentials between the prices of different grades of crude oil, operating efficiency and reliability, product mix and costs of product distribution and transportation. Certain of our competitors that have larger and more complex refineries may be able to realize lower per-barrel costs or higher margins per barrel of throughput. Several of our principal competitors are integrated national or international oil companies that are larger and have substantially greater resources. Because of their integrated operations and larger capitalization, these companies may be

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more flexible in responding to volatile industry or market conditions, such as shortages of feedstocks or intense price fluctuations. Refining margins are frequently impacted by sharp changes in crude oil costs, which may not be immediately reflected in product prices.


The refining industry is highly competitive with respect to feedstock supply. Unlike certain of our competitors that have access to proprietary controlled sources of crude oil production available for use at their own refineries, we obtain substantially all of our crude oil and substantially all other feedstocks from unaffiliated sources. The availability and cost of crude oil isand feedstock are affected by global supply and demand. We have no crude oil reserves and are not engaged in the exploration or production of crude oil. We believe, however, that we will be able to obtain adequate crude oil and other feedstocks at generally competitive prices for the foreseeable future.
Our complex refinery system and sourcing optionality may position us favorably to benefit from changes in certain market conditions and governmental or industry regulations, such as the pending requirement from the International Maritime Organization (“IMO”) related to the reduction in sulfur content of marine fuels to a maximum of 0.5% effective January 1, 2020. Due to our relative refinery complexity and ample coking capacity, we anticipate being able to favorably capture the benefit from potential product margin uplift associated with an increase in demand for low sulfur fuel or a widening of the discount on high-sulfur feedstocks as a result of the new IMO regulations.
Agreements with PBFX
Beginning with the completion of the PBFX Offering, we have entered into a series of agreements with PBFX, including commercial and operational agreements. Each of these agreements and their impact to our operations is outlined below.
Contribution Agreements
On May 8, 2014, PBFX, PBF GP, PBF Energy, PBF LLC, PBF Holding, DCR, Delaware City Terminaling Company LLC (“Delaware City Terminaling”) and TRC entered into the Contribution and Conveyance Agreement (the “Contribution Agreement I”). On May 14, 2014, concurrent withImmediately prior to the closing of certain contribution agreements, which PBF LLC entered into with PBFX (as defined in the PBFX Offering,table below, and collectively referred to as the following transactions occurred“Contribution Agreements”), we contributed certain assets to PBF LLC. PBF LLC in turn contributed those assets to PBFX pursuant to the Contribution Agreement I:
DCR distributed all of the interests in Delaware City Terminaling and TRC distributed the Toledo Truck Terminal, in each case, toAgreements. Certain proceeds received by PBF Holding at their historical cost.
PBF Holding contributed, at their historical cost, (i) all of the interests in Delaware City Terminaling and (ii) the Toledo Truck Terminal toLLC from PBFX in exchange for (a) 74,053 common units and 15,886,553 subordinated units representing an aggregate 50.2% limited partner interest in PBFX, (b) all of PBFX’s incentive distribution rights, (c) the right to receive a distribution of $30.0 million from PBFX as reimbursement for certain preformation capital expenditures attributable to the contributed assets, and (d) the right to receive a distribution of $298.7 million; and in connectionaccordance with the foregoing, PBFX redeemed PBF Holding’s initial partner interests in PBFX for $1,000.
PBF Holding distributed to PBF LLC (i) its interest in PBF GP, (ii) the common units, subordinated units and incentive distribution rights, (iii) the right to receive a distribution of $30.0 million as reimbursement for certain preformation capital expenditures, and (iv) the right to receive a distribution of $298.7 million.
On September 30, 2014, PBF Holding, PBF LLC and PBFX closed the transaction contemplated by the Contribution Agreement dated September 16, 2014 (the “Contribution Agreement II”). Pursuant to the terms of the Contribution Agreement II, PBF Holding distributed to PBF LLC all of the equity interests of DCT II, which assets consisted solely of the DCR West Rack, immediately prior to the transfer of such equity interestsAgreements were subsequently contributed by PBF LLC to PBFX.us. The DCR West Rack was previously ownedContribution Agreements include the following:
Contribution AgreementEffective DateAssets ContributedTotal Consideration
Contribution Agreement I5/8/2014DCR Rail Terminal and the Toledo Truck Terminal74,053 PBFX common units and 15,886,553 PBFX subordinated units
Contribution Agreement II9/16/2014DCR West Rack$135.0 million in cash and $15.0 million through the issuance of 589,536 PBFX common units
Contribution Agreement III12/2/2014Toledo Storage Facility$135.0 million in cash and $15.0 million through the issuance of 620,935 PBFX common units
Contribution Agreement IV5/5/2015DCR Products Pipeline and Truck Rack$112.5 million in cash and $30.5 million through the issuance of 1,288,420 PBFX common units
Contribution Agreement V8/31/2016Torrance Valley Pipeline$175.0 million in cash
Contribution Agreement VI2/15/2017Paulsboro Natural Gas Pipeline$11.6 million affiliate promissory note
Contribution Agreements VII-X7/16/2018Development Assets$31.6 million through the issuance of 1,494,134 PBFX common units


Pursuant to Contribution Agreement V on August 31, 2016, we contributed 50% of the issued and operated by PBF Holding’s subsidiary, DCT II, and is located at the Company's Delaware City refinery. PBFX paidoutstanding limited liability company interests of Torrance Valley Pipeline Company LLC (“TVPC”) to PBF LLC total considerationLLC. PBFX then acquired 50% of $150.0 million, consistingthe issued and outstanding limited liability company interests of $135.0 millionTVPC. TVPC’s assets consist of cashthe Torrance Valley Pipeline which include the M55, M1 and $15.0 millionM70 pipeline systems, including 11 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 common units, or 589,536 common units,Op Co, has the sole ability to direct the activities of TVPC that most significantly impact its economic performance. Accordingly, PBFX, and not us, is considered to be the primary beneficiary for accounting purposes and as a result PBFX fully consolidates TVPC. Subsequent to Contribution Agreement V, we record an investment in exchangeequity method investee on our consolidated balance sheet for the DCR West Rack.50% interest in TVPC that we own. The carrying value of our equity method investment in TVPC was $169.5 million and $171.9 million at December 31, 2018 and 2017, respectively.
On December 11, 2014, PBF Holding, PBF LLC and PBFX closed the transaction contemplated by thePursuant to Contribution Agreement dated December 2, 2014 (“Contribution Agreement III”). Pursuant to the Contribution Agreement III, PBF Holding distributed to PBF LLCVI entered into on February 15, 2017, we contributed all of the issued and outstanding limited liability company interests of Toledo Terminaling, whose assets consisted of the Toledo Storage Facility. PBF LLC then contributed to PBFX all of the equity interests of Toledo Terminaling for total consideration payable to PBF LLC of $150.0 million, consisting of $135.0 million of cash and $15.0 million of PBFX common units, or 620,935 common units.
On May 14, 2015, PBF Holding, PBF LLC and PBFX closed the transactions contemplated by the Contribution Agreement dated May 5, 2015 (“Contribution Agreement IV”). Pursuant to the Contribution Agreement IV, PBF Holding distributed all of the equity interests of DelawarePaulsboro Natural Gas Pipeline Company LLC (“DPC”) and Delaware City Logistics Company LLC (“DCLC”PNGPC”) to PBF LLC immediately prior toLLC. PBFX Op Co, in turn acquired the contribution of suchlimited liability company interests byin PNGPC from PBF LLC to PBFX. The assets consisted of the Delaware City Products Pipeline and Truck Rack, for a total consideration payable to PBF LLC of $143.0 million, consisting of $112.5 million of cash and $30.5 million of PBFX common units, or 1,288,420 common units.

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Commercial Agreements
Inin 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 railContribution Agreement VI effective February 28, 2017. PNGPC owns and truck terminaling and storage services to PBF Holding and PBF Holding has committed to provide PBFX with minimum fees based on minimum monthly throughput volumes. The fees under each of these agreements are indexed for inflation and any increase in operating costs for providing such services to us. Prior to the PBFX Offering, the DCR Rail Terminal, Toledo Truck Terminal, the DCR West Rack and the Toledo Storage Facility and other assets contributed to PBFX subsequent to the PBFX Offering were owned, operated and maintained by PBF Holding. Therefore, PBF Holding did not previously pay a fee for the utilization of the facilities. Below is a summary of the agreements and corresponding fees for the use of each of the assets.
2014 Commercial agreements
Delaware City Rail Terminaling Services Agreement
On May 14, 2014, concurrent with the closing of the PBFX Offering, PBF Holding entered into a rail terminaling services agreement with PBFX to obtain terminaling services at the DCR Rail Terminaloperates an existing interstate natural gas pipeline that serves our Paulsboro refinery (the “DCR Terminaling Agreement”“Paulsboro Natural Gas Pipeline”).The DCR Terminaling Agreement terminates on the first December 31st following the seventh anniversary of the closing of the PBFX Offering and may be extended, at PBF Holding’s option, for up to two additional five-year terms. Under the DCR Terminaling Agreement, PBF Holding is obligated to throughput aggregate volumes of crude oil of at least 85,000 bpd per quarter (calculated on a quarterly average basis) for a terminaling service fee of $2.00 per barrel,, which will decrease to $0.50 per barrel to the extent volumes exceed the minimum throughput commitment. PBF Holding also pays PBFX for providing related ancillary services at the terminal that are specified in the agreement. The terminaling service fee is subject to (i) increase or decrease on January 1 of each year, beginning on January 1, 2015, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) increase by the increase in any operating costs that increase greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the DCR Terminaling Agreement. Effective January 1, 2015, the terminaling service fee was increased to $2.032 per barrel up to the minimum throughput commitment and $0.508 per barrel for volumes that exceed the minimum throughput commitment.
Toledo Truck Unloading & Terminaling Services Agreement
On May 14, 2014, concurrent with the closing of the PBFX Offering, PBF Holding entered into a truck unloading and terminaling services agreement with PBFX to obtain terminaling services at the Toledo Truck Terminal, (as amended the “Toledo Terminaling Agreement”). The Toledo Terminaling Agreement terminates on the first December 31st following the seventh anniversary of the closing of the PBFX Offering and may be extended, at PBF Holding’s option, for up to two additional five-year terms. Under the Toledo Terminaling Agreement, PBF Holding was obligated to throughput aggregate volumes of crude oil of at least 4,000 bpd (calculated on a quarterly average basis) for a terminaling service fee of $1.00 per barrel. The Toledo Terminaling Agreement was amended and restated effective as of June 1, 2014, to among other things, increase the minimum throughput volume commitment from 4,000 bpd to 5,500 bpd beginning August 1, 2014. PBF Holding also pays PBFX for providing related ancillary services at the terminal which are specified in the Toledo Terminaling Agreement. The terminaling service fee is subject to (i) increase or decrease on January 1 of each year, beginning on January 1, 2015, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) adjustment by the amount of any increases in any operating costs greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the Toledo Terminaling Agreement. Effective January 1, 2015, the terminaling service fee was increased to $1.016 per barrel.
Delaware City West Ladder Rack Terminaling Services Agreement
On October 1, 2014, PBF Holding and DCT II entered into a seven year terminaling services agreement (the “West Ladder Rack Terminaling Agreement”) under which PBFX, through DCT II, provides rail terminaling services to PBF Holding. DCT II was merged with and into Delaware City Terminaling, a wholly-owned subsidiary of PBFX, with all property, rights, liabilities and obligations of DCT II vesting in Delaware City Terminaling as the surviving company. The agreement may be extended by PBF Holding for two additional five year periods. Under the West Ladder Rack Terminaling Agreement, PBF Holding is obligated to throughput aggregate volumes of crude oil of at least 40,000 bpd for a terminaling service fee equal to $2.20 per barrel for all volumes of crude oil throughput up to the minimum throughput commitment, and $1.50 per barrel for all volumes of crude oil throughput in excess of the minimum throughput commitment, in any contract quarter. PBF Holding also pays PBFX for providing related ancillary services at the terminal which are specified in the West Ladder Rack Terminaling Agreement. The terminaling service fee is subject to (i) increase or decrease on January 1 of each year, beginning on January 1, 2016, by the amount of any change in the Producer Price Index, provided

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that the fee may not be adjusted below the initial amount and (ii) increase by the increase in any operating costs that increase greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the West Ladder Rack Terminaling Agreement.
Toledo Storage Facility Storage and Terminaling Services Agreement
On December 12, 2014, PBF Holding and Toledo Terminaling entered into a ten-year storage and terminaling services agreement (the “Toledo Storage Facility Storage and Terminaling Agreement”) under which PBFX, through Toledo Terminaling, will provide storage and terminaling services to PBF Holding in return for storage and throughput fees. The Toledo Storage Facility Storage and Terminaling Agreement can be extended by PBF Holding for two additional five-year periods.
The Toledo Storage Facility Storage and Terminaling Agreement requires PBFX to accept, redeliver and store all products tendered by PBF Holding in the tanks and load products at the storage facility on behalf of PBF Holding up to the effective operating capacity of each tank, the loading capacity of the products rack and the overall capacity of the Toledo Storage Facility. PBF Holding pays a fee of $0.50 per barrel of shell capacity dedicated to PBF Holding under the Toledo Storage Facility Storage and Terminaling Agreement. The minimum throughput commitment for the propane storage and loading facility is at least 4,400 bpd (calculated on a quarterly average basis) for a fee equal to $2.52 per barrel of product loaded up to the minimum throughput commitment with no fee reduction for barrels loaded in excess of the minimum throughput commitment. The storage and terminaling service fee is subject to (i) increase or decrease effective January 1 of each year, beginning January 1, 2016, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) adjustment by the amount of any increases in operating costs greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services under the Toledo Storage Facility Storage Terminaling Agreement.
PBFX is required to maintain the Toledo Storage Facility in a condition and with a capacity sufficient to store and handle a volume of PBF Holding's products at least equal to the current operating capacity for the storage facility as a whole subject to interruptions for routine repairs and maintenance and force majeure events. Failure to meet such obligations may result in a reduction of fees payable under the Toledo Storage Facility Storage and Terminaling Agreement.
2015 Commercial Agreements
Delaware Pipeline Services Agreement
PBF Holding entered into a pipeline services agreement with PBFX (the “Delaware Pipeline Services Agreement”). Under the Delaware Pipeline Services Agreement, PBFX provides PBF Holding with pipeline throughput services in return for throughput fees. The Delaware Pipeline Services Agreement has an initial term of approximately ten years, after which PBF Holding has the option to extend the agreement for two additional five year periods, under which PBFX provides pipeline services to PBF Holding on the Delaware Products Pipeline. The minimum throughput commitment for the pipeline facility is 50,000 bpd, at an initial fee equal to $0.5266 per barrel for all volumes of product received on the pipeline equal to at least the minimum throughput commitment, in any contract quarter. The pipeline service fee is subject to (i) increase or decrease effective as of July 1 of each year, by the amount of any change in any inflationary index promulgatedregulation by the Federal Energy Regulatory Commission (“FERC”). In connection with the PNGPC contribution agreement, PBFX constructed a new pipeline to replace the existing pipeline, which commenced services in accordanceAugust 2017.
In consideration for the PNGPC limited liability company interests, PBFX delivered to PBF LLC (i) an $11.6 million affiliate promissory note in favor of Paulsboro Refining Company LLC, one of our wholly-owned subsidiaries (the “Promissory Note”), (ii) an expansion rights and right of first refusal agreement in favor of PBF LLC with FERC’s indexing methodology or (ii)respect to the new pipeline and (iii) an assignment and assumption agreement with respect to certain outstanding litigation involving PNGPC and the existing pipeline. As a result of the completion of the Paulsboro Natural Gas Pipeline in the event that FERC terminatesfourth quarter of 2017, we received full payment for the affiliate Promissory Note.
On July 16, 2018, PBFX entered into four contribution agreements with PBF LLC pursuant to which we contributed to PBF LLC certain of its indexing methodology duringsubsidiaries (the “Development Assets Contribution Agreements”). Pursuant to the termDevelopment Asset Contribution Agreements, we contributed all of the agreement, byissued and outstanding limited liability company interests of: Toledo Rail Logistics Company LLC (“TRLC”), whose assets consist of a percentage equal toloading and unloading rail facility located at the change inToledo refinery (the “Toledo Rail Products Facility”); Chalmette Logistics Company LLC (“CLC”), whose assets consist of a truck loading rack facility (the “Chalmette Truck Rack”) and a rail yard facility (the “Chalmette Rosin Yard”), both of which are located at the Consumer Price Index- All Urban ConsumersChalmette refinery; Paulsboro Terminaling Company LLC (“CPI-U”PTC”). Effective July 2015,, whose assets consist of a lube oil terminal facility located at the pipeline service fee was raised to $0.5507 per barrel, due toPaulsboro refinery (the “Paulsboro Lube Oil Terminal”); and DCR Storage and Loading Company LLC (“DSLC”), whose assets consist of an increase in the FERC tariff.
Delaware City Truck Loading Service Agreement
PBF Holding entered into a terminaling services agreement with PBFX (the “Delaware City Truck Loading Agreement”). Under the Delaware City Truck Loading Agreement, PBFX provides PBF Holding with terminaling services in return for fees. The Delaware City Truck Loading Agreement has an initial term of approximately ten years, after which PBF Holding has the option to extend the agreement for two additional five year periods, under which PBFX provides loading services to PBF Holdingethanol storage facility located at the Delaware City Terminal. The minimum throughput commitment forrefinery (the “Delaware Ethanol Storage Facility” and collectively with the truck rack is (i) at least 30,000 bpd of gasoline, dieselToledo Rail Products Facility, the Chalmette Truck Rack, the Chalmette Rosin Yard, and heating oil for a fee equalthe Paulsboro Lube Oil Terminal, the “Development Assets”) to $0.462 per barrel, and (ii) at least 5,000 bpd for LPGs for a fee equal to $2.52 per barrel for all volumes of product loaded into trucks atPBF LLC. PBFX Op Co, in turn acquired the products terminal equal to at least the minimum throughput commitment, in any contract quarter.
The terminaling service fee is subject to (i) increase or decrease effective as of January 1 of each year, commencing on January 1, 2016, by the amount of any changelimited liability company interests in the Producer Price Index provided thatDevelopment Assets from PBF LLC in connection with the Development Assets Contribution Agreements effective July 31, 2018.


Commercial Agreements
PBFX currently derives the majority of its revenue from long-term, fee-based commercial agreements with us, the majority of which include a minimum volume commitment (“MVC”) and are supported by contractual fee may not be adjusted below the initial amountescalations for inflation adjustments and (ii) adjustment by the amount of anycertain increases in operating costs greatercosts. We believe 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.
Refer to “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements for further discussion regarding the Producer

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Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the Delaware City Truck Loading Services Agreement.
Operational Agreements
PBF Holding and certain of its affiliates have entered into operationalcommercial agreements with PBFX for the use of centralized corporate services. In accordance with such agreements, PBF Holding receives fees from PBFX for use of these services. Below is a summary of the agreements and corresponding fees that PBFX pays PBF Holding.PBFX.
Third Amended and Restated Omnibus Agreement
Under the omnibus agreement (as amended from time to time, the “Omnibus Agreement”), PBFX, among other things, reimburses related affiliates, including PBF Holding, for services provided to PBFX. The omnibus agreement entered into on May 14, 2014 (the “Original Omnibus Agreement”) addressed the following matters:

PBFX's obligation to pay PBF LLC an administrative fee, in the amount of $2.30 million per year, for the provision by PBF LLC of centralized corporate services (which fee is inIn addition to certain expenses of PBF GP and its affiliates that are reimbursed under the PBFX partnership agreement;
PBFX’s obligation to reimburse PBF LLC for the salaries and benefits costs of employees who devote more than 50% of their time to PBFX;
PBFX’s agreement to reimburse PBF Holding for all other direct or allocated costs and expenses incurred by PBF LLC on PBFX's behalf;
PBF LLC’s agreement not to compete with PBFX under certain circumstances, subject to certain exceptions;
PBFX’s right of first offer for ten years to acquire certain logistics assets retained by PBF Energy following the PBFX Offering, including certain logistics assets that PBF LLC or its subsidiaries may construct or acquire in the future, subject to certain exceptions;
a license to use the PBFX trademark and name; and
PBF Holding’s agreement to reimburse PBFX for certain expenditures up to $20.0 million per event (net of any insurance recoveries) related to the Contributed Assets for a period of five years aftercommercial agreements described above, at the closing of the PBFX Offering, and PBFX'sPBFX entered into an omnibus agreement, to bear the costs associated with the prior expansion of the DCR Rail Terminal crude unloading capability.
On September 30, 2014, the Original Omnibus Agreement waswhich has been amended and restated in connection with the DCR West Rack Acquisition (the “A&R Omnibus Agreement”).closing of each of the Contribution Agreements with PBF GP, PBF LLC and us. The omnibus agreement addresses the payment of an annual fee for the provision of various general and administrative fee to be paid by the Partnership toservices and reimbursement of salary and benefit costs for certain PBF Energy increased from $2.3 million to approximately $2.5 million.employees. On December 12, 2014,July 31, 2018, we entered into the A&RFifth Amended and Restated Omnibus Agreement was(as amended, and restatedthe “Omnibus Agreement”) in connection with the Toledo Storage Facility Acquisition (the “Second A&R Omnibus Agreement”). The Second A&R Omnibus Agreement clarified the reimbursements to be made by the Partnership to PBF LLC and from PBF LLC to the Partnership and increased the annual administrative fee to be paid by the Partnership to PBF Energy from approximately $2.5 million to $2.7 million. Pursuant to the terms of the Original Omnibus Agreement, as amended by the A&R Omnibus Agreement and the Second A&R Omnibus Agreement the annual administrative fee of $2.7 million per year was reduced to $2.2 million per year effective as of January 1, 2015. On May 15, 2015, the Second A&R Omnibus Agreement was amended and restated in connection with the Delaware City Products Pipeline and Truck Rack Acquisition (the “Third A&R Omnibus Agreement”)Development Assets Contribution Agreements, resulting in an increase inof the estimated annual administrative fee from $2.2 million to $2.35$7.0 million.
Third Amended and Restated Operation and Management Services and Secondment Agreement
On May 14, 2014, PBF Holding and certain of its subsidiariesIn connection with the PBFX Offering, PBFX also entered into an operation and management services and secondment agreement (the “Services Agreement”) with PBFX,us and certain of our subsidiaries, pursuant to which PBF Holding and its subsidiarieswe provide PBFX with the personnel necessary for PBFX to perform its obligations under its commercial agreements. Under the agreement, PBFX reimburses PBF Holdingus for the use of such employees and the provision of certain infrastructure-related services to the extent applicable to its operations, including storm water discharge and waste water treatment, steam, potable water, access to certain roads and grounds, sanitary sewer access, electrical power, emergency response, filter press, fuel gas, API solids treatment, fire water and compressed air. In addition,
On July 31, 2018, in connection with the Development Assets Contribution Agreements, we entered into the Sixth Amended and Restated Operation and Management Services and Secondment Agreement (as amended, the “Services Agreement”) with PBFX, paysresulting in an initialincrease of the annual fee of $0.5 million to PBF Holding for the provision of such services pursuant to the Services Agreement.$8.6 million. The Services Agreement will terminate upon the termination of the Second Amended and Restated Omnibus Agreement, provided that PBFX may terminate any service on 30 days’30-days’ notice. The Services Agreement was amended and restated in connection with the Contribution Agreement II (the “Amended and Restated Services Agreement”) and Contribution Agreement III (the “Second Amended and Restated Services Agreement”). The annual fee payable under the Amended and Restated Services Agreement increased from $0.5 million to $0.8 million (indexed for inflation) as a result of the inclusion of the DCR West

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Rack and was further increased under the Second Amended and Restated Services Agreement to $4.4 million (indexed for inflation) as a result of the inclusion of the Toledo Storage Facility. On May 15, 2015, the Second Amended and Restated Services Agreement was amended and restated in connection with the Delaware City Pipeline and Truck Rack Acquisition (the “Third Amended and Restated Services Agreement”) resulting in an increase in the annual fee payable from $4.4 million to $4.5 million. All fees to be paid pursuant to the Third Amended and Restated Services Agreement are indexed for inflation. The Third Amended and Restated Services Agreement will terminate upon the termination of the Third Amended and Restated Omnibus Agreement, provided that the Partnership may terminate any service on 30 days’ notice.
GLOSSARY OF SELECTED TERMS
Unless otherwise noted or indicated by context, the following terms used in this Annual Report on Form 10-K have the following meanings:
“AB32” refers to the greenhouse gas emission control regulations in the state of California to comply with Assembly Bill 32.
“ASCI” refers to the Argus Sour Crude Index, a pricing index used to approximate market prices for sour, heavy crude oil.
“Bakken” refers to both a crude oil production region generally covering North Dakota, Montana and Western Canada, and the crude oil that is produced in that region.
“barrel” refers to a common unit of measure in the oil industry, which equates to 42 gallons.
“blendstocks” refers to various compounds that are combined with gasoline or diesel from the crude oil refining process to make finished gasoline and diesel; these may include natural gasoline, FCC unit gasoline, ethanol, reformate or butane, among others.
“bpd” refers to an abbreviation for barrels per day.
“CAA” refers to the Clean Air Act.
“CAM Pipeline” or “CAM Connection Pipeline” refers to the Clovelly-Alliance-Meraux pipeline in Louisiana.
“CARB”refers to the California Air Resources Board; gasoline and diesel fuel sold in the state of California are regulated by CARB and require stricter quality and emissions reduction performance than required by other states.
“catalyst” refers to a substance that alters, accelerates, or instigates chemical changes, but is not produced as a product of the refining process.
“coke” refers to a coal-like substance that is produced from heavier crude oil fractions during the refining process.
“complexity” refers to the number, type and capacity of processing units at a refinery, measured by the Nelson Complexity Index, which is often used as a measure of a refinery’s ability to process lower quality crude in an economic manner.
“crack spread” refers to a simplified calculation that measures the difference between the price for light products and crude oil. For example, we reference (a) the 2-1-1 crack spread, which is a general industry standard utilized by our Delaware City, Paulsboro and Chalmette refineries that approximates the per barrel refining margin resulting from processing two barrels of crude oil to produce one barrel of gasoline and one barrel of heating oil or ULSD, and (b) the 4-3-1 crack spread, which is a benchmark utilized by our Toledo and Torrance refineries that approximates the per barrel refining margin resulting from processing four barrels of crude oil to produce three barrels of gasoline and one-half barrel of jet fuel and one-half barrel of ULSD.
“Dated Brent” refers to Brent blend oil, a light, sweet North Sea crude oil, characterized by an API gravity of 38° and a sulfur content of approximately 0.4 weight percent, that is used as a benchmark for other crude oils.
“distillates” refers primarily to diesel, heating oil, kerosene and jet fuel.
“DNREC” refers to the Delaware Department of Natural Resources and Environmental Control.
“downstream” refers to the downstream sector of the energy industry generally describing oil refineries, marketing and distribution companies that refine crude oil and sell and distribute refined products. The opposite of the downstream sector is the upstream sector, which refers to exploration and production companies that search for and/or produce crude oil and natural gas underground or through drilling or exploratory wells.


“EPA” refers to the United States Environmental Protection Agency.
“Ethanol Permit” refers to a Coastal Zone Act permit for ethanol.
“ethanol” refers to a clear, colorless, flammable oxygenated liquid. Ethanol is typically produced chemically from ethylene, or biologically from fermentation of various sugars from carbohydrates found in agricultural crops. It is used in the United States as a gasoline octane enhancer and oxygenate.
“feedstocks” refers to crude oil and partially refined petroleum products that are processed and blended into refined products.
“FASB” refers to the Financial Accounting Standards Board which develops U.S. generally accepted accounting principles.
“FCC” refers to fluid catalytic cracking.
“FCU” refers to fluid coking unit.
“FERC” refers to the Federal Energy Regulatory Commission.
“GAAP” refers to U.S. generally accepted accounting principles developed by the Financial Accounting Standards Board for nongovernmental entities.
“GHG” refers to the greenhouse gas carbon dioxide.
“Group I base oils or lubricants” refers to conventionally refined products characterized by sulfur content less than 0.03% with a viscosity index between 80 and 120. Typically, these products are used in a variety of automotive and industrial applications.
“heavy crude oil” refers to a relatively inexpensive crude oil with a low API gravity characterized by high relative density and viscosity. Heavy crude oils require greater levels of processing to produce high value products such as gasoline and diesel.
“IPO” refers to the initial public offering of PBF Energy Class A common stock which closed on December 18, 2012.
“J. Aron” refers to J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc.
“KV” refers to Kilovolts.
“LCM” refers to a GAAP requirement for inventory to be valued at the lower of cost or market.
“light crude oil” refers to a relatively expensive crude oil with a high API gravity characterized by low relative density and viscosity. Light crude oils require lower levels of processing to produce high value products such as gasoline and diesel.
“light products” refers to the group of refined products with lower boiling temperatures, including gasoline and distillates.
“light-heavy differential” refers to the price difference between light crude oil and heavy crude oil.
“LLS” refers to Light Louisiana Sweet benchmark for crude oil reflective of Gulf coast economics for light sweet domestic and foreign crudes.
“LPG” refers to liquefied petroleum gas.
“Maya” refers to Maya crude oil, a heavy, sour crude oil characterized by an API gravity of approximately 22° and a sulfur content of approximately 3.3 weight percent that is used as a benchmark for other heavy crude oils.


“MLP” refers to the master limited partnership.
“MMBTU” refers to million British thermal units.
“MMSCFD” refers to million standard cubic feet per day.
“MOEM Pipeline” refers to a pipeline that originates at a terminal in Empire, Louisiana approximately 30 miles north of the mouth of the Mississippi River. The MOEM Pipeline is 14 inches in diameter, 54 miles long and transports crude from South Louisiana to the Chalmette refinery and transports Heavy Louisiana Sweet (HLS) and South Louisiana Intermediate (SLI) crude.
“MW” refers to Megawatt.
“Nelson Complexity Index” refers to the complexity of an oil refinery as measured by the Nelson Complexity Index, which is calculated on an annual basis by the Oil and Gas Journal. The Nelson Complexity Index assigns a complexity factor to each major piece of refinery equipment based on its complexity and cost in comparison to crude distillation, which is assigned a complexity factor of 1.0. The complexity of each piece of refinery equipment is then calculated by multiplying its complexity factor by its throughput ratio as a percentage of crude distillation capacity. Adding up the complexity values assigned to each piece of equipment, including crude distillation, determines a refinery’s complexity on the Nelson Complexity Index. A refinery with a complexity of 10.0 on the Nelson Complexity Index is considered ten times more complex than crude distillation for the same amount of throughput.
“NYH” refers to the New York Harbor market value of petroleum products.
“NYMEX” refers to the New York Mercantile Exchange.
“NYSE” refers to the New York Stock Exchange.
“PADD” refers to Petroleum Administration for Defense Districts.
“Platts” refers to Platts, a division of The McGraw-Hill Companies.
“PPM” refers to parts per million.
“RINS” refers to renewable fuel credits required for compliance with the Renewable Fuel Standard.
“refined products” refers to petroleum products, such as gasoline, diesel and jet fuel, that are produced by a refinery.
“sour crude oil” refers to a crude oil that is relatively high in sulfur content, requiring additional processing to remove the sulfur. Sour crude oil is typically less expensive than sweet crude oil.
“Saudi Aramco” refers to Saudi Arabian Oil Company.
“SEC” refers to the United States Securities and Exchange Commission.
“Sunoco” refers to Sunoco, LLC.
“sweet crude oil” refers to a crude oil that is relatively low in sulfur content, requiring less processing to remove the sulfur than sour crude oil. Sweet crude oil is typically more expensive than sour crude oil.
“Syncrude” refers to a blend of Canadian synthetic oil, a light, sweet crude oil, typically characterized by API gravity between 30° and 32° and a sulfur content of approximately 0.1-0.2 weight percent.
“TCJA” refers to the U.S. government comprehensive tax legislation enacted on December 22, 2017 and commonly referred to as the Tax Cuts and Jobs Act.


“throughput” refers to the volume processed through a unit or refinery.
“turnaround” refers to a periodically required shutdown and comprehensive maintenance event to refurbish and maintain a refinery unit or units that involves the inspection of such units and occurs generally on a periodic cycle.
“ULSD” refers to ultra-low-sulfur diesel.
“Valero” refers to Valero Energy Corporation.
“WCS” refers to Western Canadian Select, a heavy, sour crude oil blend typically characterized by API gravity between 20° and 22° and a sulfur content of approximately 3.5 weight percent that is used as a benchmark for heavy Western Canadian crude oil.
“WTI” refers to West Texas Intermediate crude oil, a light, sweet crude oil, typically characterized by API gravity between 38° and 40° and a sulfur content of approximately 0.3 weight percent that is used as a benchmark for other crude oils.
“WTS” refers to West Texas Sour crude oil, a sour crude oil characterized by API gravity between 30° and 33° and a sulfur content of approximately 1.28 weight percent that is used as a benchmark for other sour crude oils.
“yield” refers to the percentage of refined products that is produced from crude oil and other feedstocks.



PART I
In this Annual Report on Form 10-K, unless the context otherwise requires, references to the “Company,” “we,” “our” or “us” refer to PBF Holding, and, in each case, unless the context otherwise requires, its consolidated subsidiaries. References to “subsidiary guarantors” refer to PBF Services Company LLC, PBF Power Marketing LLC, Paulsboro Refining Company LLC (“Paulsboro Refining”), Toledo Refining Company LLC (“Toledo Refining” or “TRC”), Delaware City Refining Company LLC (“Delaware City Refining” or “DCR”), PBF Investments LLC (“PBF Investments”), PBF International Inc., Chalmette Refining, L.L.C. (“Chalmette Refining”), PBF Energy Western Region LLC (“PBF Western Region”), Torrance Refining Company LLC (“Torrance Refining”) and Torrance Logistics Company LLC (“Torrance Logistics”), which are the subsidiaries of PBF Holding that guarantee PBF Holding’s 7.00% senior notes due 2023 (the “2023 Senior Notes”) and 7.25% senior notes due 2025 (the “2025 Senior Notes”, and together with the 2023 Senior Notes, the “Senior Notes”) on a joint and several basis.
In this Annual Report on Form 10-K, we make certain forward-looking statements, including statements regarding our plans, strategies, objectives, expectations, intentions, and resources. You should read our forward-looking statements together with our disclosures under the heading: “Cautionary Statement Regarding Forward-Looking Statements.” When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements set forth in this Annual Report on Form 10-K under “Risk Factors” in Item 1A.
ITEM. 1 BUSINESS
Overview and Corporate OfficesStructure
We lease approximately 53,000 square feet for our principal corporate offices in Parsippany, New Jersey. The lease for our principal corporate offices expires in 2017. Functions performedare one of the largest independent petroleum refiners and suppliers of unbranded transportation fuels, heating oil, petrochemical feedstocks, lubricants and other petroleum products in the Parsippany office include overall corporate management, refineryUnited States. We sell our products throughout the Northeast, Midwest, Gulf Coast and HSE management, planningWest Coast of the United States, as well as in other regions of the United States, Canada and strategy, corporate finance, commercial operations, logistics, contract administration, marketing, investor relations, governmental affairs, accounting, tax, treasury, information technology, legalMexico and human resources support functions.
Employees
are able to ship products to other international destinations. We were formed in 2008 to pursue acquisitions of crude oil refineries and downstream assets in North America. As of December 31, 2018, we own and operate five domestic oil refineries and related assets, which we acquired in 2010, 2011, 2015 and 2016. Our refineries have a combined processing capacity, known as throughput, of approximately 900,000 barrels per day (“bpd”), and a weighted-average Nelson Complexity Index of 12.2. The Company’s five oil refineries are aggregated into one reportable segment.
Ownership Structure
We are a Delaware limited liability company and a holding company for our operating subsidiaries. PBF Finance is a wholly-owned subsidiary of PBF Holding. We are a wholly-owned subsidiary of PBF LLC, and PBF Energy is the sole managing member of, and owner of an equity interest as of December 31, 2018 representing approximately 99.0% of the outstanding economic interests in PBF LLC.
On December 18, 2012, our indirect parent, PBF Energy completed its initial public offering. As a result of PBF Energy’s initial public offering and related organization transactions, PBF Energy became the sole managing member of PBF LLC and operates and controls all of its business and affairs and consolidates the financial results of PBF LLC and its subsidiaries, including PBF Holding and PBF Finance. As of December 31, 2018, PBF Energy held 119,895,422 PBF LLC Series C Units and its current and former executive officers and directors and certain employees and others beneficially held 1,206,325 PBF LLC Series A Units, and the holders of PBF Energy’s issued and outstanding shares of its Class A common stock have approximately 99.0% of the voting power in PBF Energy and the members of PBF LLC other than PBF Energy through their holdings of Class B common stock have the remaining 1.0% of the voting power.


PBF Holding Refineries
Our five refineries are located in Delaware City, Delaware, Paulsboro, New Jersey, Toledo, Ohio, New Orleans, Louisiana and Torrance, California. Each refinery is briefly described in the table below:
RefineryRegion
Nelson Complexity
Index
Throughput Capacity (in barrels per day)PADD
Crude Processed (1)
Source (1)
Delaware CityEast Coast11.3190,0001light sweet through heavy sourwater, rail
PaulsboroEast Coast13.2180,0001light sweet through heavy sourwater
ToledoMid-Continent9.2170,0002light sweetpipeline, truck, rail
ChalmetteGulf Coast12.7189,0003light sweet through heavy sourwater, pipeline
TorranceWest Coast14.9155,0005medium and heavypipeline, water, truck
________
(1) Reflects the typical crude and feedstocks and related sources utilized under normal operating conditions and prevailing market environments.
Public Offerings of PBF Logistics LP and Subsequent Drop-Down Transactions
PBF Logistics LP (“PBFX” or the “Partnership”) is an affiliate of ours. PBFX is a fee-based, growth-oriented, publicly-traded Delaware master limited partnership formed by PBF Energy to own or lease, operate, develop and acquire crude oil and refined petroleum products terminals, pipelines, storage facilities and similar logistics assets. PBFX engages in the receiving, handling, storing and transferring of crude oil, refined products, natural gas and intermediates from sources located throughout the United States and Canada for PBF Energy in support of certain of its refineries, as well as for third-party customers. As of December 31, 2018, a substantial majority of PBFX’s revenue is derived from long-term, fee-based commercial agreements with us, which include minimum volume commitments, for receiving, handling, storing and transferring crude oil, refined products, and natural gas. PBF Energy also has agreements with PBFX that establish fees for certain general and administrative services and operational and maintenance services provided by us to PBFX.
PBF Logistics GP LLC (“PBF GP”) serves as the general partner of PBFX. PBF GP is wholly-owned by PBF LLC. On May 14, 2014, PBFX completed its initial public offering (the “PBFX Offering”). In connection with the PBFX Offering, we had approximately 2,270 employees. At Paulsboro, 286distributed to PBF LLC, which in turn contributed to PBFX, the assets and liabilities of certain crude oil terminaling assets. In a series of additional transactions subsequent to the PBFX Offering, we distributed certain additional assets to PBF LLC, which in turn contributed those assets to PBFX. See “Agreements with PBFX” below as well as “Note 10 - Related Party Transactions” of our 454 employeesNotes to Consolidated Financial Statements for additional information.
See “Item 1A. Risk Factors” and “Item 13. Certain Relationships and Related Transactions, and Director Independence.”
Available Information
Our website address is www.pbfenergy.com. Information contained on our website is not part of this Annual Report on Form 10-K. Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any other materials filed with (or furnished to) the U.S. Securities and Exchange Commission (“SEC”) by us are covered by a collective bargaining agreement. In addition, 927available on our website (under “Investors”) free of our 1,584 employees at Delaware City, Toledo and Chalmette are covered by a collective bargaining agreement. None of our corporate employees are covered by a collective bargaining agreement. We consider our relations with the represented employees to be satisfactory. At Delaware City, Toledo and Chalmette, most hourly employees are covered by a collective bargaining agreement through the United Steel Workers (“USW”). The agreements with the USW covering Delaware City and Toledo are scheduled to expire in February 2018 while the agreement with the USW covering Chalmette is scheduled to expire in January 2019. Similarly, at Paulsboro hourly employees are represented by the Independent Oil Workers (“IOW”) under a contract scheduled to expire in March 2018.charge, soon after we file or furnish such material.
Environmental, Health and Safety Matters

The Company's refinery, pipelinediagram below depicts our organizational structure as of December 31, 2018:
pbfhstructurechart2018.gif



Refining Operations
We own and related operations are subject to extensiveoperate five refineries providing geographic and frequently changing federal, state and local laws and regulations, including, but not limited to, those relating to the dischargemarket diversity. We produce a variety of matter into the environment or otherwise relating 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. Permits are also required under these laws for the operationproducts at each of our refineries, including gasoline, ULSD, heating oil, jet fuel, lubricants, petrochemicals and asphalt. We sell our products throughout the Northeast, Midwest, Gulf Coast and West Coast of the United States, as well as in other regions of the United States, Canada and Mexico, and are able to ship products to other international destinations.
Delaware City Refinery
Overview. The Delaware City refinery is located on an approximately 5,000-acre site, with access to waterborne cargoes and an extensive distribution network of pipelines, barges and tankers, truck and rail. Delaware City is a fully integrated operation that receives crude via rail at its crude unloading facilities, or ship or barge at its docks located on the Delaware River. The crude and other feedstocks are stored in an extensive tank farm prior to processing. In addition, there is a 15-lane, 76,000 bpd capacity truck loading rack located adjacent to the refinery and a 23-mile interstate pipeline that are used to distribute clean products, which were sold to PBFX in conjunction with its acquisition of the DCR Products Pipeline and Truck Rack (as defined in “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements) in May 2015.
As a result of its configuration and process units, Delaware City has the capability of processing a slate of heavy crudes with a high concentration of high sulfur crudes and is one of the largest and most complex refineries on the East Coast. The Delaware City refinery is one of two heavy crude coking refineries, the other being our Paulsboro refinery, on the East Coast of the United States with coking capacity equal to approximately 25% of crude capacity.
The Delaware City refinery primarily processes a variety of medium to heavy, sour crude oils, but can run light, sweet crude oils as well. The refinery has large conversion capacity with its 82,000 bpd fluid catalytic cracking unit (“FCC unit”), 47,000 bpd fluid coking unit and 18,000 bpd hydrocracking unit with vacuum distillation.
The following table approximates the Delaware City refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Unit190,000
Vacuum Distillation Unit102,000
Fluid Catalytic Cracking Unit82,000
Hydrotreating Units160,000
Hydrocracking Unit18,000
Catalytic Reforming Unit43,000
Benzene / Toluene Extraction Unit15,000
Butane Isomerization Unit6,000
Alkylation Unit11,000
Polymerization Unit16,000
Fluid Coking Unit47,000
Feedstocks and Supply Arrangements. We source our crude oil needs for Delaware City primarily through short-term and spot market agreements.
Refined Product Yield and Distribution. The Delaware City refinery predominantly produces gasoline, jet fuel, ULSD and ultra-low sulfur heating oil as well as certain other products. We market and sell all of our refined products independently to a variety of customers on the spot market or through term agreements.


Inventory Intermediation Agreement. On June 26, 2013, we entered into an Inventory Intermediation Agreement (the “Inventory Intermediation Agreement”) with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. (“J. Aron”) to support the operations of the Delaware City refinery, which commenced upon the termination of the previous product offtake agreement. Pursuant to such Inventory Intermediation Agreement, J. Aron purchases the Products (as defined in “Item 1A - Risk Factors”) produced and delivered into the refinery’s storage tanks on a daily basis. J. Aron further agrees to sell to us on a daily basis the Products delivered out of the refinery’s storage tanks. On certain dates subsequent to the inception of the Inventory Intermediation Agreement, we and our subsidiary, DCR, entered into amendments to the amended and restated inventory intermediation agreement (as amended, the “Amended Delaware Intermediation Agreement”) with J. Aron pursuant to which certain terms of the Inventory Intermediation Agreement were amended, including, among other things, pricing and an extension of the term. The most recent of these amendments was executed on September 8, 2017 which extended the term to July 1, 2019, which term may be further extended by mutual consent of the parties to July 1, 2020. At expiration, we will have to repurchase the inventories outstanding under the Amended Delaware Intermediation Agreement at that time.
Tankage Capacity. The Delaware City refinery has total storage capacity of approximately 10.0 million barrels. Of the total, approximately 3.6 million barrels of storage capacity are dedicated to crude oil and other feedstock storage with the remaining 6.4 million barrels allocated to finished products, intermediates and other products.
Energy and Other Utilities. Under normal operating conditions, the Delaware City refinery consumes approximately 65,000 MMBTU per day of natural gas supplied via pipeline from third parties. The Delaware City refinery has a 280 MW power plant located on site that consists of two natural gas-fueled turbines with combined capacity of approximately 140 MW and four turbo generators with combined nameplate capacity of approximately 140 MW. Collectively, this power plant produces electricity in excess of Delaware City’s refinery load of approximately 90 MW. Excess electricity is sold into the Pennsylvania-New Jersey-Maryland, or PJM, grid. Steam is primarily produced by a combination of three dedicated boilers, two heat recovery steam generators on the gas turbines, and is supplemented by secondary boilers at the FCC and Coker. Hydrogen is provided via the refinery’s steam methane reformer and continuous catalytic reformer. During 2018, we signed an agreement with a third-party for the construction and subsequent lease of a new 25 million cubic feet per day hydrogen facility (the “Hydrogen Facility”) which is expected to be completed in the first quarter of 2020. Upon completion, the Hydrogen Facility will provide us with additional complex crude processing capabilities.
Paulsboro Refinery
Overview. The Paulsboro refinery is located on approximately 950 acres on the Delaware River in Paulsboro, New Jersey, near Philadelphia and approximately 30 miles away from Delaware City. Paulsboro receives crude and feedstocks via its marine terminal on the Delaware River. Paulsboro is one of two operating refineries on the East Coast with coking capacity, the other being our Delaware City refinery. The Paulsboro refinery primarily processes a variety of medium and heavy, sour crude oils but can run light, sweet crude oils as well.


The following table approximates the Paulsboro refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Units168,000
Vacuum Distillation Units83,000
Fluid Catalytic Cracking Unit55,000
Hydrotreating Units141,000
Catalytic Reforming Unit32,000
Alkylation Unit11,000
Lube Oil Processing Unit12,000
Delayed Coking Unit27,000
Propane Deasphalting Unit11,000
Feedstocks and Supply Arrangements. We have a contract with Saudi Aramco pursuant to which we have purchased up to approximately 100,000 bpd of crude oil from Saudi Aramco that is processed at Paulsboro. The crude purchased under this contract is priced off the ASCI.
Refined Product Yield and Distribution. The Paulsboro refinery predominantly produces gasoline, diesel fuels and jet fuel and also manufactures Group I base oils or lubricants and asphalt. We market and sell all of our refined products independently to a variety of customers on the spot market or through term agreements under which we sell approximately 35% of our Paulsboro refinery’s gasoline production.
Inventory Intermediation Agreement. On June 26, 2013, we entered into an Inventory Intermediation Agreement with J. Aron to support the operations of the Paulsboro refinery, which commenced upon the termination of the previous product offtake agreement. Pursuant to such Inventory Intermediation Agreement, J. Aron purchases the Products produced and delivered into the refinery’s storage tanks on a daily basis. J. Aron further agrees to sell to us on a daily basis the Products delivered out of the refinery’s storage tanks. On certain dates subsequent to the inception of the Inventory Intermediation Agreement, we and our subsidiary, PRC, entered into amendments to the amended and restated inventory intermediation agreement (as amended, the “Amended Paulsboro Intermediation Agreement”, and collectively with the Amended Delaware Intermediation Agreement, referred to as the “Inventory Intermediation Agreements”) with J. Aron pursuant to which certain terms of the Inventory Intermediation Agreements were amended, including, among other things, pricing and an extension of the term. The most recent of these amendments was executed on September 8, 2017 which extended the term to December 31, 2019, which may be further extended by mutual consent of the parties to December 31, 2020. At expiration, we will be required to repurchase the inventories outstanding under the Amended Paulsboro Intermediation Agreement at that time.
Tankage Capacity. The Paulsboro refinery has total storage capacity of approximately 7.5 million barrels. Of the total, approximately 2.1 million barrels are dedicated to crude oil storage with the remaining 5.4 million barrels allocated to finished products, intermediates and other products.
Energy and Other Utilities. Under normal operating conditions, the Paulsboro refinery consumes approximately 40,000 MMBTU per day of natural gas supplied via pipeline from third parties. The Paulsboro refinery is mostly self-sufficient for electrical power through a mix of gas and steam turbine generators. The Paulsboro refinery generation typically supplies about 57 MW of the total 63 MW total refinery load. There are circumstances where available generation is greater than the total refinery load, but the Paulsboro refinery does not typically export power to the utility grid. If necessary, supplemental electrical power is available on a guaranteed basis from the local utility. The Paulsboro refinery is connected to the grid via three separate 69KV aerial feeders and has the ability to run entirely on imported power. Steam is produced in three boilers and a heat recovery steam generator fed by the exhaust from the gas turbine. In addition, there are a number of waste heat boilers and furnace stack economizers throughout the refinery that supplement the steam generation capacity. Backup capability is


provided by package boilers. The Paulsboro refinery’s current hydrogen needs are met by the hydrogen supply from the reformer. In addition, the refinery employs a standalone steam methane reformer. This ancillary hydrogen plant is utilized as a back-up source of hydrogen for the refinery’s process units.
Toledo Refinery
Overview. The Toledo refinery primarily processes a slate of light, sweet crudes from Canada, the Mid-Continent, the Bakken region and the U.S. Gulf Coast. The Toledo refinery is located on a 282-acre site near Toledo, Ohio, approximately 60 miles from Detroit. Crude is delivered to the Toledo refinery through three primary pipelines: (1) Enbridge from the north, (2) Capline from the south and (3) Mid-Valley from the south. Crude is also delivered to a nearby terminal by rail and from local sources by truck to a truck unloading facility within the refinery.
The following table approximates the Toledo refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Unit170,000
Fluid Catalytic Cracking Unit79,000
Hydrotreating Units95,000
Hydrocracking Unit45,000
Catalytic Reforming Units45,000
Alkylation Unit10,000
Polymerization Unit7,000
UDEX Unit16,300
Feedstocks and Supply Arrangements. We source our crude oil needs for Toledo primarily through short-term and spot market agreements.
Refined Product Yield and Distribution. Toledo produces finished products including gasoline and ULSD, in addition to a variety of high-value petrochemicals including benzene, toluene, xylene, nonene and tetramer. Toledo is connected, via pipelines, to an extensive distribution network throughout Ohio, Illinois, Indiana, Kentucky, Michigan, Pennsylvania and West Virginia. The finished products are transported on pipelines owned by Sunoco Logistics Partners L.P. and Buckeye Partners. In addition, we have proprietary connections to a variety of smaller pipelines and related operationsspurs that help us optimize our clean products distribution. A significant portion of Toledo’s gasoline and these permitsULSD are subject to revocation, modification and renewal. Compliance with applicable environmental laws, regulations and permits will continue todistributed through the approximately 36 terminals in this network.
We have an impact on our operations, results of operationsagreement with Sunoco whereby Sunoco purchases gasoline and capital requirements. We believe that our current operations are in substantial compliance with existing environmental laws, regulations and permits.
Our operations and manydistillate products representing approximately one-third of the products we manufacture areToledo refinery’s gasoline and distillates production. The agreement had an initial three-year term, subject to certain specific requirementsearly termination rights. In March 2017, the agreement was renewed and extended for a two-year term. We are currently in the process of negotiating a renewal of this agreement. We sell the bulk of the Clean Air Act,petrochemicals produced at the Toledo refinery through short-term contracts or CAA,on the spot market and related state and local regulations. The CAA contains provisions that require capital expenditures for the installation of certain air pollution control devices at our 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, six Northeastern states require heating oil with 15 PPM or less sulfur. By July 1, 2016, two more states are expected to adopt this requirement and by July 1, 2018 mostmajority of the petrochemical distribution is done via rail.
Tankage Capacity. The Toledo refinery has total storage capacity of approximately 4.5 million barrels. The Toledo refinery receives its crude through pipeline connections and a truck rack. Of the total, approximately 1.3 million barrels are dedicated to crude oil storage with the remaining Northeastern states (except for Pennsylvania3.2 million barrels allocated to intermediates and New Hampshire) will require heatingproducts. A portion of storage capacity dedicated to crude oil and finished products was sold to PBFX in conjunction with 15 PPM or less sulfur. Allits acquisition of the heating oilToledo Storage Facility (as defined in “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements) in December 2014.


Energy and Other Utilities. Under normal operating conditions, the Company currently produces meets these specifications.Toledo refinery consumes approximately 20,000 MMBTU per day of natural gas supplied via pipeline from third parties. The mandateToledo refinery purchases its electricity from the PJM grid and other requirements do not currently havehas 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 standardslong-term contract to purchase hydrogen 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, withsteam from a credit trading program to provide compliance flexibility. The EPA responded to industry comments on the proposed rule

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and maintained the per gallon sulfur cap on gasoline at the existing 80 PPM cap. The standards set by the new rule are not expected to have a material impact on the Company’s financial position, results of operations or cash flows.
The EPA was required to release the final annual standards for the Reformulated Fuels Standard (“RFS”) for 2014 no later than Nov 29, 2013 and for 2015 no later than Nov 29, 2014. The EPA did not meet these requirements but did release proposed standards for 2014. The EPA did not finalize this proposal in 2014. However, in May 2015, the EPA re-proposed annual standards for RFS 2 for 2014, and proposed new standards for 2015 and 2016 and biomass-based diesel volumes for 2017. The final standards were issued on November 30, 2015. The standards issued by the EPA include volume requirements in the annual standards which, while below the volumes originally set by Congress, increased renewable fuel use in the U.S. above historical levels and provide for steady growth over time. The EPA also increased the required volume of biomass-based diesel in 2015, 2016, and 2017 while maintaining the opportunity for growth in other advanced biofuels. The Company is currently evaluating the final standards and they may have a material impact on the Company's cost of compliance with RFS 2.
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.local third-party supplier. In addition to the third-party steam supplier, Toledo consumes 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.
As of January 1, 2011, we are required to comply with the EPA’s Control of Hazardous Air Pollutants From Mobile Sources, or MSAT2, regulations on gasoline that impose reductions in the benzene content of our produced gasoline. We purchase benzene credits to meet these requirements. Our planned capital projects will reduce the amount of benzene credits that we need to purchase. In addition, the renewable fuel standards mandate the blending of prescribed percentages of renewable fuels (e.g., ethanol and biofuels) into our produced gasoline and diesel. These new requirements, other requirementsportion of the CAAsteam that is generated by its various process units.
Chalmette Refinery
Overview. The Chalmette refinery is located on a 400-acre site near New Orleans, Louisiana. It is a dual-train coking refinery and other presently existing or future environmental regulations may cause usis capable of processing both light and heavy crude oil through its 189,000 bpd crude units and downstream units. Chalmette Refining owns 100% of the MOEM Pipeline, providing access to make substantial capital expendituresthe Empire Terminal, as well as the purchaseCAM Connection Pipeline, providing access to the Louisiana Offshore Oil Port facility through a third-party pipeline. Chalmette Refining also owns 80% of credits at significant cost,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 enablethe Plantation and Colonial Pipelines. In addition, there is also 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 following table approximates the Chalmette refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery UnitsNameplate
Capacity

Crude Distillation Unit189,000
Fluid Catalytic Cracking Unit72,000
Hydrotreating Units186,000
Delayed Coker29,000
Catalytic Reforming Unit40,000
Alkylation Unit15,000
Feedstocks and Supply Arrangements. We source our refineriescrude oil and feedstock needs for Chalmette through connections to produce productsthe CAM and MOEM pipelines as well as our marine terminal. On November 1, 2015, we entered into a market-based crude supply agreement with Petróleos de Venezuela S.A. (“PDVSA”) that meet applicable requirements.
Our operations are alsohas a ten-year term with a renewal option for an additional five years, subject to certain early termination rights. The pricing for the federal Clean Water Act, orcrude supply is market based and is agreed upon on a quarterly basis by both parties. We have not sourced crude oil under this agreement since the CWA, the federal Safe Drinking Water Act, or the SDWA, and comparable state and local requirements. The CWA, the SDWA and analogous laws prohibit any discharge into surface waters, ground waters, injection wells and publicly-owned treatment works except in strict conformance with permits, suchthird quarter of 2017 as pre-treatment permits and discharge permits, issued by federal, state and local governmental agencies. Federal waste-water discharge permits and analogous state waste-water discharge permits are issued for fixed terms and must be renewed.
We generate wastes that may be subjectPDVSA has suspended deliveries due to the federal Resource Conservationparties’ inability to agree to mutually acceptable payment terms.
Refined Product Yield and Recovery Act, or RCRA,Distribution. The Chalmette refinery predominantly produces gasoline and comparable statediesel fuels and also manufactures high-value petrochemicals including benzene and xylene. Products produced at the Chalmette refinery are transferred to customers through pipelines, the marine terminal and truck rack. The majority of our clean products are delivered to customers via pipelines. Our ownership of the Collins Pipeline and T&M Terminal provides Chalmette with strategic access to Southeast and East Coast markets through third-party logistics.
Tankage Capacity. Chalmette has a total tankage capacity of approximately 8.1 million barrels. Of this total, approximately 2.6 million barrels are allocated to crude oil storage with the remaining 5.5 million barrels allocated to intermediates and products.
Energy and Other Utilities. Under normal operating conditions, the Chalmette refinery consumes approximately 30,000 MMBTU per day of natural gas supplied via pipeline from third parties. The Chalmette refinery purchases its electricity from a local requirements.utility and has a long-term contract to purchase hydrogen and steam from third-party suppliers.


Coker Project: The EPAChalmette refinery is currently in the process of restarting its idled 12,000 barrel per day coker unit to increase the refinery’s long-term feedstock flexibility and various state agencies have limitedbe positioned to benefit from potential dislocations in the approved methodsprice for heavy and high-sulfur feedstocks. The unit is expected to be in service by the end of disposal for certain hazardous2019 and non-hazardous wastes.is expected to increase the refinery’s total coking capacity to approximately 42,000 barrels per day.
Torrance Refinery
Acquisition. On July 1, 2016, we acquired from ExxonMobil and its subsidiary, Mobil Pacific Pipe Line Company, the Torrance refinery and related logistics assets (collectively, the “Torrance Acquisition”).
Overview. The Torrance refinery is located on 750 acres in Torrance, California. It is a high-conversion crude, delayed-coking refinery. It is capable of processing both heavy and medium crude oil through its crude unit and downstream units. In addition to refining assets, the Torrance Acquisition 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 logistics asset 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 that supplies jet fuel to the Los Angeles airport.
The EPA publishedfollowing table approximates the Torrance refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Unit155,000
Vacuum Distillation Unit102,000
Fluid Catalytic Cracking Unit88,000
Hydrotreating Units151,000
Hydrocracking Unit23,000
Alkylation Unit27,000
Delayed Coker53,000
Feedstocks and Supply Arrangements. The Torrance refinery primarily processes a Final Rule to the CWA Section 316(b) in August 2014 regarding cooling water intake structures, which includes requirements for petroleum refineries. The purposevariety of this rule is to prevent fish from being trapped against cooling water intake screens (impingement)medium 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 gives state agencies the discretion to establish implementation time lines. We continue to evaluate the impact of this regulation, and at this time do not anticipate it having a material impact on our financial position, results of operations or cash flows.
The federal Comprehensive Environmental Response, Compensation and Liability Act of 1980, or CERCLA, also known as “Superfund,” imposes liability, without regard to fault or the legality of the original conduct, on certain classes of persons who are considered to be responsible for the release of a “hazardous substance” into the environment. These persons include the current or former owner or operator of the disposal site or sites where the release occurred and companies that disposed of or arranged for the disposal of the hazardous substances. Under CERCLA, such persons may be subject to joint and several liability for investigation and the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. As discussed more fully below, certain of our sites are subject to these laws and we may be held liable for investigation and remediation costs or claims for natural resource damages. It is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the environment. Analogous state laws impose similar responsibilities and liabilities on responsible parties. In our current

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normal operations, we have generated waste, some of which falls within the statutory definition of a “hazardous substance” and some of which may have been disposed of at sites that may require cleanup under Superfund.
As is the case with all companies engaged in industries similar to ours, we face potential exposure to future claims and lawsuits involving environmental matters. These matters include soil and water contamination, air pollution, personal injury and property damage allegedly caused by substances which we manufactured, handled, used, released or disposed of.
Current and future environmental regulations are expected to require additional expenditures, including expenditures for investigation and remediation, which may be significant, at our refineries and at our other facilities. To the extent that future expenditures for these purposes are material and can be reasonably determined, these costs are disclosed and accrued.
Our operations are also subject to various laws and regulations relating to occupational health and safety. We maintain safety training and maintenance programs as part of our ongoing efforts to ensure compliance with applicable laws and regulations. Compliance with applicable health and safety laws and regulations has required and continues to require substantial expenditures.
heavy crude oils. In connection with each of our acquisitions, we assumed certain environmental remediation obligations. In the caseclosing of the PaulsboroTorrance Acquisition, we entered into a crude supply agreement with ExxonMobil for approximately 60,000 bpd of crude oil that can be processed at our Torrance refinery. This crude supply agreement has a five-year term with an automatic renewal feature unless either party gives thirty-six months prior written notice. Additionally, we obtain crude and feedstocks from other sources through connections to third-party pipelines as well as ship docks and truck racks.
Refined Product Yield and Distribution. The Torrance refinery a self-guarantee is in placepredominantly produces gasoline, jet fuel and diesel fuels. Products produced at the Torrance refinery are transferred to meet state financial assurance requirements, incustomers through pipelines, the amountmarine terminal and truck rack. The majority of approximately $12.1 million, the estimated cost of the remediation obligations. Both the short and long-term portions of this environmental liabilityclean products are recorded in accrued expenses and other long-term liabilities, respectively. In connectiondelivered to customers via pipelines. Concurrently with the acquisition of the Chalmette refinery on July 1, 2016, we entered into an offtake agreement with ExxonMobil pursuant to which ExxonMobil purchases up to 50% of our gasoline production. This offtake agreement had an initial term of three years and was scheduled to automatically renew for another three-year term unless either party provided six-months written notice of its intent to terminate the Company obtained $3.9agreement. This contract has been terminated and will not be renewed upon expiration on July 1, 2019. On a prospective basis, we will market and sell all of our refined products independently to a variety of customers either on the spot market or through term agreements.


Tankage Capacity. Torrance has a total tankage capacity of approximately 8.6 million barrels. Of this total, approximately 2.1 million barrels are allocated to crude oil storage with the remaining 6.5 million barrels allocated to intermediates and products.
Energy and Other Utilities. Under normal operating conditions, the Torrance refinery consumes approximately 45,000 MMBTU per day of natural gas supplied via pipeline from third parties. The Torrance refinery generates some power internally using a combination of steam and gas turbines and purchases any additional needed power from the local utility. The Torrance refinery has a long-term contract to purchase hydrogen from a third-party supplier.
Principal Products
Our refineries make various grades of gasoline, distillates (including diesel fuel, jet fuel, and ULSD) and other products from crude oil, other feedstocks, and blending components. We sell these products through our commercial accounts, and sales with major oil companies. For the years ended December 31, 2018, 2017 and 2016, gasoline and distillates accounted for 84.8%, 84.1% and 88.1% of our revenues, respectively.
Customers
We sell a variety of refined products to a diverse customer base. The majority of our refined products are primarily sold through short-term contracts or on the spot market. However, we do have product offtake arrangements for a portion of our clean products. For the years ended December 31, 2018, 2017 and 2016, no single customer accounted for 10% or more of our revenues, respectively. As of December 31, 2018 and 2017, no single customer accounted for 10% or more of our total trade accounts receivable.
Seasonality
Demand for gasoline and diesel is generally higher during the summer months than during the winter months due to seasonal increases in financial assurance (inhighway traffic and construction work. Decreased demand during the formwinter months can lower gasoline and diesel prices. As a result, our operating results for the first and fourth calendar quarters may be lower than those for the second and third calendar quarters of surety bond)each year. Refining margins remain volatile and our results of operations may not reflect these historical seasonal trends. Additionally, the degree of seasonality may differ by the geographic areas in which we operate.
Competition
The refining business is very competitive. We compete directly with various other refining companies on the East, Gulf and West Coasts and in the Mid-Continent, with integrated oil companies, with foreign refiners that import products into the United States and with producers and marketers in other industries supplying alternative forms of energy and fuels to cover estimated site remediationsatisfy the requirements of industrial, commercial and individual consumers. Some of our competitors have expanded the capacity of their refineries and internationally new refineries are coming on line which could also affect our competitive position.
Profitability in the refining industry depends largely on refined product margins, which can fluctuate significantly, as well as crude oil prices and differentials between the prices of different grades of crude oil, operating efficiency and reliability, product mix and costs of product distribution and transportation. Certain of our competitors that have larger and more complex refineries may be able to realize lower per-barrel costs or higher margins per barrel of throughput. Several of our principal competitors are integrated national or international oil companies that are larger and have substantially greater resources. Because of their integrated operations and larger capitalization, these companies may be more flexible in responding to volatile industry or market conditions, such as shortages of feedstocks or intense price fluctuations. Refining margins are frequently impacted by sharp changes in crude oil costs, which may not be immediately reflected in product prices.


The refining industry is highly competitive with respect to feedstock supply. Unlike certain of our competitors that have access to proprietary controlled sources of crude oil production available for use at their own refineries, we obtain all of our crude oil and substantially all other feedstocks from unaffiliated sources. The availability and cost of crude oil and feedstock are affected by global supply and demand. We have no crude oil reserves and are not engaged in the exploration or production of crude oil. We believe, however, that we will be able to obtain adequate crude oil and other feedstocks at generally competitive prices for the foreseeable future.
Our complex refinery system and sourcing optionality may position us favorably to benefit from changes in certain market conditions and governmental or industry regulations, such as the pending requirement from the International Maritime Organization (“IMO”) related to the reduction in sulfur content of marine fuels to a maximum of 0.5% effective January 1, 2020. Due to our relative refinery complexity and ample coking capacity, we anticipate being able to favorably capture the benefit from potential product margin uplift associated with an agreed to Administrative Orderincrease in demand for low sulfur fuel or a widening of Consentthe discount on high-sulfur feedstocks as a result of the new IMO regulations.
Agreements with PBFX
Beginning with the EPA.completion of the PBFX Offering, we have entered into a series of agreements with PBFX, including commercial and operational agreements. Each of these agreements and their impact to our operations is outlined below.
Contribution Agreements
Immediately prior to the closing of certain contribution agreements, which PBF LLC entered into with PBFX (as defined in the table below, and collectively referred to as the “Contribution Agreements”), we 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 us. The estimated cost assumes remedialContribution Agreements include the following:
Contribution AgreementEffective DateAssets ContributedTotal Consideration
Contribution Agreement I5/8/2014DCR Rail Terminal and the Toledo Truck Terminal74,053 PBFX common units and 15,886,553 PBFX subordinated units
Contribution Agreement II9/16/2014DCR West Rack$135.0 million in cash and $15.0 million through the issuance of 589,536 PBFX common units
Contribution Agreement III12/2/2014Toledo Storage Facility$135.0 million in cash and $15.0 million through the issuance of 620,935 PBFX common units
Contribution Agreement IV5/5/2015DCR Products Pipeline and Truck Rack$112.5 million in cash and $30.5 million through the issuance of 1,288,420 PBFX common units
Contribution Agreement V8/31/2016Torrance Valley Pipeline$175.0 million in cash
Contribution Agreement VI2/15/2017Paulsboro Natural Gas Pipeline$11.6 million affiliate promissory note
Contribution Agreements VII-X7/16/2018Development Assets$31.6 million through the issuance of 1,494,134 PBFX common units


Pursuant to Contribution Agreement V on August 31, 2016, we contributed 50% of the issued and outstanding limited liability company interests of Torrance Valley Pipeline Company LLC (“TVPC”) to PBF LLC. PBFX then acquired 50% of the issued and outstanding limited liability company interests of TVPC. TVPC’s assets consist of the Torrance Valley Pipeline which include the M55, M1 and M70 pipeline systems, including 11 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 will continueof TVPC that most significantly impact its economic performance. Accordingly, PBFX, and not us, is considered to be the primary beneficiary for accounting purposes and as a result PBFX fully consolidates TVPC. Subsequent to Contribution Agreement V, we record an investment in equity method investee on our consolidated balance sheet for the 50% interest in TVPC that we own. The carrying value of our equity method investment in TVPC was $169.5 million and $171.9 million at December 31, 2018 and 2017, respectively.
Pursuant to Contribution Agreement VI entered into on February 15, 2017, we contributed all of the issued and outstanding limited liability company interests of Paulsboro Natural Gas Pipeline Company LLC (“PNGPC”) to PBF LLC. PBFX Op Co, in turn acquired the limited liability company interests in PNGPC from PBF LLC in connection with Contribution Agreement VI effective February 28, 2017. PNGPC owns and operates an existing interstate natural gas pipeline that serves our Paulsboro refinery (the “Paulsboro Natural Gas Pipeline”), which is subject to regulation by the Federal Energy Regulatory Commission (“FERC”). In connection with the PNGPC contribution agreement, PBFX constructed a new pipeline to replace the existing pipeline, which commenced services in August 2017.
In consideration for the PNGPC limited liability company interests, PBFX delivered to PBF LLC (i) an $11.6 million affiliate promissory note in favor of Paulsboro Refining Company LLC, one of our wholly-owned subsidiaries (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. As a result of the completion of the Paulsboro Natural Gas Pipeline in the fourth quarter of 2017, we received full payment for the affiliate Promissory Note.
On July 16, 2018, PBFX entered into four contribution agreements with PBF LLC pursuant to which we contributed to PBF LLC certain of its subsidiaries (the “Development Assets Contribution Agreements”). Pursuant to the Development Asset Contribution Agreements, we contributed all of the issued and outstanding limited liability company interests of: Toledo Rail Logistics Company LLC (“TRLC”), whose assets consist of a loading and unloading rail facility located at the Toledo refinery (the “Toledo Rail Products Facility”); Chalmette Logistics Company LLC (“CLC”), whose assets consist of a truck loading rack facility (the “Chalmette Truck Rack”) and a rail yard facility (the “Chalmette Rosin Yard”), both of which are located at the Chalmette refinery; Paulsboro Terminaling Company LLC (“PTC”), whose assets consist of a lube oil terminal facility located at the Paulsboro refinery (the “Paulsboro Lube Oil Terminal”); and DCR Storage and Loading Company LLC (“DSLC”), whose assets consist of an ethanol storage facility located at the Delaware City refinery (the “Delaware Ethanol Storage Facility” and collectively with the Toledo Rail Products Facility, the Chalmette Truck Rack, the Chalmette Rosin Yard, and the Paulsboro Lube Oil Terminal, the “Development Assets”) to PBF LLC. PBFX Op Co, in turn acquired the limited liability company interests in the Development Assets from PBF LLC in connection with the Development Assets Contribution Agreements effective July 31, 2018.


Commercial Agreements
PBFX currently derives the majority of its revenue from long-term, fee-based commercial agreements with us, the majority of which include a minimum volume commitment (“MVC”) and are supported by contractual fee escalations for inflation adjustments and certain increases in operating costs. We believe 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.
Refer to “Note 10 - Related Party Transactions” of 30 years.our Notes to Consolidated Financial Statements for further discussion regarding the commercial agreements with PBFX.
Omnibus Agreement
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 us. 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. On July 31, 2018, we entered into the Fifth Amended and Restated Omnibus Agreement (as amended, the “Omnibus Agreement”) in connection with the Development Assets Contribution Agreements, resulting in an increase of the estimated annual fee to $7.0 million.
Services Agreement
In connection with the acquisitionPBFX Offering, PBFX also entered into an operation and management services and secondment agreement with us and certain of our subsidiaries, pursuant to which we provide PBFX with the Delaware City refinery,personnel necessary for PBFX to perform its obligations under its commercial agreements. PBFX reimburses us for the prior owners remain responsible subjectuse 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 limitations, for certain environmental obligations including ongoing remediation of soilroads and groundwater contamination at the site. Further,grounds, sanitary sewer access, electrical power, emergency response, filter press, fuel gas, API solids treatment, fire water and compressed air.
On July 31, 2018, in connection with the Delaware CityDevelopment Assets Contribution Agreements, we entered into the Sixth Amended and Paulsboro acquisitions, we purchased two individual ten-year, $75.0 million environmental insurance policies to insure against unknown environmental liabilities at each refinery. In connectionRestated Operation and Management Services and Secondment Agreement (as amended, the “Services Agreement”) with the acquisitionPBFX, resulting in an increase of the Toledo refinery,annual fee to $8.6 million. The Services Agreement will terminate upon the seller, subject to certain limitations, initially retains remediation obligations which will transition to us over a 20-year period. However, there can be no assurance that any available indemnity, self-guarantee or insurance will be sufficient to cover any ultimate environmental liabilities we may incur with respect to our refineries, which could be significant. In connection with the acquisitiontermination of the Chalmette refinery, the Company purchased a ten year, $100.0 million environmental insurance policy to insure against unknown environmental liabilities at the refinery.
We cannot predict what additional health, safety and environmental legislation or regulations will be enacted or become effective in the future or how existing or future laws or regulations will be administered or interpreted with respect to our operations. Compliance with more stringent laws or regulations or adverse changes in the interpretation of existing requirements or discovery of new information such as unknown contamination could have an adverse effectOmnibus Agreement, provided that PBFX may terminate any service on the financial position and the results of our operations and could require substantial expenditures for the installation and operation of systems and equipment that we do not currently possess.30-days’ notice.

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GLOSSARY OF SELECTED TERMS
Unless otherwise noted or indicated by context, the following terms used in this Annual Report on Form 10-K have the following meanings:
“AB32” refers to the greenhouse gas emission control regulations in the state of California to comply with Assembly Bill 32.
“ASCI” refers to the Argus Sour Crude Index, a pricing index used to approximate market prices for sour, heavy crude oil.
“Bakken” refers to both a crude oil production region generally covering North Dakota, Montana and Western Canada, and the crude oil that is produced in that region.
“barrel” refers to a common unit of measure in the oil industry, which equates to 42 gallons at 1 atmosphere pressure.gallons.
“blendstocks” refers to various compounds that are combined with gasoline or diesel from the crude oil refining process to make finished gasoline and diesel; these may include natural gasoline, FCC unit gasoline, ethanol, reformate or butane, among others.
“bpd” refers to an abbreviation for barrels per day.
“CAA” refers to the Clean Air Act.
“CAM Pipeline” or “CAM Connection Pipeline” refers to the Clovelly-Alliance-Meraux pipeline in Louisiana.
CAPP”CARB”refers to the Canadian AssociationCalifornia Air Resources Board; gasoline and diesel fuel sold in the state of Petroleum Producers.California are regulated by CARB and require stricter quality and emissions reduction performance than required by other states.
“catalyst” refers to a substance that alters, accelerates, or instigates chemical changes, but is not produced as a product of the refining process.
“coke” refers to a coal-like substance that is produced from heavier crude oil fractions during the refining process.
“complexity” refers to the number, type and capacity of processing units at a refinery, measured by the Nelson Complexity Index, which is often used as a measure of a refinery’s ability to process lower quality crude in an economic manner.
“crack spread” refers to a simplified calculation that measures the difference between the price for light products and crude oil. For example, we reference (a) the 2-1-1 crack spread, which is a general industry standard utilized by our Delaware City, Paulsboro and Chalmette refineries that approximates the per barrel refining margin resulting from processing two barrels of crude oil to produce one barrel of gasoline and one barrel of heating oil or ULSD, and (b) the 4-3-1 crack spread, which is a benchmark utilized by our Toledo refineryand Torrance refineries that approximates the per barrel refining margin resulting from processing four barrels of crude oil to produce three barrels of gasoline and one-half barrel of jet fuel and one-half barrel of ULSD.
“Dated Brent” refers to Brent blend oil, a light, sweet North Sea crude oil, characterized by an API gravity of 38° and a sulfur content of approximately 0.4 weight percent, that is used as a benchmark for other crude oils.
“distillates” refers primarily to diesel, heating oil, kerosene and jet fuel.
“DNREC” refers to the Delaware Department of Natural Resources and Environmental Control.
“downstream” refers to the downstream sector of the energy industry generally describing oil refineries, marketing and distribution companies that refine crude oil and sell and distribute refined products. The opposite of the downstream sector is the upstream sector, which refers to exploration and production companies that search for and/or produce crude oil and natural gas underground or through drilling or exploratory wells.


“EPA” refers to the United States Environmental Protection Agency.
“Ethanol Permit” refers to a Coastal Zone Act permit for ethanol.
“ethanol” refers to a clear, colorless, flammable oxygenated liquid. Ethanol is typically produced chemically from ethylene, or biologically from fermentation of various sugars from carbohydrates found in agricultural crops and cellulosic residues from crops or wood.crops. It is used in the United States as a gasoline octane enhancer and oxygenate.
“feedstocks” refers to crude oil and partially refined petroleum products that are processed and blended into refined products.
FASB” refers to the Financial Accounting Standards Board which develops U.S. generally accepted accounting principles.
FCC” refers to fluid catalytic cracking.
“FCU” refers to fluid coking unit.

20“FERC” refers to the Federal Energy Regulatory Commission.



“GAAP” refers to U.S. generally accepted accounting principles developed by the Financial Accounting Standards Board for nongovernmental entities.
“GHG” refers to the greenhouse gas.gas carbon dioxide.
“Group I base oils or lubricants” refers to conventionally refined products characterized by sulfur content less than 0.03% with a viscosity index between 80 and 120. Typically, these products are used in a variety of automotive and industrial applications.
“heavy crude oil” refers to a relatively inexpensive crude oil with a low API gravity characterized by high relative density and viscosity. Heavy crude oils require greater levels of processing to produce high value products such as gasoline and diesel.
“IPO” refers to the initial public offering of PBF Energy’sEnergy Class A common stock which closed on December 18, 2012.
“J. Aron” refers to J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc.
“KV” refers to Kilovolts.
“LCM” refers to a GAAP requirement for inventory to be valued at the lower of cost or market.
“light crude oil” refers to a relatively expensive crude oil with a high API gravity characterized by low relative density and viscosity. Light crude oils require lower levels of processing to produce high value products such as gasoline and diesel.
“light products” refers to the group of refined products with lower boiling temperatures, including gasoline and distillates.
“light-heavy differential” refers to the price difference between light crude oil and heavy crude oil.
“LLS” refers to Light Louisiana Sweet benchmark for crude oil reflective of Gulf coast economics for light sweet domestic and foreign crudes.
“LPG” refers to liquefied petroleum gas.
“Maya” refers to Maya crude oil, a heavy, sour crude oil characterized by an API gravity of approximately 22° and a sulfur content of approximately 3.3 weight percent that is used as a benchmark for other heavy crude oils.


“MLP” refers to the master limited partnership.
“MMbbls” refers to an abbreviation for million barrels.
“MMBTU” refers to million British thermal units.
“MMSCFD” refers to million standard cubic feet per day.
“MOEM Pipeline” refers to a pipeline that originates at a terminal in Empire, Louisiana approximately 30 miles north of the mouth of the Mississippi River. The MOEM Pipeline is 14 inches in diameter, 54 miles long and transports crude from South Louisiana to the Chalmette Refining, L.L.C. The MOEM Pipelinerefinery and transports Heavy Louisiana Sweet (HLS) and South Louisiana Intermediate (SLI) crude.
“MSCG” refers to Morgan Stanley Capital Group Inc.
“MW” refers to Megawatt.
“Nelson Complexity Index” refers to the complexity of an oil refinery as measured by the Nelson Complexity Index, which is calculated on an annual basis by the Oil and Gas Journal. The Nelson Complexity Index assigns a complexity factor to each major piece of refinery equipment based on its complexity and cost in comparison to crude distillation, which is assigned a complexity factor of 1.0. The complexity of each piece of refinery equipment is then calculated by multiplying its complexity factor by its throughput ratio as a percentage of crude distillation capacity. Adding up the complexity values assigned to each piece of equipment, including crude distillation, determines a refinery’s complexity on the Nelson Complexity Index. A refinery with a complexity of 10.0 on the Nelson Complexity Index is considered ten times more complex than crude distillation for the same amount of throughput.

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“NYH” refers to the New York Harbor market value of petroleum products.
“NYMEX” refers to the New York Mercantile Exchange.
“NYSE” refers to the New York Stock Exchange.
“PADD” refers to Petroleum Administration for Defense Districts.
“Platts” refers to Platts, a division of The McGraw-Hill Companies.
“PPM” refers to parts per million.
“RINS” refers to renewable fuel credits required for compliance with the Renewable FuelsFuel Standard.
“refined products” refers to petroleum products, such as gasoline, diesel and jet fuel, that are produced by a refinery.
“sour crude oil” refers to a crude oil that is relatively high in sulfur content, requiring additional processing to remove the sulfur. Sour crude oil is typically less expensive than sweet crude oil.
“Saudi Aramco” refers to Saudi Arabian Oil Company.
Statoil” SEC”refers to Statoil Marketingthe United States Securities and Trading (US) Inc.Exchange Commission.
“Sunoco” refers to Sunoco, Inc. (R&M).LLC.
“sweet crude oil” refers to a crude oil that is relatively low in sulfur content, requiring less processing to remove the sulfur than sour crude oil. Sweet crude oil is typically more expensive than sour crude oil.
“Syncrude” refers to a blend of Canadian synthetic oil, a light, sweet crude oil, typically characterized by API gravity between 30° and 32° and a sulfur content of approximately 0.1-0.2 weight percent.
“TCJA” refers to the U.S. government comprehensive tax legislation enacted on December 22, 2017 and commonly referred to as the Tax Cuts and Jobs Act.


“throughput” refers to the volume processed through a unit or refinery.
“turnaround” refers to a periodically required shutdown and comprehensive maintenance event to refurbish and maintain a refinery unit or units that involves the inspection of such units and occurs generally on a periodic cycle.
“ULSD” refers to ultra-low-sulfur diesel.
“Valero” refers to Valero Energy Corporation.
“WCS” refers to Western Canadian Select, a heavy, sour crude oil blend typically characterized by API gravity between 20° and 22° and a sulfur content of approximately 3.5 weight percent that is used as a benchmark for heavy Western Canadian crude oil.
“WTI” refers to West Texas Intermediate crude oil, a light, sweet crude oil, typically characterized by API gravity between 38° and 40° and a sulfur content of approximately 0.3 weight percent that is used as a benchmark for other crude oils.
“WTS” refers to West Texas Sour crude oil, a sour crude oil characterized by API gravity between 30° and 33° and a sulfur content of approximately 1.28 weight percent that is used as a benchmark for other sour crude oils.
“yield” refers to the percentage of refined products that is produced from crude oil and other feedstocks.


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PART I
In this Annual Report on Form 10-K, unless the context otherwise requires, references to the “Company,” “we,” “our” or “us” refer to PBF Holding, and, in each case, unless the context otherwise requires, its consolidated subsidiaries. References to “subsidiary guarantors” refer to PBF Services Company LLC, PBF Power Marketing LLC, Paulsboro Refining Company LLC (“Paulsboro Refining”), Toledo Refining Company LLC (“Toledo Refining” or “TRC”), Delaware City Refining Company LLC (“Delaware City Refining” or “DCR”), PBF Investments LLC (“PBF Investments”), PBF International Inc., Chalmette Refining, L.L.C. (“Chalmette Refining”), PBF Energy Western Region LLC (“PBF Western Region”), Torrance Refining Company LLC (“Torrance Refining”) and Torrance Logistics Company LLC (“Torrance Logistics”), which are the subsidiaries of PBF Holding that guarantee PBF Holding’s 7.00% senior notes due 2023 (the “2023 Senior Notes”) and 7.25% senior notes due 2025 (the “2025 Senior Notes”, and together with the 2023 Senior Notes, the “Senior Notes”) on a joint and several basis.
In this Annual Report on Form 10-K, we make certain forward-looking statements, including statements regarding our plans, strategies, objectives, expectations, intentions, and resources. You should read our forward-looking statements together with our disclosures under the heading: “Cautionary Statement Regarding Forward-Looking Statements.” When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements set forth in this Annual Report on Form 10-K under “Risk Factors” in Item 1A.
ITEM. 1 BUSINESS
Overview and Corporate Structure
We are one of the largest independent petroleum refiners and suppliers of unbranded transportation fuels, heating oil, petrochemical feedstocks, lubricants and other petroleum products in the United States. We sell our products throughout the Northeast, Midwest, Gulf Coast and West Coast of the United States, as well as in other regions of the United States, Canada and Mexico and are able to ship products to other international destinations. We were formed in 2008 to pursue acquisitions of crude oil refineries and downstream assets in North America. As of December 31, 2018, we own and operate five domestic oil refineries and related assets, which we acquired in 2010, 2011, 2015 and 2016. Our refineries have a combined processing capacity, known as throughput, of approximately 900,000 barrels per day (“bpd”), and a weighted-average Nelson Complexity Index of 12.2. The Company’s five oil refineries are aggregated into one reportable segment.
Ownership Structure
We are a Delaware limited liability company and a holding company for our operating subsidiaries. PBF Finance is a wholly-owned subsidiary of PBF Holding. We are a wholly-owned subsidiary of PBF LLC, and PBF Energy is the sole managing member of, and owner of an equity interest as of December 31, 2018 representing approximately 99.0% of the outstanding economic interests in PBF LLC.
On December 18, 2012, our indirect parent, PBF Energy completed its initial public offering. As a result of PBF Energy’s initial public offering and related organization transactions, PBF Energy became the sole managing member of PBF LLC and operates and controls all of its business and affairs and consolidates the financial results of PBF LLC and its subsidiaries, including PBF Holding and PBF Finance. As of December 31, 2018, PBF Energy held 119,895,422 PBF LLC Series C Units and its current and former executive officers and directors and certain employees and others beneficially held 1,206,325 PBF LLC Series A Units, and the holders of PBF Energy’s issued and outstanding shares of its Class A common stock have approximately 99.0% of the voting power in PBF Energy and the members of PBF LLC other than PBF Energy through their holdings of Class B common stock have the remaining 1.0% of the voting power.


PBF Holding Refineries
Our five refineries are located in Delaware City, Delaware, Paulsboro, New Jersey, Toledo, Ohio, New Orleans, Louisiana and Torrance, California. Each refinery is briefly described in the table below:
RefineryRegion
Nelson Complexity
Index
Throughput Capacity (in barrels per day)PADD
Crude Processed (1)
Source (1)
Delaware CityEast Coast11.3190,0001light sweet through heavy sourwater, rail
PaulsboroEast Coast13.2180,0001light sweet through heavy sourwater
ToledoMid-Continent9.2170,0002light sweetpipeline, truck, rail
ChalmetteGulf Coast12.7189,0003light sweet through heavy sourwater, pipeline
TorranceWest Coast14.9155,0005medium and heavypipeline, water, truck
________
(1) Reflects the typical crude and feedstocks and related sources utilized under normal operating conditions and prevailing market environments.
Public Offerings of PBF Logistics LP and Subsequent Drop-Down Transactions
PBF Logistics LP (“PBFX” or the “Partnership”) is an affiliate of ours. PBFX is a fee-based, growth-oriented, publicly-traded Delaware master limited partnership formed by PBF Energy to own or lease, operate, develop and acquire crude oil and refined petroleum products terminals, pipelines, storage facilities and similar logistics assets. PBFX engages in the receiving, handling, storing and transferring of crude oil, refined products, natural gas and intermediates from sources located throughout the United States and Canada for PBF Energy in support of certain of its refineries, as well as for third-party customers. As of December 31, 2018, a substantial majority of PBFX’s revenue is derived from long-term, fee-based commercial agreements with us, which include minimum volume commitments, for receiving, handling, storing and transferring crude oil, refined products, and natural gas. PBF Energy also has agreements with PBFX that establish fees for certain general and administrative services and operational and maintenance services provided by us to PBFX.
PBF Logistics GP LLC (“PBF GP”) serves as the general partner of PBFX. PBF GP is wholly-owned by PBF LLC. On May 14, 2014, PBFX completed its initial public offering (the “PBFX Offering”). In connection with the PBFX Offering, we distributed to PBF LLC, which in turn contributed to PBFX, the assets and liabilities of certain crude oil terminaling assets. In a series of additional transactions subsequent to the PBFX Offering, we distributed certain additional assets to PBF LLC, which in turn contributed those assets to PBFX. See “Agreements with PBFX” below as well as “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements for additional information.
See “Item 1A. Risk Factors” and “Item 13. Certain Relationships and Related Transactions, and Director Independence.”
Available Information
Our website address is www.pbfenergy.com. Information contained on our website is not part of this Annual Report on Form 10-K. Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any other materials filed with (or furnished to) the U.S. Securities and Exchange Commission (“SEC”) by us are available on our website (under “Investors”) free of charge, soon after we file or furnish such material.


The diagram below depicts our organizational structure as of December 31, 2018:
pbfhstructurechart2018.gif



Refining Operations
We own and operate five refineries providing geographic and market diversity. We produce a variety of products at each of our refineries, including gasoline, ULSD, heating oil, jet fuel, lubricants, petrochemicals and asphalt. We sell our products throughout the Northeast, Midwest, Gulf Coast and West Coast of the United States, as well as in other regions of the United States, Canada and Mexico, and are able to ship products to other international destinations.
Delaware City Refinery
Overview. The Delaware City refinery is located on an approximately 5,000-acre site, with access to waterborne cargoes and an extensive distribution network of pipelines, barges and tankers, truck and rail. Delaware City is a fully integrated operation that receives crude via rail at its crude unloading facilities, or ship or barge at its docks located on the Delaware River. The crude and other feedstocks are stored in an extensive tank farm prior to processing. In addition, there is a 15-lane, 76,000 bpd capacity truck loading rack located adjacent to the refinery and a 23-mile interstate pipeline that are used to distribute clean products, which were sold to PBFX in conjunction with its acquisition of the DCR Products Pipeline and Truck Rack (as defined in “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements) in May 2015.
As a result of its configuration and process units, Delaware City has the capability of processing a slate of heavy crudes with a high concentration of high sulfur crudes and is one of the largest and most complex refineries on the East Coast. The Delaware City refinery is one of two heavy crude coking refineries, the other being our Paulsboro refinery, on the East Coast of the United States with coking capacity equal to approximately 25% of crude capacity.
The Delaware City refinery primarily processes a variety of medium to heavy, sour crude oils, but can run light, sweet crude oils as well. The refinery has large conversion capacity with its 82,000 bpd fluid catalytic cracking unit (“FCC unit”), 47,000 bpd fluid coking unit and 18,000 bpd hydrocracking unit with vacuum distillation.
The following table approximates the Delaware City refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Unit190,000
Vacuum Distillation Unit102,000
Fluid Catalytic Cracking Unit82,000
Hydrotreating Units160,000
Hydrocracking Unit18,000
Catalytic Reforming Unit43,000
Benzene / Toluene Extraction Unit15,000
Butane Isomerization Unit6,000
Alkylation Unit11,000
Polymerization Unit16,000
Fluid Coking Unit47,000
Feedstocks and Supply Arrangements. We source our crude oil needs for Delaware City primarily through short-term and spot market agreements.
Refined Product Yield and Distribution. The Delaware City refinery predominantly produces gasoline, jet fuel, ULSD and ultra-low sulfur heating oil as well as certain other products. We market and sell all of our refined products independently to a variety of customers on the spot market or through term agreements.


Inventory Intermediation Agreement. On June 26, 2013, we entered into an Inventory Intermediation Agreement (the “Inventory Intermediation Agreement”) with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. (“J. Aron”) to support the operations of the Delaware City refinery, which commenced upon the termination of the previous product offtake agreement. Pursuant to such Inventory Intermediation Agreement, J. Aron purchases the Products (as defined in “Item 1A - Risk Factors”) produced and delivered into the refinery’s storage tanks on a daily basis. J. Aron further agrees to sell to us on a daily basis the Products delivered out of the refinery’s storage tanks. On certain dates subsequent to the inception of the Inventory Intermediation Agreement, we and our subsidiary, DCR, entered into amendments to the amended and restated inventory intermediation agreement (as amended, the “Amended Delaware Intermediation Agreement”) with J. Aron pursuant to which certain terms of the Inventory Intermediation Agreement were amended, including, among other things, pricing and an extension of the term. The most recent of these amendments was executed on September 8, 2017 which extended the term to July 1, 2019, which term may be further extended by mutual consent of the parties to July 1, 2020. At expiration, we will have to repurchase the inventories outstanding under the Amended Delaware Intermediation Agreement at that time.
Tankage Capacity. The Delaware City refinery has total storage capacity of approximately 10.0 million barrels. Of the total, approximately 3.6 million barrels of storage capacity are dedicated to crude oil and other feedstock storage with the remaining 6.4 million barrels allocated to finished products, intermediates and other products.
Energy and Other Utilities. Under normal operating conditions, the Delaware City refinery consumes approximately 65,000 MMBTU per day of natural gas supplied via pipeline from third parties. The Delaware City refinery has a 280 MW power plant located on site that consists of two natural gas-fueled turbines with combined capacity of approximately 140 MW and four turbo generators with combined nameplate capacity of approximately 140 MW. Collectively, this power plant produces electricity in excess of Delaware City’s refinery load of approximately 90 MW. Excess electricity is sold into the Pennsylvania-New Jersey-Maryland, or PJM, grid. Steam is primarily produced by a combination of three dedicated boilers, two heat recovery steam generators on the gas turbines, and is supplemented by secondary boilers at the FCC and Coker. Hydrogen is provided via the refinery’s steam methane reformer and continuous catalytic reformer. During 2018, we signed an agreement with a third-party for the construction and subsequent lease of a new 25 million cubic feet per day hydrogen facility (the “Hydrogen Facility”) which is expected to be completed in the first quarter of 2020. Upon completion, the Hydrogen Facility will provide us with additional complex crude processing capabilities.
Paulsboro Refinery
Overview. The Paulsboro refinery is located on approximately 950 acres on the Delaware River in Paulsboro, New Jersey, near Philadelphia and approximately 30 miles away from Delaware City. Paulsboro receives crude and feedstocks via its marine terminal on the Delaware River. Paulsboro is one of two operating refineries on the East Coast with coking capacity, the other being our Delaware City refinery. The Paulsboro refinery primarily processes a variety of medium and heavy, sour crude oils but can run light, sweet crude oils as well.


The following table approximates the Paulsboro refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Units168,000
Vacuum Distillation Units83,000
Fluid Catalytic Cracking Unit55,000
Hydrotreating Units141,000
Catalytic Reforming Unit32,000
Alkylation Unit11,000
Lube Oil Processing Unit12,000
Delayed Coking Unit27,000
Propane Deasphalting Unit11,000
Feedstocks and Supply Arrangements. We have a contract with Saudi Aramco pursuant to which we have purchased up to approximately 100,000 bpd of crude oil from Saudi Aramco that is processed at Paulsboro. The crude purchased under this contract is priced off the ASCI.
Refined Product Yield and Distribution. The Paulsboro refinery predominantly produces gasoline, diesel fuels and jet fuel and also manufactures Group I base oils or lubricants and asphalt. We market and sell all of our refined products independently to a variety of customers on the spot market or through term agreements under which we sell approximately 35% of our Paulsboro refinery’s gasoline production.
Inventory Intermediation Agreement. On June 26, 2013, we entered into an Inventory Intermediation Agreement with J. Aron to support the operations of the Paulsboro refinery, which commenced upon the termination of the previous product offtake agreement. Pursuant to such Inventory Intermediation Agreement, J. Aron purchases the Products produced and delivered into the refinery’s storage tanks on a daily basis. J. Aron further agrees to sell to us on a daily basis the Products delivered out of the refinery’s storage tanks. On certain dates subsequent to the inception of the Inventory Intermediation Agreement, we and our subsidiary, PRC, entered into amendments to the amended and restated inventory intermediation agreement (as amended, the “Amended Paulsboro Intermediation Agreement”, and collectively with the Amended Delaware Intermediation Agreement, referred to as the “Inventory Intermediation Agreements”) with J. Aron pursuant to which certain terms of the Inventory Intermediation Agreements were amended, including, among other things, pricing and an extension of the term. The most recent of these amendments was executed on September 8, 2017 which extended the term to December 31, 2019, which may be further extended by mutual consent of the parties to December 31, 2020. At expiration, we will be required to repurchase the inventories outstanding under the Amended Paulsboro Intermediation Agreement at that time.
Tankage Capacity. The Paulsboro refinery has total storage capacity of approximately 7.5 million barrels. Of the total, approximately 2.1 million barrels are dedicated to crude oil storage with the remaining 5.4 million barrels allocated to finished products, intermediates and other products.
Energy and Other Utilities. Under normal operating conditions, the Paulsboro refinery consumes approximately 40,000 MMBTU per day of natural gas supplied via pipeline from third parties. The Paulsboro refinery is mostly self-sufficient for electrical power through a mix of gas and steam turbine generators. The Paulsboro refinery generation typically supplies about 57 MW of the total 63 MW total refinery load. There are circumstances where available generation is greater than the total refinery load, but the Paulsboro refinery does not typically export power to the utility grid. If necessary, supplemental electrical power is available on a guaranteed basis from the local utility. The Paulsboro refinery is connected to the grid via three separate 69KV aerial feeders and has the ability to run entirely on imported power. Steam is produced in three boilers and a heat recovery steam generator fed by the exhaust from the gas turbine. In addition, there are a number of waste heat boilers and furnace stack economizers throughout the refinery that supplement the steam generation capacity. Backup capability is


provided by package boilers. The Paulsboro refinery’s current hydrogen needs are met by the hydrogen supply from the reformer. In addition, the refinery employs a standalone steam methane reformer. This ancillary hydrogen plant is utilized as a back-up source of hydrogen for the refinery’s process units.
Toledo Refinery
Overview. The Toledo refinery primarily processes a slate of light, sweet crudes from Canada, the Mid-Continent, the Bakken region and the U.S. Gulf Coast. The Toledo refinery is located on a 282-acre site near Toledo, Ohio, approximately 60 miles from Detroit. Crude is delivered to the Toledo refinery through three primary pipelines: (1) Enbridge from the north, (2) Capline from the south and (3) Mid-Valley from the south. Crude is also delivered to a nearby terminal by rail and from local sources by truck to a truck unloading facility within the refinery.
The following table approximates the Toledo refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Unit170,000
Fluid Catalytic Cracking Unit79,000
Hydrotreating Units95,000
Hydrocracking Unit45,000
Catalytic Reforming Units45,000
Alkylation Unit10,000
Polymerization Unit7,000
UDEX Unit16,300
Feedstocks and Supply Arrangements. We source our crude oil needs for Toledo primarily through short-term and spot market agreements.
Refined Product Yield and Distribution. Toledo produces finished products including gasoline and ULSD, in addition to a variety of high-value petrochemicals including benzene, toluene, xylene, nonene and tetramer. Toledo is connected, via pipelines, to an extensive distribution network throughout Ohio, Illinois, Indiana, Kentucky, Michigan, Pennsylvania and West Virginia. The finished products are transported on pipelines owned by Sunoco Logistics Partners L.P. and Buckeye Partners. In addition, we have proprietary connections to a variety of smaller pipelines and spurs that help us optimize our clean products distribution. A significant portion of Toledo’s gasoline and ULSD are distributed through the approximately 36 terminals in this network.
We have an agreement with Sunoco whereby Sunoco purchases gasoline and distillate products representing approximately one-third of the Toledo refinery’s gasoline and distillates production. The agreement had an initial three-year term, subject to certain early termination rights. In March 2017, the agreement was renewed and extended for a two-year term. We are currently in the process of negotiating a renewal of this agreement. We sell the bulk of the petrochemicals produced at the Toledo refinery through short-term contracts or on the spot market and the majority of the petrochemical distribution is done via rail.
Tankage Capacity. The Toledo refinery has total storage capacity of approximately 4.5 million barrels. The Toledo refinery receives its crude through pipeline connections and a truck rack. Of the total, approximately 1.3 million barrels are dedicated to crude oil storage with the remaining 3.2 million barrels allocated to intermediates and products. A portion of storage capacity dedicated to crude oil and finished products was sold to PBFX in conjunction with its acquisition of the Toledo Storage Facility (as defined in “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements) in December 2014.


Energy and Other Utilities. Under normal operating conditions, the Toledo refinery consumes approximately 20,000 MMBTU per day of natural gas supplied via pipeline from third parties. The Toledo refinery purchases its electricity from the PJM grid and has a long-term contract to purchase hydrogen and steam from a local third-party supplier. In addition to the third-party steam supplier, Toledo consumes a portion of the steam that is generated by its various process units.
Chalmette Refinery
Overview. The Chalmette refinery is located on a 400-acre site near New Orleans, Louisiana. It is a dual-train coking refinery and is capable of processing both light and heavy crude oil through its 189,000 bpd crude units and downstream units. 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. In addition, there is also 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 following table approximates the Chalmette refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery UnitsNameplate
Capacity

Crude Distillation Unit189,000
Fluid Catalytic Cracking Unit72,000
Hydrotreating Units186,000
Delayed Coker29,000
Catalytic Reforming Unit40,000
Alkylation Unit15,000
Feedstocks and Supply Arrangements. We source our crude oil and feedstock needs for Chalmette through connections to the CAM and MOEM pipelines as well as our marine terminal. On November 1, 2015, we entered into a market-based crude supply agreement with Petróleos de Venezuela S.A. (“PDVSA”) that has a ten-year term with a renewal option for an additional five years, subject to certain early termination rights. The pricing for the crude supply is market based and is agreed upon on a quarterly basis by both parties. We have not sourced crude oil under this agreement since the third quarter of 2017 as PDVSA has suspended deliveries due to the parties’ inability to agree to mutually acceptable payment terms.
Refined Product Yield and Distribution. The Chalmette refinery predominantly produces gasoline and diesel fuels and also manufactures high-value petrochemicals including benzene and xylene. Products produced at the Chalmette refinery are transferred to customers through pipelines, the marine terminal and truck rack. The majority of our clean products are delivered to customers via pipelines. Our ownership of the Collins Pipeline and T&M Terminal provides Chalmette with strategic access to Southeast and East Coast markets through third-party logistics.
Tankage Capacity. Chalmette has a total tankage capacity of approximately 8.1 million barrels. Of this total, approximately 2.6 million barrels are allocated to crude oil storage with the remaining 5.5 million barrels allocated to intermediates and products.
Energy and Other Utilities. Under normal operating conditions, the Chalmette refinery consumes approximately 30,000 MMBTU per day of natural gas supplied via pipeline from third parties. The Chalmette refinery purchases its electricity from a local utility and has a long-term contract to purchase hydrogen and steam from third-party suppliers.


Coker Project: The Chalmette refinery is currently in the process of restarting its idled 12,000 barrel per day coker unit to increase the refinery’s long-term feedstock flexibility and be positioned to benefit from potential dislocations in the price for heavy and high-sulfur feedstocks. The unit is expected to be in service by the end of 2019 and is expected to increase the refinery’s total coking capacity to approximately 42,000 barrels per day.
Torrance Refinery
Acquisition. On July 1, 2016, we acquired from ExxonMobil and its subsidiary, Mobil Pacific Pipe Line Company, the Torrance refinery and related logistics assets (collectively, the “Torrance Acquisition”).
Overview. The Torrance refinery is located on 750 acres in Torrance, California. It is a high-conversion crude, delayed-coking refinery. It is capable of processing both heavy and medium crude oil through its crude unit and downstream units. In addition to refining assets, the Torrance Acquisition 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 logistics asset 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 that supplies jet fuel to the Los Angeles airport.
The following table approximates the Torrance refinery’s major process unit capacities. Unit capacities are shown in barrels per stream day.
Refinery Units
Nameplate
Capacity

Crude Distillation Unit155,000
Vacuum Distillation Unit102,000
Fluid Catalytic Cracking Unit88,000
Hydrotreating Units151,000
Hydrocracking Unit23,000
Alkylation Unit27,000
Delayed Coker53,000
Feedstocks and Supply Arrangements. The Torrance refinery primarily processes a variety of medium and heavy crude oils. In connection with the closing of the Torrance Acquisition, we entered into a crude supply agreement with ExxonMobil for approximately 60,000 bpd of crude oil that can be processed at our Torrance refinery. This crude supply agreement has a five-year term with an automatic renewal feature unless either party gives thirty-six months prior written notice. Additionally, we obtain crude and feedstocks from other sources through connections to third-party pipelines as well as ship docks and truck racks.
Refined Product Yield and Distribution. The Torrance refinery predominantly produces gasoline, jet fuel and diesel fuels. Products produced at the Torrance refinery are transferred to customers through pipelines, the marine terminal and truck rack. The majority of clean products are delivered to customers via pipelines. Concurrently with the acquisition of the refinery on July 1, 2016, we entered into an offtake agreement with ExxonMobil pursuant to which ExxonMobil purchases up to 50% of our gasoline production. This offtake agreement had an initial term of three years and was scheduled to automatically renew for another three-year term unless either party provided six-months written notice of its intent to terminate the agreement. This contract has been terminated and will not be renewed upon expiration on July 1, 2019. On a prospective basis, we will market and sell all of our refined products independently to a variety of customers either on the spot market or through term agreements.


Tankage Capacity. Torrance has a total tankage capacity of approximately 8.6 million barrels. Of this total, approximately 2.1 million barrels are allocated to crude oil storage with the remaining 6.5 million barrels allocated to intermediates and products.
Energy and Other Utilities. Under normal operating conditions, the Torrance refinery consumes approximately 45,000 MMBTU per day of natural gas supplied via pipeline from third parties. The Torrance refinery generates some power internally using a combination of steam and gas turbines and purchases any additional needed power from the local utility. The Torrance refinery has a long-term contract to purchase hydrogen from a third-party supplier.
Principal Products
Our refineries make various grades of gasoline, distillates (including diesel fuel, jet fuel, and ULSD) and other products from crude oil, other feedstocks, and blending components. We sell these products through our commercial accounts, and sales with major oil companies. For the years ended December 31, 2018, 2017 and 2016, gasoline and distillates accounted for 84.8%, 84.1% and 88.1% of our revenues, respectively.
Customers
We sell a variety of refined products to a diverse customer base. The majority of our refined products are primarily sold through short-term contracts or on the spot market. However, we do have product offtake arrangements for a portion of our clean products. For the years ended December 31, 2018, 2017 and 2016, no single customer accounted for 10% or more of our revenues, respectively. As of December 31, 2018 and 2017, no single customer accounted for 10% or more of our total trade accounts receivable.
Seasonality
Demand for gasoline and diesel is generally higher during the summer months than during the winter months due to seasonal increases in highway traffic and construction work. Decreased demand during the winter months can lower gasoline and diesel prices. As a result, our operating results for the first and fourth calendar quarters may be lower than those for the second and third calendar quarters of each year. Refining margins remain volatile and our results of operations may not reflect these historical seasonal trends. Additionally, the degree of seasonality may differ by the geographic areas in which we operate.
Competition
The refining business is very competitive. We compete directly with various other refining companies on the East, Gulf and West Coasts and in the Mid-Continent, with integrated oil companies, with foreign refiners that import products into the United States and with producers and marketers in other industries supplying alternative forms of energy and fuels to satisfy the requirements of industrial, commercial and individual consumers. Some of our competitors have expanded the capacity of their refineries and internationally new refineries are coming on line which could also affect our competitive position.
Profitability in the refining industry depends largely on refined product margins, which can fluctuate significantly, as well as crude oil prices and differentials between the prices of different grades of crude oil, operating efficiency and reliability, product mix and costs of product distribution and transportation. Certain of our competitors that have larger and more complex refineries may be able to realize lower per-barrel costs or higher margins per barrel of throughput. Several of our principal competitors are integrated national or international oil companies that are larger and have substantially greater resources. Because of their integrated operations and larger capitalization, these companies may be more flexible in responding to volatile industry or market conditions, such as shortages of feedstocks or intense price fluctuations. Refining margins are frequently impacted by sharp changes in crude oil costs, which may not be immediately reflected in product prices.


The refining industry is highly competitive with respect to feedstock supply. Unlike certain of our competitors that have access to proprietary controlled sources of crude oil production available for use at their own refineries, we obtain all of our crude oil and substantially all other feedstocks from unaffiliated sources. The availability and cost of crude oil and feedstock are affected by global supply and demand. We have no crude oil reserves and are not engaged in the exploration or production of crude oil. We believe, however, that we will be able to obtain adequate crude oil and other feedstocks at generally competitive prices for the foreseeable future.
Our complex refinery system and sourcing optionality may position us favorably to benefit from changes in certain market conditions and governmental or industry regulations, such as the pending requirement from the International Maritime Organization (“IMO”) related to the reduction in sulfur content of marine fuels to a maximum of 0.5% effective January 1, 2020. Due to our relative refinery complexity and ample coking capacity, we anticipate being able to favorably capture the benefit from potential product margin uplift associated with an increase in demand for low sulfur fuel or a widening of the discount on high-sulfur feedstocks as a result of the new IMO regulations.
Agreements with PBFX
Beginning with the completion of the PBFX Offering, we have entered into a series of agreements with PBFX, including commercial and operational agreements. Each of these agreements and their impact to our operations is outlined below.
Contribution Agreements
Immediately prior to the closing of certain contribution agreements, which PBF LLC entered into with PBFX (as defined in the table below, and collectively referred to as the “Contribution Agreements”), we 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 us. The Contribution Agreements include the following:
Contribution AgreementEffective DateAssets ContributedTotal Consideration
Contribution Agreement I5/8/2014DCR Rail Terminal and the Toledo Truck Terminal74,053 PBFX common units and 15,886,553 PBFX subordinated units
Contribution Agreement II9/16/2014DCR West Rack$135.0 million in cash and $15.0 million through the issuance of 589,536 PBFX common units
Contribution Agreement III12/2/2014Toledo Storage Facility$135.0 million in cash and $15.0 million through the issuance of 620,935 PBFX common units
Contribution Agreement IV5/5/2015DCR Products Pipeline and Truck Rack$112.5 million in cash and $30.5 million through the issuance of 1,288,420 PBFX common units
Contribution Agreement V8/31/2016Torrance Valley Pipeline$175.0 million in cash
Contribution Agreement VI2/15/2017Paulsboro Natural Gas Pipeline$11.6 million affiliate promissory note
Contribution Agreements VII-X7/16/2018Development Assets$31.6 million through the issuance of 1,494,134 PBFX common units


Pursuant to Contribution Agreement V on August 31, 2016, we contributed 50% of the issued and outstanding limited liability company interests of Torrance Valley Pipeline Company LLC (“TVPC”) to PBF LLC. PBFX then acquired 50% of the issued and outstanding limited liability company interests of TVPC. TVPC’s assets consist of the Torrance Valley Pipeline which include the M55, M1 and M70 pipeline systems, including 11 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 us, is considered to be the primary beneficiary for accounting purposes and as a result PBFX fully consolidates TVPC. Subsequent to Contribution Agreement V, we record an investment in equity method investee on our consolidated balance sheet for the 50% interest in TVPC that we own. The carrying value of our equity method investment in TVPC was $169.5 million and $171.9 million at December 31, 2018 and 2017, respectively.
Pursuant to Contribution Agreement VI entered into on February 15, 2017, we contributed all of the issued and outstanding limited liability company interests of Paulsboro Natural Gas Pipeline Company LLC (“PNGPC”) to PBF LLC. PBFX Op Co, in turn acquired the limited liability company interests in PNGPC from PBF LLC in connection with Contribution Agreement VI effective February 28, 2017. PNGPC owns and operates an existing interstate natural gas pipeline that serves our Paulsboro refinery (the “Paulsboro Natural Gas Pipeline”), which is subject to regulation by the Federal Energy Regulatory Commission (“FERC”). In connection with the PNGPC contribution agreement, PBFX constructed a new pipeline to replace the existing pipeline, which commenced services in August 2017.
In consideration for the PNGPC limited liability company interests, PBFX delivered to PBF LLC (i) an $11.6 million affiliate promissory note in favor of Paulsboro Refining Company LLC, one of our wholly-owned subsidiaries (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. As a result of the completion of the Paulsboro Natural Gas Pipeline in the fourth quarter of 2017, we received full payment for the affiliate Promissory Note.
On July 16, 2018, PBFX entered into four contribution agreements with PBF LLC pursuant to which we contributed to PBF LLC certain of its subsidiaries (the “Development Assets Contribution Agreements”). Pursuant to the Development Asset Contribution Agreements, we contributed all of the issued and outstanding limited liability company interests of: Toledo Rail Logistics Company LLC (“TRLC”), whose assets consist of a loading and unloading rail facility located at the Toledo refinery (the “Toledo Rail Products Facility”); Chalmette Logistics Company LLC (“CLC”), whose assets consist of a truck loading rack facility (the “Chalmette Truck Rack”) and a rail yard facility (the “Chalmette Rosin Yard”), both of which are located at the Chalmette refinery; Paulsboro Terminaling Company LLC (“PTC”), whose assets consist of a lube oil terminal facility located at the Paulsboro refinery (the “Paulsboro Lube Oil Terminal”); and DCR Storage and Loading Company LLC (“DSLC”), whose assets consist of an ethanol storage facility located at the Delaware City refinery (the “Delaware Ethanol Storage Facility” and collectively with the Toledo Rail Products Facility, the Chalmette Truck Rack, the Chalmette Rosin Yard, and the Paulsboro Lube Oil Terminal, the “Development Assets”) to PBF LLC. PBFX Op Co, in turn acquired the limited liability company interests in the Development Assets from PBF LLC in connection with the Development Assets Contribution Agreements effective July 31, 2018.


Commercial Agreements
PBFX currently derives the majority of its revenue from long-term, fee-based commercial agreements with us, the majority of which include a minimum volume commitment (“MVC”) and are supported by contractual fee escalations for inflation adjustments and certain increases in operating costs. We believe 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.
Refer to “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements for further discussion regarding the commercial agreements with PBFX.
Omnibus Agreement
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 us. 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. On July 31, 2018, we entered into the Fifth Amended and Restated Omnibus Agreement (as amended, the “Omnibus Agreement”) in connection with the Development Assets Contribution Agreements, resulting in an increase of the estimated annual fee to $7.0 million.
Services Agreement
In connection with the PBFX Offering, PBFX also entered into an operation and management services and secondment agreement with us and certain of our subsidiaries, pursuant to which we provide PBFX with the personnel necessary for PBFX to perform its obligations under its commercial agreements. PBFX reimburses us 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 July 31, 2018, in connection with the Development Assets Contribution Agreements, we entered into the Sixth Amended and Restated Operation and Management Services and Secondment Agreement (as amended, the “Services Agreement”) with PBFX, resulting in an increase of the annual fee to $8.6 million. The Services Agreement will terminate upon the termination of the Omnibus Agreement, provided that PBFX may terminate any service on 30-days’ notice.
Corporate Offices
We currently lease approximately 58,000 square feet for our principal corporate offices in Parsippany, New Jersey. The lease for our principal corporate offices expires in 2022. Functions performed in the Parsippany office include overall corporate management, refinery and HSE management, planning and strategy, corporate finance, commercial operations, logistics, contract administration, marketing, investor relations, governmental affairs, accounting, tax, treasury, information technology, legal and human resources support functions.
We lease approximately 4,000 square feet for our regional corporate office in Long Beach, California. The lease for our Long Beach office expires in 2021. Functions performed in the Long Beach office include overall regional corporate management, planning and strategy, commercial operations, logistics, contract administration, marketing and governmental affairs.


Employees
As of December 31, 2018, we had approximately 3,184 employees, of which 1,596 are covered by collective bargaining agreements. Our hourly employees are covered by collective bargaining agreements through the United Steel Workers (“USW”), the Independent Oil Workers (“IOW”) and the International Brotherhood of Electrical Workers (“IBEW”). We consider our relations with the represented employees to be satisfactory.
Location Number of employees Employees covered by collective bargaining agreements Collective bargaining agreements Expiration date
Headquarters 379  N/A N/A
Delaware City refinery 559 377 USW January 2022
Paulsboro refinery 470 291 IOW March 2022
Toledo refinery 528 331 USW February 2022
Chalmette refinery 562 264 USW January 2022
Torrance refinery 578 288 USW, IBEW January 2022
Torrance logistics 108 45 USW January 2022
April 2021
Total employees 3,184 1,596    
Environmental, Health and Safety Matters
Our 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. Permits are also required under these laws for the operation of our refineries, pipelines and related operations and these permits are subject to revocation, modification and renewal. Compliance with applicable environmental laws, regulations and permits will continue to have an impact on our operations, results of operations and capital requirements. We believe that our current operations are in substantial compliance with existing environmental laws, regulations and permits.
In connection with the Paulsboro refinery acquisition, we assumed certain environmental remediation obligations. The Paulsboro environmental liability of $11.0 million recorded as of December 31, 2018 ($10.3 million as of December 31, 2017) represents the present value of expected future costs discounted at a rate of 8.0%. The current portion of the environmental liability is recorded in Accrued expenses and the non-current portion is recorded in Other long-term liabilities. As of December 31, 2018 and December 31, 2017, this liability is self-guaranteed by us.
In connection with the acquisition of the Delaware City assets, Valero Energy Corporation (“Valero”) remains responsible for certain pre-acquisition environmental obligations up to $20.0 million 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, we and Valero purchased ten year, $75.0 million environmental insurance policies to insure against unknown environmental liabilities at each site. In connection with the Toledo refinery acquisition, Sunoco, Inc. (R&M) 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, we obtained $3.9 million 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 United States Environmental Protection Agency (“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, we purchased a ten year, $100.0 million environmental insurance policy to insure against unknown environmental liabilities at the refinery. At the time we acquired the Chalmette refinery it was subject to a Consolidated Compliance Order and Notice of Potential Penalty (the “Order”) issued by the Louisiana Department of Environmental Quality (“LDEQ”) covering deviations from 2009 and 2010. Chalmette Refining and LDEQ subsequently entered into a dispute resolution agreement to negotiate the resolution of deviations on or before December 31, 2014. On May 18, 2018 the Order was settled by LDEQ and the Chalmette refinery for an administrative penalty of $741,000, of which $100,000 has been paid in cash and the remainder has been spent on beneficial environmental projects.
The Delaware City refinery appealed a Notice of Penalty Assessment and Secretary’s Order issued in March 2017, including a $150,000 fine, alleging violation of a 2013 Secretary’s Order authorizing crude oil shipment by barge. The Delaware Department of Natural Resources and Environmental Control (the “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 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, the Delaware City refinery appealed the Notice of Penalty Assessment and Secretary’s Order. On March 5, 2018, Notice of Penalty Assessment was settled by DNREC, the Delaware Attorney General and Delaware City refinery for $100,000. The Delaware City refinery made no admissions with respect to the alleged violations and agreed to request a Coastal Zone Act status decision prior to making crude oil shipments to destinations other than Paulsboro. The Coastal Zone Act status decision request was submitted to DNREC and the outstanding appeal was withdrawn as required under the settlement agreement.
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 (the “Coastal Zone Board”) held a public hearing and dismissed the appeal, determining that the appellants did not have standing. The appellants filed an appeal of the Coastal Zone Board’s decision with the Delaware Superior Court (the “Superior Court”) on March 30, 2017. On January 19, 2018, the Superior Court rendered an Opinion regarding the decision of the Coastal Zone Board to dismiss the appeal of the Ethanol Permit for the ethanol project. The Judge determined that the record created by the Coastal Zone Board was insufficient for the Superior Court to make a decision, and therefore remanded the case back to the Coastal Zone Board to address the deficiency in the record. Specifically, the Superior Court directed the Coastal Zone Board to address any evidence concerning whether the appellants’ claimed injuries would be affected by the increased quantity of ethanol shipments. On remand, the Coastal Zone Board met on January 28, 2019 and reversed its previous decision on standing, ruling that the appellants have standing to appeal the issuance of the Ethanol Permit. DCR is currently evaluating its appeal options.
At the time we acquired the Toledo refinery, EPA had initiated an investigation into the compliance of the refinery with EPA standards governing flaring pursuant to Section 114 of the Clean Air Act. On February 1, 2013, EPA issued an Amended Notice of Violation, and on September 20, 2013, EPA issued a Notice of Violation and Finding of Violation to Toledo refinery, alleging certain violations of the Clean Air Act at its Plant 4 and Plant 9 flares since the acquisition of the refinery on March 1, 2011. Toledo refinery and EPA subsequently entered into tolling agreements pending settlement discussions. Although the resolution has not been finalized, the civil administrative penalty is anticipated to be approximately $645,000, including supplemental environmental projects. To the extent the administrative penalty exceeds such amount, it is not expected to be material to us.
In connection with the acquisition of the Torrance refinery and related logistics assets, we assumed certain pre-existing environmental liabilities totaling $130.8 million as of December 31, 2018 ($136.5 million as of


December 31, 2017), related to certain environmental remediation obligations to address existing soil and groundwater contamination and monitoring activities and other clean-up activities, which reflects the current estimated cost of the remediation obligations. 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 our consolidated balance sheet. In addition, in connection with the acquisition of the Torrance refinery and related logistics assets, we purchased a ten year, $100.0 million environmental insurance policy to insure against unknown environmental liabilities. Furthermore, in connection with the acquisition, we assumed responsibility for certain specified environmental matters that occurred prior to our ownership of the refinery and the logistics assets, including specified incidents and/or notices of violations (“NOVs”) issued by regulatory agencies in various years before our ownership, including the Southern California Air Quality Management District (“SCAQMD”) and the Division of Occupational Safety and Health of the State of California (“Cal/OSHA”).
In connection with the acquisition of the Torrance refinery and related logistics assets, we agreed to take responsibility for NOV No. P63405 that ExxonMobil had received from the SCAQMD for Title V deviations that are alleged to have occurred in 2015. On August 14, 2018, we received a letter from SCAQMD offering to settle this NOV for $515,250. We are currently in communication with SCAQMD to resolve this NOV.
Subsequent to the acquisition, further NOVs were issued by the SCAQMD, Cal/OSHA, the City of Torrance, the City of Torrance Fire Department and the Los Angeles County Sanitation District related to alleged operational violations, emission discharges and/or flaring incidents at the refinery and the logistics assets both before and after our acquisition. EPA in November 2016 conducted a Risk Management Plan (“RMP”) inspection following the acquisition related to Torrance operations and issued preliminary findings in March 2017 concerning RMP potential operational violations. We are currently in communication with EPA to resolve the RMP preliminary findings. EPA and the California Department of Toxic Substances Control (“DTSC”) in December 2016 conducted a Resource Conservation and Recovery Act (“RCRA”) inspection following the acquisition related to Torrance operations and also issued in March 2017 preliminary findings concerning RCRA potential operational violations. In April 2017, EPA referred the RCRA preliminary findings to DTSC for final resolution. On March 1, 2018, we received a notice of intent to sue from Environmental Integrity Project, on behalf of Environment California, under RCRA with respect to the alleged violations from EPA’s and DTSC’s December 2016 inspection. On March 2, 2018, DTSC issued an order to correct alleged RCRA violations relating to the accumulation of oil bearing materials in roll off bins during 2016 and 2017. On June 14, 2018, the Torrance refinery and DTSC reached settlement regarding the oil bearing materials in the form of a stipulation and order, wherein the Torrance refinery agreed that it would recycle or properly dispose of the oil bearing materials by the end of 2018 and pay an administrative penalty of $150,000. The Torrance refinery has complied with these requirements. Following this settlement, in June 2018, DTSC referred the remaining alleged RCRA violations from EPA’s and DTSC’s December 2016 inspection to the California Attorney General for final resolution. The Torrance refinery and the California Attorney General are in discussions to resolve these remaining alleged RCRA violations. Other than the $150,000 DTSC administrative penalty, no other settlement or penalty demands have been received to date with respect to any of the other NOVs, preliminary findings, or order that are in excess of $100,000. As the ultimate outcomes are uncertain, we cannot currently estimate the final amount or timing of their resolution, but any such amount is not expected to have a material impact on our financial position, results of operations or cash flows, individually or in the aggregate.


Applicable Federal and State Regulatory Requirements
Our operations and many of the products we manufacture 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 our 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. As of July 1, 2018 most of the Northeastern states require heating oil with 15 PPM or less sulfur (except for Pennsylvania and Maryland - where less than 500 PPM sulfur is required). All of the heating oil we currently produce meet these specifications. The mandate and other requirements do not currently have a material impact on our financial position, results of operations or cash flows.
EPA issued the final Tier 3 Gasoline standards on March 3, 2014 under the CAA. 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. 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 refineries are complying with these new requirements as planned, either directly or using flexibility provided by sulfur credits generated or purchased in advance as an economic optimization. The standards set by the new rule are not expected to have a material impact on our financial position, results of operations or cash flows.
We are required to comply with the Renewable Fuel Standard (“RFS”) implemented by EPA, which sets annual quotas for the quantity of renewable fuels (such as ethanol) that must be blended into motor fuels consumed in the United States. In July 2018, EPA issued proposed amendments to the RFS program regulations that would
establish annual percentage standards for cellulosic biofuel, biomass-based diesel, advanced biofuel, and renewable fuels that would apply to all gasoline and diesel produced in the U.S. or imported in the year 2019. In addition, the separate proposal includes a proposed biomass-based diesel applicable volume for 2020. It is likely that RIN production will continue to be lower than needed forcing obligated parties, such as us, to purchase cellulosic waiver credits or purchase excess RINs from suppliers on the open market.
In addition, on November 26, 2018 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 was implemented prior to the deadline of January 30, 2018. We are in the process of implementing the requirements of this regulation. The regulation does not have a material impact on our financial position, results of operations or cash flows.
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. We continue to evaluate the impact of this regulation, and at this time do not anticipate it having a material impact on our financial position, results of operations or cash flows.


As a result of the Torrance Acquisition, we are subject to greenhouse gas emission control regulations in the state of California pursuant to Assembly Bill 32 (“AB32”). AB32 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, which was extended for an additional ten years to 2030 in July 2017. We are responsible for the AB32 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 (“SB32”) which further reduces greenhouse gas emissions targets to 40 percent below 1990 levels by 2030.
However, subsequent to the acquisition, we are recovering the majority of these costs from our customers, and as such do not expect this obligation to materially impact our financial position, results of operations, or cash flows. To the degree there are unfavorable changes to AB32 or SB32 regulations or we are unable to recover such compliance costs from customers, these regulations could have a material adverse effect on our financial position, results of operations, and cash flows.
We are subject to obligations to purchase RINs. On February 15, 2017, we received a notification that EPA records indicated that PBF Holding used potentially invalid RINs that were in fact verified under EPA’s RIN Quality Assurance Program (“QAP”) by an independent auditor as QAP A RINs. Under the regulations, use of potentially invalid QAP A RINs provided the user with an affirmative defense from civil penalties provided certain conditions are met. We have asserted the affirmative defense and if accepted by EPA will not be required to replace these RINs and will not be subject to civil penalties under the program. It is reasonably possible that EPA will not accept our defense and may assess penalties in these matters but any such amount is not expected to have a material impact on our financial position, results of operations or cash flows.
As of January 1, 2011, we are required to comply with EPA’s Control of Hazardous Air Pollutants From Mobile Sources, or MSAT2, regulations on gasoline that impose reductions in the benzene content of our produced gasoline. We purchase benzene credits to meet these requirements. Our planned capital projects will reduce the amount of benzene credits that we need to purchase. In addition, the renewable fuel standards mandate the blending of prescribed percentages of renewable fuels (e.g., ethanol and biofuels) into our produced gasoline and diesel. These new requirements, other requirements of the CAA and other presently existing or future environmental regulations may cause us to make substantial capital expenditures as well as the purchase of credits at significant cost, to enable our refineries to produce products that meet applicable requirements.
The federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 (“CERCLA”), also known as “Superfund,” imposes liability, without regard to fault or the legality of the original conduct, on certain classes of persons who are considered to be responsible for the release of a “hazardous substance” into the environment. These persons include the current or former owner or operator of the disposal site or sites where the release occurred and companies that disposed of or arranged for the disposal of the hazardous substances. Under CERCLA, such persons may be subject to joint and several liability for investigation and the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. As discussed more fully above, certain of our sites are subject to these laws and we may be held liable for investigation and remediation costs or claims for natural resource damages. It is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the environment. Analogous state laws impose similar responsibilities and liabilities on responsible parties. In our current normal operations, we have generated waste, some of which falls within the statutory definition of a “hazardous substance” and some of which may have been disposed of at sites that may require cleanup under Superfund.
As is the case with all companies engaged in industries similar to ours, we face potential exposure to future claims and lawsuits involving environmental matters. These matters include soil and water contamination, air pollution, personal injury and property damage allegedly caused by substances which we manufactured, handled, used, released or disposed of.


Current and future environmental regulations are expected to require additional expenditures, including expenditures for investigation and remediation, which may be significant, at our refineries and at our other facilities. To the extent that future expenditures for these purposes are material and can be reasonably determined, these costs are disclosed and accrued.
Our operations are also subject to various laws and regulations relating to occupational health and safety. We maintain safety training and maintenance programs as part of our ongoing efforts to ensure compliance with applicable laws and regulations. Compliance with applicable health and safety laws and regulations has required and continues to require substantial expenditures.
We cannot predict what additional health, safety and environmental legislation or regulations will be enacted or become effective in the future or how existing or future laws or regulations will be administered or interpreted with respect to our operations. Compliance with more stringent laws or regulations or adverse changes in the interpretation of existing requirements or discovery of new information such as unknown contamination could have an adverse effect on the financial position and the results of our operations and could require substantial expenditures for the installation and operation of systems and equipment that we do not currently possess.



ITEM 1A. RISK FACTORS
Risks Relating to Our Business and Industry
You should carefully read the risks and uncertainties described below. The risks and uncertainties described below are not the only ones facing our company. Additional risks and uncertainties may also impair our business operations. If any of the following risks actually occur, our business, financial condition, results of operations or cash flows would likely suffer.
The price volatility of crude oil, other feedstocks, blendstocks, refined products and fuel and utility services may have a material adverse effect on our revenues, profitability, cash flows and liquidity.
Our revenues, profitability, cash flows and liquidity from operations depend primarily on the margin above operating expenses (including the cost of refinery feedstocks, such as crude oil, intermediate partially refined petroleum products, and natural gas liquids that are processed and blended into refined products) at which we are able to sell refined products. Refining is primarily a margin-based business and, to increase profitability, it is important to maximize the yields of high value finished products while minimizing the costs of feedstock and operating expenses. When the margin between refined product prices and crude oil and other feedstock costs contracts, our earnings, profitability and cash flows are negatively affected. Refining margins historically have been volatile, and are likely to continue to be volatile, as a result of a variety of factors, including fluctuations in the prices of crude oil, other feedstocks, refined products and fuel and utility services. An increase or decrease in the price of crude oil will likely result in a similar increase or decrease in prices for refined products; however, there may be a time lag in the realization, or no such realization, of the similar increase or decrease in prices for refined products. The effect of changes in crude oil prices on our refining margins therefore depends in part on how quickly and how fully refined product prices adjust to reflect these changes.
In addition, the nature of our business requires us to maintain substantial crude oil, feedstock and refined product inventories. Because crude oil, feedstock and refined products are commodities, we have no control over the changing market value of these inventories. Our crude oil, feedstock and refined product inventories are valued at the lower of cost or market value under the last-in-first-out (“LIFO”) inventory valuation methodology. If the market value of our crude oil, feedstock and refined product inventory declines to an amount less than our LIFO cost, we would record a write-down of inventory and a non-cash chargeimpact to cost of sales.products and other. For example, during the year ended December 31, 2015, the Company2018, we recorded an adjustment to value itsour inventories to the lower of cost or market which decreased operating income from operations and net income by $427.2$351.3 million, respectively, reflecting the net change in the lower of cost or market (“LCM”) inventory reserve from $690.1$300.5 million at December 31, 20142017 to $1,117.3$651.7 million at December 31, 2015.2018.
Prices of crude oil, other feedstocks, blendstocks, and refined products depend on numerous factors beyond our control, including the supply of and demand for crude oil, other feedstocks, gasoline, diesel, ethanol, asphalt and other refined products. Such supply and demand are affected by a variety of economic, market, environmental and political conditions.
Our direct operating expense structure also impacts our profitability. Our major direct operating expenses include employee and contract labor, maintenance and energy. Our predominant variable direct operating cost is energy, which is comprised primarily of fuel and other utility services. The volatility in costs of fuel, principally natural gas, and other utility services, principally electricity, used by our refineries and other operations affect our operating costs. Fuel and utility prices have been, and will continue to be, affected by factors outside our control, such as supply and demand for fuel and utility services in both local and regional markets. Natural gas prices have historically been volatile and, typically, electricity prices fluctuate with natural gas prices. Future increases in fuel and utility prices may have a negative effect on our refining margins, profitability and cash flows.


Our profitability is affected by crude oil differentials and related factors, which fluctuate substantially.
A significant portion of our profitability is derived from the ability to purchase and process crude oil feedstocks that historically have been cheaperless expensive than benchmark crude oils, such as the heavy, sour crude oils processed at our Delaware City, Paulsboro, Chalmette and ChalmetteTorrance refineries. For our Toledo refinery, historicallyaside from recent crude

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differential volatility, purchased crude prices have historically been slightly above the WTI benchmark, however, that premium to WTIsuch crude slate typically results in favorable refinery production yield. For all locations, these crude oil differentials can vary significantly from quarter to quarter depending on overall economic conditions and trends and conditions within the markets for crude oil and refined products. Any change in these crude oil differentials may have an impact on our earnings. Our rail investment and strategy to acquire cost advantaged Mid-Continent and Canadian crude, which are priced based on WTI, could be adversely affected when the Dated Brent/WTI or related differential narrows. For example, the WTI/WCS differential, a proxy for the difference between light U.S. and heavy Canadian crudes, has decreased from $19.45 per barrel in 2014 to $11.87 per barrel for the year ended December 31, 2015, however, this decrease may not be indicative of the differential going forward. Moreover, a furtherdifferentials narrow. A narrowing of the light-heavy differential may reduce our refining margins and adversely affect our profitability and earnings. In addition, while our Toledo refinery benefits from a widening of the WTI/Dated Brent/WTI differential, a narrowing of thisBrent differential may result in our Toledo refinery losing a portion of its crude oil price advantage over certain of our competitors, which negatively impacts our profitability. This applies as wellIn addition, efforts in Canada to control the imbalance between its production and capacity to export crude may continue to result in price volatility and the narrowing of the WTI/WCS differential, which is a proxy for the difference between light U.S. and heavy Canadian crude oil, and may reduce our East Coast strategy of delivering crude by rail, which has been unfavorably impacted by narrowing Dated Brent/WTI differentials during 2015refining margins and adversely affect our rail related commitments.profitability and earnings. Divergent views have been expressed as to the expected magnitude of changes to these crude differentials in the future.future periods. Any continued or further and continued narrowing of these differentials could have a material adverse effect on our business and profitability.

The recent repealAdditionally, governmental and regulatory actions, including continued resolutions by the Organization of the Petroleum Exporting Countries to restrict crude oil export ban in the United States may affect our profitability.

In December 2015, the United States Congress passedproduction levels and the President signed the 2016 Omnibus Appropriations bill which included a repeal of the ban on the export of crude oil produced in the United States. The crude export ban was establishedexecutive actions by the Energy Policy and Conservation Act in 1975current U.S. presidential administration to reduce reliance on foreign oil producing countries. While there are differing views onadvance certain energy infrastructure projects such as the magnitude of theKeystone XL pipeline, may continue to impact of lifting the crude export ban on crude oil prices, most economists believe the export ban repeal will lead to higher crude oil prices and in turn higher gasoline prices in the United States. Crude oil is our most significant input cost and there is no guaranty that increases in our crude oil costs will be offset by corresponding increases in the selling prices of our refined products. As a result, andifferentials. Any increase in crude oil prices resulting from the repeal of theor unfavorable movements in crude oil export ban may reduce our profitability.

Our recent historical earnings have been concentrated and may continue to be concentrated in the future.
Our four refineries have similar throughput capacity, however, favorable market conditionsdifferentials due to among other things, geographic location,such actions or changing regulatory environment may negatively impact our ability to acquire crude and refined product slates, and customer demand, may cause an individual refinery to contribute more significantly to our earnings than others for a period of time. For example, our Toledo, Ohio refinery in the past has produced a substantial portion of our earnings. As a result, if there were a significant disruption to operationsoil at this refinery, our earnings could be materially adversely affected (to the extent not recoverable through insurance) disproportionately to Toledo’s portion of our consolidated throughput. The Toledo refinery, or one of our other refineries, may continue to disproportionately affect our results of operations in the future. Any prolonged disruption to the operations of such refinery, whether due to labor difficulties, destruction of or damage to such facilities, severe weather conditions, interruption of utilities service or other reasons,economical prices and could have a material adverse effect on our business results of operations or financial condition.and profitability.
A significant interruption or casualty loss at any of our refineries and related assets could reduce our production, particularly if not fully covered by our insurance. Failure by one or more insurers to honor its coverage commitments for an insured event could materially and adversely affect our future cash flows, operating results and financial condition.
Our business currently consists of owning and operating fourfive refineries and related assets. As a result, our operations could be subject to significant interruption if any of our refineries were to experience a major accident, be damaged by severe weather or other natural disaster, or otherwise be forced to shut down or curtail production due to unforeseen events, such as acts of God, nature, orders of governmental authorities, supply chain disruptions impacting our crude rail facilities or other logistical assets, power outages, acts of terrorism, fires, toxic emissions

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and maritime hazards. Any such shutdown or disruption would reduce the production from that refinery. There is also risk of mechanical failure and equipment shutdowns both in general and following unforeseen events. Further, in such situations, undamaged refinery processing units may be dependent on or interact with damaged sections of our refineries and, accordingly, are also subject to being shut down. In the event any of our refineries is forced to shut down for a significant period of time, it would have a material adverse effect on our earnings, our other results of operations and our financial condition as a whole.
As protection against these hazards, we maintain insurance coverage against some, but not all, such potential losses and liabilities. We may not be able to maintain or obtain insurance of the type and amount we desire at reasonable rates. As a result of market conditions, premiums and deductibles for certain of our insurance policies may increase substantially. In some instances, certain insurance could become unavailable or available only for reduced amounts of coverage. For example, coverage for hurricane damage can be limited, and coverage for terrorism risks can include broad exclusions. If we were to incur a significant liability for which we were not fully insured, it could have a material adverse effect on our financial position.


Our insurance program includes a number of insurance carriers. Significant disruptions in financial markets could lead to a deterioration in the financial condition of many financial institutions, including insurance companies and, therefore, we may not be able to obtain the full amount of our insurance coverage for insured events.
Our refineries are subject to interruptions of supply and distribution as a result of our reliance on pipelines and railroads for transportation of crude oil and refined products.

OverOur Toledo, Chalmette and Torrance refineries receive a significant portion of their crude oil through pipelines. These pipelines include the past few years, we expandedEnbridge system, Capline and upgraded existing on-site railroad infrastructure at our Delaware City refinery, which significantly increased our capacity to unloadMid-Valley pipelines for supplying crude by rail. Currently, the majority of the crude delivered to this facility is consumed at our Delaware City refinery, although we also transport some of the crude delivered by rail from Delaware City via barge to our Paulsboro refinery. The Delaware City rail unloading facilities allowToledo refinery, the MOEM and CAM pipelines for supplying crude to our East Coast refineries to source WTI-based crudes from Western CanadaChalmette refinery and the Mid-Continent, which can provide significant cost advantages versus traditional Brent-based international crudes. Any disruptions or restrictionsSan Joaquin Pipeline, San Ardo and Coastal Pipeline systems for supplying crude to our supply of crude by rail due to problems with third party logistics infrastructure or operations or asTorrance refinery. Additionally, our Toledo, Chalmette and Torrance refineries deliver a result of increased regulations could increase our crude costs and negatively impact our results of operations and cash flows.    
Our Toledo refinery receives a substantialsignificant portion of its crude oil and delivers a portion of itsthe refined products through pipelines. The Enbridge system is our primary supply route for crude oil from Canada,These pipelines include pipelines such as the Bakken region and Michigan, and supplies approximately 55% to 65% of the crude oil used at our Toledo refinery. In addition, we source domestic crude oil through our connections to the Capline and Mid-Valley pipelines. We also distribute a portion of our transportation fuels through pipelines owned and operated by Sunoco Logistics Partners L.P. and Buckeye Partners L.P. pipelines at Toledo, the Collins Pipeline at our Chalmette refinery and Jet Pipeline to the Los Angeles International Airport, the Product Pipeline to Vernon and the Product Pipeline to Atwood at our Torrance refinery. We could experience an interruption of supply or delivery, or an increased cost of receiving crude oil and delivering refined products to market, if the ability of these pipelines to transport crude oil or refined products is disrupted because of accidents, weather interruptions, governmental regulation, terrorism, other third partythird-party action or casualty or other events.
Our Chalmette refinery, located onThe Delaware City rail unloading facilities and supporting infrastructure allow our East Coast refineries to source WTI-based crudes from Western Canada and the Mississippi River, sources approximately 50%Mid-Continent, which may provide significant cost advantages versus traditional Brent-based international crudes in certain market environments. Any disruptions or restrictions to our supply of its crude oilby rail due to problems with third-party logistics infrastructure or operations or as a result of increased regulations, could increase our crude costs and feedstocks via marine terminals and approximately 50% via pipelines. The Chalmette refinery distributes approximately 80% of its refined products through the Collins Pipeline, 15% through marine terminals and 5% through its truck rack. As with our other refineries, any interruption of supply or delivery or other issues with logistical assets, or an increased cost of receiving crude oil and delivering refined products to market could negatively impact our results of operations and cash flows.
In addition, due to the common carrier regulatory obligation applicable to interstate oil pipelines, capacity is proratedallocation among shippers in accordance with the tariff then in effectcan become contentious in the event there are nominationsdemand is in excess of capacity. Therefore, nominations by new shippers or increased nominations by existing shippers may reduce the capacity available to us. Any prolonged interruption in the operation or curtailment of available capacity of

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the pipelines that we rely upon for transportation of crude oil and refined products could have a further material adverse effect on our business, financial condition, results of operations and cash flows.
Regulation of emissions of greenhouse gases could force us to incur increased capital and operating costs and could have a material adverse effect on our results of operations and financial condition.
Both houses of Congress have actively considered legislation to reduce emissions of greenhouse gases (“GHGs”), such as carbon dioxide and methane, including proposals to: (i) establish a cap and trade system, (ii) create a federal renewable energy or “clean” energy standard requiring electric utilities to provide a certain percentage of power from such sources, and (iii) create enhanced incentives for use of renewable energy and increased efficiency in energy supply and use. In addition, EPA is taking steps to regulate GHGs under the existing federal Clean Air Act (the “CAA”). EPA has already adopted regulations limiting emissions of GHGs from motor vehicles, addressing the permitting of GHG emissions from stationary sources, and requiring the reporting of GHG emissions from specified large GHG emission sources, including refineries. These and similar regulations could require us to incur costs to monitor and report GHG emissions or reduce emissions of GHGs associated with our operations. In addition, various states, individually as well as in some cases on a regional basis, have taken steps to control GHG emissions, including adoption of GHG reporting requirements, cap and trade systems and renewable portfolio standards (such as AB32 regulations in California). Efforts have also been undertaken to delay, limit or prohibit EPA and possibly state action to regulate GHG emissions, and it is not possible at this time to predict the ultimate form, timing or extent of federal or state regulation. In addition, it is currently uncertain how the current presidential administration will address GHG emissions. In the event we do incur increased costs as a result of increased efforts to control GHG emissions, we may not be able to pass on any of these costs to our customers. Such requirements also could adversely affect demand for the refined petroleum products that we produce. Any increased costs or reduced demand could materially and adversely affect our business and results of operation.


Requirements to reduce emissions could result in increased costs to operate and maintain our facilities as well as implement and manage new emission controls and programs put in place. For example, AB32 in California requires the state to reduce its GHG emissions to 1990 levels by 2020. Additionally, in September 2016, the state of California enacted Senate Bill 32 which further reduces greenhouse gas emissions targets to 40 percent below 1990 levels by 2030. Two regulations implemented to achieve these goals are Cap-and-Trade and the Low Carbon Fuel Standard (“LCFS”). In 2012, the California Air Resource Board (“CARB”) implemented Cap-and-Trade. This program currently places a cap on GHGs and we are required to acquire a sufficient number of credits to cover emissions from our refineries and our in-state sales of gasoline and diesel. In 2009, CARB adopted the LCFS, which requires a 10% reduction in the carbon intensity of gasoline and diesel by 2020. Compliance is achieved through blending lower carbon intensity biofuels into gasoline and diesel or by purchasing credits. Compliance with each of these programs is facilitated through a market-based credit system. If sufficient credits are unavailable for purchase or we are unable to pass through costs to our customers, we have to pay a higher price for credits or if we are otherwise unable to meet our compliance obligations, our financial condition and results of operations could be adversely affected.
Our hedging activities may limit our potential gains, exacerbate potential losses and involve other risks.
We may enter into commodity derivatives contracts to hedge our crude price risk or crack spread risk with respect to a portion of our expected gasoline and distillate production on a rolling basis or to hedge our exposure to the price of natural gas, which is a significant component of our refinery operating expenses. Consistent with that policy we may hedge some percentage of our future crude and natural gas supply. We may enter into hedging arrangements with the intent to secure a minimum fixed cash flow stream on the volume of products hedged during the hedge term and to protect against volatility in commodity prices. Our hedging arrangements may fail to fully achieve these objectives for a variety of reasons, including our failure to have adequate hedging arrangements, if any, in effect at any particular time and the failure of our hedging arrangements to produce the anticipated results. We may not be able to procure adequate hedging arrangements due to a variety of factors. Moreover, such transactions may limit our ability to benefit from favorable changes in crude oil, refined product and natural gas prices. In addition, our hedging activities may expose us to the risk of financial loss in certain circumstances, including instances in which:
the volumes of our actual use of crude oil or natural gas or production of the applicable refined products is less than the volumes subject to the hedging arrangement;
accidents, interruptions in feedstock transportation, inclement weather or other events cause unscheduled shutdowns or otherwise adversely affect our refineries, or those of our suppliers or customers;
changes in commodity prices have a material impact on collateral and margin requirements under our hedging arrangements, resulting in us being subject to margin calls;
the counterparties to our derivative contracts fail to perform under the contracts; or
a sudden, unexpected event materially impacts the commodity or crack spread subject to the hedging arrangement.
As a result, the effectiveness of our hedging strategy could have a material impact on our financial results. See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Quantitative and Qualitative Disclosures About Market Risk.”
In addition, these hedging activities involve basis risk. Basis risk in a hedging arrangement occurs when the price of the commodity we hedge is more or less variable than the index upon which the hedged commodity is based, thereby making the hedge less effective. For example, a NYMEX index used for hedging certain volumes of our crude oil or refined products may have more or less variability than the actual cost or price we realize for such crude oil or refined products. We may not hedge all the basis risk inherent in our hedging arrangements and derivative contracts.


We may have capital needs for which our internally generated cash flows and other sources of liquidity may not be adequate.
If we cannot generate sufficient cash flows or otherwise secure sufficient liquidity to support our short-term and long-term capital requirements, we may not be able to meet our payment obligations or our future debt obligations, comply with certain deadlines related to environmental regulations and standards, or pursue our business strategies, including acquisitions, in which case our operations may not perform as we currently expect. We have substantial short-term capital needs and may have substantial long term capital needs. Our short-term working capital needs are primarily related to financing certain of our crude oil and refined products inventory not covered by our various supply and Inventory Intermediation Agreements. We terminated our supply agreement with Statoil for our Delaware City refinery effective December 31, 2015 and our MSCG offtake agreements for our Paulsboro and Delaware City refineries effective July 1, 2013. Concurrent with the termination of our MSCG offtake agreements, we entered into Inventory Intermediation Agreements with J. Aron at our Paulsboro and Delaware City refineries. Pursuant to the Inventory Intermediation Agreements, J. Aron purchases and holds title to certain of the intermediate and finished products (the “Products”) produced by the Delaware City and Paulsboro refineries (the “Refineries”) and delivered into the tanks at the refineriesRefineries (or at other locations outside of the refineriesRefineries as agreed upon by both parties). Furthermore, J. Aron agrees to sell the intermediate and finished productsProducts back to us as they are discharged out of the refineries'Refineries’ tanks (or other locations outside of the refineriesRefineries as agreed upon by both parties). On May 29, 2015, the Company entered into amended and restated inventory intermediation agreements with J. Aron pursuant to which certain terms of the existing inventory intermediation agreements were amended, including, among other things, pricing and an extension of the term for a period of two years from the original expiry date of July 1, 2015, subject to certain early termination rights. In addition, the A&R Intermediation Agreements include one-year renewal clauses by mutual consent of both parties. We market and sell the finished productsProducts independently to third parties.
If we cannot adequately handle our crude oil and feedstock requirements or if we are required to obtain our crude oil supply at our other refineries without the benefit of the existing supply arrangements or the applicable counterparty defaults in its obligations, our crude oil pricing costs may increase as the number of days between when we pay for the crude oil and when the crude oil is delivered to us increases. Termination of our A&RInventory Intermediation Agreements with J. Aron would require us to finance our refined products inventory covered by the agreements at terms that may not be as favorable. Additionally, we are obligated to repurchase from J. Aron all volumes of products located at the refineries’ storage tanks (or at other locations outside of the refineries as agreed upon by both parties) upon termination of these agreements, which may have a material adverse impact on our working capital and financial condition. Further, if we are not able to market and sell our finished productsProducts to credit worthy customers, we may be subject to delays in the collection of our accounts receivable and exposure to additional credit risk. Such increased exposure could negatively impact our liquidity due to our increased working capital needs as a result of the increase in the amount of crude oil inventory and accounts receivable we would have to carry on our consolidated balance sheet. Our long-term needs for cash include those to support ongoing capital expenditures for equipment maintenance and upgrades during turnarounds at our refineries and to complete our routine and normally scheduled maintenance, regulatory and security expenditures.
In addition, from time to time, we are required to spend significant amounts for repairs when one or more processing units experiences temporary shutdowns. We continue to utilize significant capital to upgrade equipment, improve facilities, and reduce operational, safety and environmental risks. In connection with the Paulsboro acquisition,and Torrance acquisitions, we assumed certain significant environmental obligations, and may similarly do so in future acquisitions. We will likely incur substantial compliance costs in connection with new or changing environmental, health and safety regulations. See “Item 7. Management’s Discussion and Analysis of Financial Condition.” Our liquidity condition will affect our ability to satisfy any and all of these needs or obligations.

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We may not be able to obtain funding on acceptable terms or at all because of volatility and uncertainty in the credit and capital markets. This may hinder or prevent us from meeting our future capital needs.
GlobalIn the past, global financial markets and economic conditions have been, and may continue toagain be, subject to disruption and volatile due to a variety of factors, including uncertainty in the financial services sector, low consumer confidence, falling commodity prices, geopolitical issues and the generally weak economic conditions. In addition, the fixed income markets have experienced periods of extreme volatility that have negatively impacted market liquidity conditions. As a result, the cost of raising money in the debt and equity capital markets has increased substantially at times while the availability of funds from those markets diminished significantly. In particular, as a result of concerns about the stability of financial markets generally, and the solvency of lending counterparties specifically,which may be subject to unforeseen disruptions, the cost of obtaining money from the credit markets may increase as many lenders and institutional investors increase interest rates, enact tighter lending standards, refuse to refinance existing debt on similar terms or at all and reduce or, in some cases, cease to provide funding to borrowers. Due to these factors, we cannot be


certain that new debt or equity financing will be available on acceptable terms. If funding is not available when needed, or is available only on unfavorable terms, we may be unable to meet our obligations as they come due. Moreover, without adequate funding, we may be unable to execute our growth strategy, complete future acquisitions, take advantage of other business opportunities or respond to competitive pressures, any of which could have a material adverse effect on our revenues and results of operations.
Competition from companies who produce their own supply of feedstocks, have extensive retail outlets, make alternative fuels or have greater financial and other resources than we do could materially and adversely affect our business and results of operations.
Our refining operations compete with domestic refiners and marketers in regions of the United States in which we operate, as well as with domestic refiners in other regions and foreign refiners that import products into the United States. In addition, we compete with other refiners, producers and marketers in other industries that supply their own renewable fuels or alternative forms of energy and fuels to satisfy the requirements of our industrial, commercial and individual consumers. Certain of our competitors have larger and more complex refineries, and may be able to realize lower per-barrel costs or higher margins per barrel of throughput. Several of our principal competitors are integrated national or international oil companies that are larger and have substantially greater resources than we do and access to proprietary sources of controlled crude oil production. Unlike these competitors, we obtain substantially all of our feedstocks from unaffiliated sources. We are not engaged in the petroleum exploration and production business and therefore do not produce any of our crude oil feedstocks. We do not have a retail business and therefore are dependent upon others for outlets for our refined products. Because of their integrated operations and larger capitalization, these companies may be more flexible in responding to volatile industry or market conditions, such as shortages of crude oil supply and other feedstocks or intense price fluctuations.
Newer or upgraded refineries will often be more efficient than our refineries, which may put us at a competitive disadvantage. We have taken significant measures to maintain our refineries including the installation of new equipment and redesigning older equipment to improve our operations. However, these actions involve significant uncertainties, since upgraded equipment may not perform at expected throughput levels, the yield and product quality of new equipment may differ from design specifications and modifications may be needed to correct equipment that does not perform as expected. Any of these risks associated with new equipment, redesigned older equipment or repaired equipment could lead to lower revenues or higher costs or otherwise have an adverse effect on future results of operations and financial condition. Over time, our refineries or certain refinery units may become obsolete, or be unable to compete, because of the construction of new, more efficient facilities by our competitors.
A portion of our workforce is unionized, and we may face labor disruptions that would interfere with our operations.
At Delaware City, Toledo, Chalmette and Torrance, most hourly employees are covered by a collective bargaining agreement through the USW. The agreements with the USW covering the represented employees at the Delaware City refinery, Chalmette refinery, and Torrance refinery are scheduled to expire in January 2022, the agreement with the USW covering Toledo refinery is scheduled to expire in February 2022 and the agreements with the USW covering certain Torrance Logistics employees are scheduled to expire in April 2021 and January 2022. Similarly, at the Paulsboro refinery, hourly employees are represented by the IOW under a contract scheduled to expire in March 2022 and certain employees at the Torrance refinery are represented by the IBEW under a contract scheduled to expire in January 2022. Future negotiations as our collective agreements expire may result in labor unrest for which a strike or work stoppage is possible. Strikes and/or work stoppages could negatively affect our operational and financial results and may increase operating expenses at the refineries.


Any political instability, military strikes, sustained military campaigns, terrorist activity, or changes in foreign policy could have a material adverse effect on our business, results of operations and financial condition.
Any political instability, military strikes, sustained military campaigns, terrorist activity, or changes in foreign policy in areas or regions of the world where we acquire crude oil and other raw materials or sell our refined petroleum products may affect our business in unpredictable ways, including forcing us to increase security

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measures and causing disruptions of supplies and distribution markets. We may also be subject to United States trade and economic sanctions laws, which change frequently as a result of foreign policy developments, and which may necessitate changes to our crude oil acquisition activities. Further, like other industrial companies, our facilities may be the target of terrorist activities. Any act of war or terrorism that resulted in damage to any of our refineries or third-party facilities upon which we are dependent for our business operations could have a material adverse effect on our business, results of operations and financial condition.
Economic turmoil in the global financial system has had and mayor an economic slowdown or recession in the future may have an adverse impact on the refining industry.industry.
Our business and profitability are affected by the overall level of demand for our products, which in turn is affected by factors such as overall levels of economic activity and business and consumer confidence and spending. DeclinesIn the past, declines in global economic activity and consumer and business confidence and spending duringsignificantly reduced the recent global downturn significantly reducedlevel of demand for our products. In addition, macroeconomic trends, such as economic recession, inflation, unemployment and interest rates can affect the level of demand for our products. Reduced demand for our products has had and may continue to have an adverse impact on our business, financial condition, results of operations and cash flows. In addition, downturns in the economy impact the demand for refined fuels and, in turn, result in excess refining capacity. Refining margins are impacted by changes in domestic and global refining capacity, as increases in refining capacity can adversely impact refining margins, earnings and cash flows.
Our business is indirectly exposed to risks faced by our suppliers, customers and other business partners. The impact on these constituencies of the risks posed by economic turmoil in the global financial system have included or could include interruptions or delays in the performance by counterparties to our contracts, reductions and delays in customer purchases, delays in or the inability of customers to obtain financing to purchase our products and the inability of customers to pay for our products. Any of these events may have an adverse impact on our business, financial condition, results of operations and cash flows.
We must make substantial capital expenditures on our operating facilities to maintain their reliability and efficiency. If we are unable to complete capital projects at their expected costs and/or in a timely manner, or if the market conditions assumed in our project economics deteriorate, our financial condition, results of operations or cash flows could be materially and adversely affected.
Delays or cost increases related to capital spending programs involving engineering, procurement and construction of new facilities (or improvements and repairs to our existing facilities and equipment)equipment, including turnarounds) could adversely affect our ability to achieve targeted internal rates of return and operating results. Such delays or cost increases may arise as a result of unpredictable factors in the marketplace, many of which are beyond our control, including:
denial or delay in obtaining regulatory approvals and/or permits;
unplanned increases in the cost of construction materials or labor;
disruptions in transportation of modular components and/or construction materials;
severe adverse weather conditions, natural disasters or other events (such as equipment malfunctions, explosions, fires or spills) affecting our facilities, or those of vendors and suppliers;
shortages of sufficiently skilled labor, or labor disagreements resulting in unplanned work stoppages;
market-related increases in a project’s debt or equity financing costs; and/or
non-performance or force majeure by, or disputes with, vendors, suppliers, contractors or sub-contractors involved with a project.


Our refineries contain many processing units, a number of which have been in operation for many years. Equipment, even if properly maintained, may require significant capital expenditures and expenses to keep it operating at optimum efficiency. One or more of the units may require unscheduled downtime for unanticipated maintenance or repairs that are more frequent than our scheduled turnarounds for such units. Scheduled and unscheduled maintenance could reduce our revenues during the period of time that the units are not operating.
Our forecasted internal rates of return are also based upon our projections of future market fundamentals, which are not within our control, including changes in general economic conditions, available alternative supply and customer demand. Any one or more of these factors could have a significant impact on our business. If we

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were unable to make up the delays associated with such factors or to recover the related costs, or if market conditions change, it could materially and adversely affect our financial position, results of operations or cash flows.
Acquisitions that we may undertake in the future involve a number of risks, any of which could cause us not to realize the anticipated benefits.
We may not be successful in acquiring additional assets, and any acquisitions that we do consummate may not produce the anticipated benefits or may have adverse effects on our business and operating results. We may selectively consider strategic acquisitions in the future within the refining and mid-stream sector based on performance through the cycle, advantageous access to crude oil supplies, attractive refined products market fundamentals and access to distribution and logistics infrastructure. Our ability to do so will be dependent upon a number of factors, including our ability to identify acceptable acquisition candidates, consummate acquisitions on acceptable terms, successfully integrate acquired assets and obtain financing to fund acquisitions and to support our growth and many other factors beyond our control. Risks associated with acquisitions include those relating to the diversion of management time and attention from our existing business, liability for known or unknown environmental conditions or other contingent liabilities and greater than anticipated expenditures required for compliance with environmental, safety or other regulatory standards or for investments to improve operating results, and the incurrence of additional indebtedness to finance acquisitions or capital expenditures relating to acquired assets. We may also enter into transition services agreements in the future with sellers of any additional refineries we acquire. Such services may not be performed timely and effectively, and any significant disruption in such transition services or unanticipated costs related to such services could adversely affect our business and results of operations. In addition, it is likely that, when we acquire refineries, we will not have access to the type of historical financial information that we will require regarding the prior operation of the refineries. As a result, it may be difficult for investors to evaluate the probable impact of significant acquisitions on our financial performance until we have operated the acquired refineries for a substantial period of time.
Our business may suffer if any of our senior executives or other key employees discontinues employment with us. Furthermore, a shortage of skilled labor or disruptions in our labor force may make it difficult for us to maintain labor productivity.
Our future success depends to a large extent on the services of our senior executives and other key employees. Our business depends on our continuing ability to recruit, train and retain highly qualified employees in all areas of our operations, including engineering, accounting, business operations, finance and other key back-office and mid-office personnel. Furthermore, our operations require skilled and experienced employees with proficiency in multiple tasks. The competition for these employees is intense, and the loss of these executives or employees could harm our business. If any of these executives or other key personnel resigns or becomes unable to continue in his or her present role and is not adequately replaced, our business operations could be materially adversely affected.
A portion of our workforce is unionized, and we may face labor disruptions that would interfere with our operations.
At Delaware City, Toledo and Chalmette, most hourly employees are covered by a collective bargaining agreement through the United Steel Workers (“USW”). The agreements with the USW covering Delaware City and Toledo are scheduled to expire in February 2018 while the agreement with the USW covering Chalmette is scheduled to expire in January 2019. Similarly, at Paulsboro hourly employees are represented by the Independent Oil Workers (“IOW”) under a contract scheduled to expire in March 2018. Future negotiations after 2018 may result in labor unrest for which a strike or work stoppage is possible. Strikes and/or work stoppages could negatively affect our operational and financial results and may increase operating expenses at the refineries.
Our hedging activities may limit our potential gains, exacerbate potential losses and involve other risks.
We may enter into commodity derivatives contracts to hedge our crude price risk or crack spread risk with respect to a portion of our expected gasoline and distillate production on a rolling basis. Consistent with that policy we may hedge some percentage of future crude supply. We may enter into hedging arrangements with the intent

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to secure a minimum fixed cash flow stream on the volume of products hedged during the hedge term and to protect against volatility in commodity prices. Our hedging arrangements may fail to fully achieve these objectives for a variety of reasons, including our failure to have adequate hedging arrangements, if any, in effect at any particular time and the failure of our hedging arrangements to produce the anticipated results. We may not be able to procure adequate hedging arrangements due to a variety of factors. Moreover, such transactions may limit our ability to benefit from favorable changes in crude oil and refined product prices. In addition, our hedging activities may expose us to the risk of financial loss in certain circumstances, including instances in which:
the volumes of our actual use of crude oil or production of the applicable refined products is less than the volumes subject to the hedging arrangement;
accidents, interruptions in feedstock transportation, inclement weather or other events cause unscheduled shutdowns or otherwise adversely affect our refineries, or those of our suppliers or customers;
changes in commodity prices have a material impact on collateral and margin requirements under our hedging arrangements, resulting in us being subject to margin calls;
the counterparties to our futures contracts fail to perform under the contracts; or
a sudden, unexpected event materially impacts the commodity or crack spread subject to the hedging arrangement.
As a result, the effectiveness of our hedging strategy could have a material impact on our financial results. See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Quantitative and Qualitative Disclosures About Market Risk.”
In addition, these hedging activities involve basis risk. Basis risk in a hedging arrangement occurs when the price of the commodity we hedge is more or less variable than the index upon which the hedged commodity is based, thereby making the hedge less effective. For example, a NYMEX index used for hedging certain volumes of our crude oil or refined products may have more or less variability than the cost or price for such crude oil or refined products. We may not hedge the basis risk inherent in our hedging arrangements and derivative contracts.
Our commodity derivative activities could result in period-to-period earnings volatility.
We do not currently apply hedge accounting to allany of our commodity derivative contracts and, as a result, unrealized gains and losses will be charged to our earnings based on the increase or decrease in the market value of such unsettled positions. These gains and losses may be reflected in our income statement in periods that differ from when the settlement of the underlying hedged items (i.e., gross margins) are reflected in our income statement. Such derivative gains or losses in earnings may produce significant period-to-period earnings volatility that is not necessarily reflective of our underlying operational performance.
The adoption of derivativesDerivatives legislation, byincluding compliance with the United States CongressDodd-Frank Act, could have an adverse effect on our business, including our ability to use derivatives contracts to reduce the effect of commodity price, interest rate and other risks associated with our business.
The United States Congress in 2010 adoptedpassed the Dodd-Frank Wall Street Reform and Consumer Protection Act or the Dodd-Frank Act,(the “Dodd-Frank Act”) which, among other things, established federal oversight and regulation of the over-the-counter derivatives market and entities that participate in that market. In connection with the Dodd-Frank Act, the Commodity Futures Trading Commission, or the CFTC, has proposedestablished rules to set position limits for certain futures and option contracts, and for swaps that are their economic equivalent, in the major energy markets. The legislation may alsoand related regulations require us to comply with margin requirements and with certain clearing and trade-execution requirements if we are in scope and do not otherwise satisfy certain specific exceptions. The legislation may also require the counterparties to our derivatives contracts to transfer or assign some of their derivatives contracts to a separate entity, which may not be as creditworthy as the current counterparty. The legislation and any newrelated regulations could significantly increase the cost of regulatory compliance as well as derivatives contracts (including through requirements to post collateral), materially alter the terms of derivatives contracts, reduce the availability of derivatives to protect against risks we encounter and reduce our ability to monetize or restructure our existing derivatives contracts, and increase our exposure to less creditworthy counterparties.contracts. If we reduce our usefail to comply with applicable regulations or the costs of derivatives as a result of the legislation and regulations,compliance becomes prohibitive, our results of operations may become more volatile and our cash flows may be less predictable, which could adversely

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affect our ability to plan for and fund capital expenditures. Any of these consequences could have a material adverse effect on us, our financial condition and our results of operations.
We may incur significant liability under, or costs and capital expenditures to comply with, environmental and health and safety regulations, which are complex and change frequently.
Our operations are subject to federal, state and local laws regulating, among other things, the use and/or handling of petroleum and other regulated materials, the emission and discharge of materials into the environment, waste management, and remediation of discharges of petroleum and petroleum products, characteristics and composition of gasoline and distillates and other matters otherwise relating to the protection of the environment and the health and safety of the surrounding community. For example, the SCAQMD is currently considering further regulations on, or potentially banning the use of, modified hydrofluoric acid, also known as MHF, in Southern California. We utilize MHF as an alkylation catalyst in the manufacturing of gasoline at our Torrance refinery. If MHF usage is limited or restricted by the SCAQMD, our current Torrance refinery operations would be adversely affected, which could have a material adverse effect on our business, financial condition, cash flows and results of operations. Our operations are also subject to extensive laws and regulations relating to occupational health and safety.
We cannot predict what additional environmental, health and safety legislation or regulations may be adopted in the future, or how existing or future laws or regulations may be administered or interpreted with respect to our operations. Many of these laws and regulations have become increasingly stringent over time, and the cost of compliance with these requirements can be expected to increase over time.
Certain environmental laws impose strict, and in certain circumstances, joint and several, liability for costs of investigation and cleanup of spills, discharges or releases on owners and operators of, as well as persons who arrange for treatment or disposal of regulated materials at, contaminated sites. Under these laws, we may incur liability or be required to pay penalties for past contamination, and third parties may assert claims against us for damages allegedly arising out of any past or future contamination. The potential penalties and clean-up costs for past or future spills, discharges or releases, the failure of prior owners of our facilities to complete their clean-up


obligations, the liability to third parties for damage to their property, or the need to address newly-discovered information or conditions that may require a response could be significant, and the payment of these amounts could have a material adverse effect on our business, financial condition, cash flows and results of operations.
Environmental clean-up and remediation costs of our sites and environmental litigation could decrease our net cash flow, reduce our results of operations and impair our financial condition.
We are subject to liability for the investigation and clean-up of environmental contamination at each of the properties that we own or operate and at off-site locations where we arrange for the treatment or disposal of regulated materials. We may become involved in litigation or other proceedings related to the foregoing. If we were to be held responsible for damages in any such litigation or proceedings, such costs may not be covered by insurance and may be material. Historical soil and groundwater contamination has been identified at our refineries. Currently, remediation projects for such contamination are underway in accordance with regulatory requirements at our refineries. In connection with the acquisitions of certain of our refineries and logistics assets, the prior owners have retained certain liabilities or indemnified us for certain liabilities, including those relating to pre-acquisition soil and groundwater conditions, and in some instances we have assumed certain liabilities and environmental obligations, including certain existing and potential remediation obligations. If the prior owners fail to satisfy their obligations for any reason, or if significant liabilities arise in the areas in which we assumed liability, we may become responsible for remediation expenses and other environmental liabilities, which could have a material adverse effect on our business, financial condition, results of operations and cash flow. As a result, in addition to making capital expenditures or incurring other costs to comply with environmental laws, we also may be liable for significant environmental litigation or for investigation and remediation costs and other liabilities arising from the ownership or operation of these assets by prior owners, which could materially adversely affect our business, financial condition, results of operations and cash flow. See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Contractual Obligations and Commitments” and “Item 1. Business—Environmental, Health and Safety Matters.”
We may also face liability arising from current or future claims alleging personal injury or property damage due to exposure to chemicals or other regulated materials, such as asbestos, benzene, silica dust and petroleum hydrocarbons, at or from our facilities. We may also face liability for personal injury, property damage, natural resource damage or clean-up costs for the alleged migration of contamination from our properties. A significant increase in the number or success of these claims could materially adversely affect our business, financial condition, results of operations and cash flow.
Our operations could be disrupted if our critical information systems are hacked or fail, causing increased expenses and loss of sales.
Our business is highly dependent on financial, accounting and other data processing systems and other communications and information systems, including our enterprise resource planning tools. We process a large number of transactions on a daily basis and rely upon the proper functioning of computer systems. If a key system was hacked or otherwise interfered with by an unauthorized access, or was to fail or experience unscheduled downtime for any reason, even if only for a short period, our operations and financial results could be affected adversely. Our systems could be damaged or interrupted by a security breach, cyber-attack, human error, fraud, fire, flood, power loss, telecommunications failure or similar event. We have a formal disaster recovery plan in place, but this plan may not prevent delays or other complications that could arise from an information systems failure. Further,
As the frequency of attempted cyber-attacks has increased in recent years, we have taken several actions to enhance our strategy to address and monitor cyber related risks. We have instituted a cybersecurity team that is dedicated and responsible for the design and execution of our cyber-risk management strategy. However, there can be no assurance that these efforts will be effective to prevent cyber attacks or other interruptions of, or damage to, our key systems, business or operations, or that our business interruption insurance may notwill compensate us adequately for losses that may occur. Finally, federal legislation relating to cyber-security threatsoccur which could impose additional requirements onmaterially, adversely affect our operations.business, financial condition, results of operations and cash flows.


Product liability claims and litigation could adversely affect our business and results of operations.
Product liability is a significant commercial risk. Substantial damage awards have been made in certain jurisdictions against manufacturers and resellers based upon claims for injuries and property damage caused by the use of or exposure to various products. Failure of our products to meet required specifications or claims that a product is inherently defective could result in product liability claims from our shippers and customers, and also arise from contaminated or off-specification product in commingled pipelines and storage tanks and/or defective fuels. Product liability claims against us could have a material adverse effect on our business or results of operations.
We may incur significant liability under, or costs and capital expenditures to comply with, environmental and health and safety regulations, which are complex and change frequently.
Our operations are subject to federal, state and local laws regulating, among other things, the handling of petroleum and other regulated materials, the emission and discharge of materials into the environment, waste management, and remediation of discharges of petroleum and petroleum products, characteristics and composition of gasoline and distillates and other matters otherwise relating to the protection of the environment. Our operations are also subject to extensive laws and regulations relating to occupational health and safety.
We cannot predict what additional environmental, health and safety legislation or regulations may be adopted in the future, or how existing or future laws or regulations may be administered or interpreted with respect to our operations. Many of these laws and regulations are becoming increasingly stringent, and the cost of compliance with these requirements can be expected to increase over time.
Certain environmental laws impose strict, and in certain circumstances, joint and several, liability for costs of investigation and cleanup of such spills, discharges or releases on owners and operators of, as well as persons who arrange for treatment or disposal of regulated materials at, contaminated sites. Under these laws, we may incur liability or be required to pay penalties for past contamination, and third parties may assert claims against us for damages allegedly arising out of any past or future contamination. The potential penalties and clean-up costs for past or future releases or spills, the failure of prior owners of our facilities to complete their clean-up obligations, the liability to third parties for damage to their property, or the need to address newly-discovered information or conditions that may require a response could be significant, and the payment of these amounts could have a material adverse effect on our business, financial condition and results of operations.
Environmental clean-up and remediation costs of our sites and environmental litigation could decrease our net cash flow, reduce our results of operations and impair our financial condition.
We are subject to liability for the investigation and clean-up of environmental contamination at each of the properties that we own or operate and at off-site locations where we arrange for the treatment or disposal of regulated

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materials. We may become involved in future litigation or other proceedings. If we were to be held responsible for damages in any litigation or proceedings, such costs may not be covered by insurance and may be material. Historical soil and groundwater contamination has been identified at each of our refineries. Currently remediation projects are underway in accordance with regulatory requirements at the Paulsboro, Delaware City and Chalmette refineries. In connection with the acquisitions of our refineries, the prior owners have retained certain liabilities or indemnified us for certain liabilities, including those relating to pre-acquisition soil and groundwater conditions, and in some instances we have assumed certain liabilities and environmental obligations, including certain existing and potential remediation obligations at the Paulsboro and Chalmette refineries. If the prior owners fail to satisfy their obligations for any reason, or if significant liabilities arise in the areas in which we assumed liability, we may become responsible for remediation expenses and other environmental liabilities, which could have a material adverse effect on our financial condition. As a result, in addition to making capital expenditures or incurring other costs to comply with environmental laws, we also may be liable for significant environmental litigation or for investigation and remediation costs and other liabilities arising from the ownership or operation of these assets by prior owners, which could materially adversely affect our financial condition, results of operations and cash flow. See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Contractual Obligations and Commitments” and “Item 1. Business—Environmental, Health and Safety Matters.”
We may also face liability arising from current or future claims alleging personal injury or property damage due to exposure to chemicals or other regulated materials, such as asbestos, benzene, silica dust and petroleum hydrocarbons, at or from our facilities. We may also face liability for personal injury, property damage, natural resource damage or clean-up costs for the alleged migration of contamination from our properties. A significant increase in the number or success of these claims could materially adversely affect our financial condition, results of operations and cash flow.
Regulation of emissions of greenhouse gases could force us to incur increased capital and operating costs and could have a material adverse effect on our results of operations and financial condition.
Both houses of Congress have actively considered legislation to reduce emissions of greenhouse gases (“GHGs”), such as carbon dioxide and methane, including proposals to: (i) establish a cap and trade system, (ii) create a federal renewable energy or “clean” energy standard requiring electric utilities to provide a certain percentage of power from such sources, and (iii) create enhanced incentives for use of renewable energy and increased efficiency in energy supply and use. In addition, the EPA is taking steps to regulate GHGs under the existing federal Clean Air Act (the “CAA”). The EPA has already adopted regulations limiting emissions of GHGs from motor vehicles, addressing the permitting of GHG emissions from stationary sources, and requiring the reporting of GHG emissions from specified large GHG emission sources, including refineries. These and similar regulations could require us to incur costs to monitor and report GHG emissions or reduce emissions of GHGs associated with our operations. In addition, various states, individually as well as in some cases on a regional basis, have taken steps to control GHG emissions, including adoption of GHG reporting requirements, cap and trade systems and renewable portfolio standards. Efforts have also been undertaken to delay, limit or prohibit EPA and possibly state action to regulate GHG emissions, and it is not possible at this time to predict the ultimate form, timing or extent of federal or state regulation. In the event we do incur increased costs as a result of increased efforts to control GHG emissions, we may not be able to pass on any of these costs to our customers. Such requirements also could adversely affect demand for the refined petroleum products that we produce. Any increased costs or reduced demand could materially and adversely affect our business and results of operation

Climate change could have a material adverse impact on our operations and adversely affect our facilities.

Some scientists have concluded that increasing concentrations of GHGs in the Earth'sEarth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts, floods and other climatic events. We believe the issue of climate change will likely continue to receive scientific and political attention, with the potential for further laws and regulations that could materially adversely affect our ongoing operations.

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In addition, as many of our facilities are located near coastal areas, rising sea levels may disrupt our ability to operate those facilities or transport crude oil and refined petroleum products. Extended periods of such disruption could have an adverse effect on our results of operation. We could also incur substantial costs to protect or repair these facilities.
Renewable fuels mandates may reduce demand for the refined fuels we produce, which could have a material adverse effect on our results of operations and financial condition. The market prices for RINs have been volatile and may harm our profitability.
Pursuant to the Energy Policy Act of 2005 and the Energy Independence and Security Act of 2007, the EPA has issued Renewable Fuel Standards, or RFS, implementing mandates to blend renewable fuels into the petroleum fuels produced and sold in the United States. Under RFS, the volume of renewable fuels that obligated refineries must blend into their finished petroleum fuels increases annually over time until 2022. In addition, certain states have passed legislation that requires minimum biodiesel blending in finished distillates. On October 13, 2010, the EPA raised the maximum amount of ethanol allowed under federal law from 10% to 15% for cars and light trucks manufactured since 2007. The maximum amount allowed under federal law currently remains at 10% ethanol for all other vehicles. Existing laws and regulations could change, and the minimum volumes of renewable fuels that must be blended with refined petroleum fuels may increase. Because we do not produce renewable fuels, increasing the volume of renewable fuels that must be blended into our products displaces an increasing volume of our refinery’s product pool, potentially resulting in lower earnings and profitability. In addition, in order to meet certain of these and future EPA requirements, we may be required to purchase renewable fuel credits, known as “RINS,”RINs, which may have fluctuating costs. We have seen a fluctuation in the cost of RINs, required for compliance with the RFS. We incurred approximately $171.6$143.9 million in RINs costs during the year ended December 31, 20152018 as compared to $115.7$293.7 million and $126.4$347.5 million during the years ended December 31, 20142017 and 2013,2016, respectively. The fluctuations in our RINs costs are due primarily to volatility in prices for ethanol-linked RINs and increases in our production of on-road transportation fuels since 2012. Our RINs purchase obligation is dependent on our actual shipment of on-road transportation fuels domestically and the amount of blending achieved which can cause variability in our profitability.
Our pipelines are subject to federal and/or state regulations, which could reduce profitability and the amount of cash we generate.
Our transportation activities are subject to regulation by multiple governmental agencies. The regulatory burden on the industry increases the cost of doing business and affects profitability. Additional proposals and proceedings that affect the oil industry are regularly considered by Congress, the states, the Federal Energy Regulatory Commission, the United States Department of Transportation, and the courts. We cannot predict when or whether any such proposals may become effective or what impact such proposals may have. Projected operating costs related to our pipelines reflect the recurring costs resulting from compliance with these regulations, and these


costs may increase due to future acquisitions, changes in regulation, changes in use, or discovery of existing but unknown compliance issues.
We are subject to strict laws and regulations regarding employee and process safety, and failure to comply with these laws and regulations could have a material adverse effect on our results of operations, financial condition and profitability.
We are subject to the requirements of the Occupational Safety & Health Administration, or OSHA, and comparable state statutes that regulate the protection of the health and safety of workers. In addition, OSHA requires that we maintain information about hazardous materials used or produced in our operations and that we provide this information to employees, state and local governmental authorities, and local residents. Failure to comply with OSHA requirements, including general industry standards, process safety standards and control of occupational exposure to regulated substances, could have a material adverse effect on our results of operations, financial condition and the cash flows of the business if we are subjected to significant fines or compliance costs.

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Compliance with and changes in tax laws could adversely affect our performance.
We are subject to extensive tax liabilities, including federal, state, local and foreign taxes such as income, excise, sales/use, payroll, franchise, property, gross receipts, withholding and ad valorem taxes. New tax laws and regulations and changes in existing tax laws and regulations are continuously being enacted or proposed that could result in increased expenditures for tax liabilities in the future. These liabilities are subject to periodic audits by the respective taxing authorities, which could increase our tax liabilities. Subsequent changes to our tax liabilities as a result of these audits may also subject us to interest and penalties. There can be no certainty that our federal, state, local or foreign taxes could be passed on to our customers.
Furthermore, the Tax Cuts and Jobs Act (“TCJA”) that was enacted on December 22, 2017 made significant permanent and temporary amendments to the Internal Revenue Code of 1986, including a reduction in corporate income taxes, elimination of the corporate minimum tax, the immediate expensing of certain capital investments, allowing for an indefinite carryforward of tax net operating losses incurred in tax years beginning after December 31, 2017 and fundamentally changing the taxation of multinational entities. Additionally, the TCJA potentially limits the amount of interest expense currently deductible, provides for a transition tax for previously unrepatriated foreign earnings, provides for current taxation of certain foreign income, a minimum tax on low-taxed foreign earnings, and new measures to deter base erosion. Certain of the amendments included in the TCJA and the regulations promulgated thereunder may adversely affect our business, result of operations and financial condition.
Changes in accounting standards issued by the FASB could have a material effect on our consolidated balance sheet, revenue and result of operations, and could require a significant expenditure of time, attention and resources, especially by senior management.
Our accounting and financial reporting policies conform to GAAP, which are periodically revised and/or expanded. The application of accounting principles is also subject to varying interpretations over time. Accordingly, we are required to adopt new or revised accounting standards or comply with revised interpretations that are issued from time to time by various parties, including accounting standard setters and those who interpret the standards, such as the FASB and the SEC and our independent registered public accounting firm. Such new financial accounting standards may result in significant changes that could adversely affect our business, financial condition, cash flow and results of operations.
Refer to “Note 2 - Summary of Significant Accounting Policies” of our Notes to Consolidated Financial Statements for further discussion of new accounting standards, including the implementation status and potential impact to our consolidated financial statements.


Changes in our credit profile could adversely affect our business.
Changes in our credit profile could affect the way crude oil suppliers view our ability to make payments and induce them to shorten the payment terms for our purchases or require us to post security or letters of credit prior to payment. Due to the large dollar amounts and volume of our crude oil and other feedstock purchases, any imposition by our suppliers of more burdensome payment terms on us may have a material adverse effect on our liquidity and our ability to make payments to our suppliers. This, in turn, could cause us to be unable to operate one or more of our refineries at full capacity.
Changes in laws or standards affecting the transportation of North American crude oil by rail could significantly impact our operations, and as a result cause our costs to increase.
Investigations into past rail accidents involving the transport of crude oil have prompted government agencies and other interested parties to call for increased regulation of the transport of crude oil by rail including in the areas of crude oil constituents, rail car design, routing of trains and other matters.The Secretary of Transportation issued an Emergency Restriction/Prohibition Order (the “Order”) that was later amended and restated on March 6, 2014 Regulation governing shipments of petroleum crude oil offered in transportation by rail. The Orderrail requires shippers to properly test and classify petroleum crude oil and further requires shippers to treat Class 3 petroleum crude oil transported by rail in tank cars as a Packing Group I or II hazardous material only. To the extent that the Order is applicable, we believe our operations already complyonly, which creates further classification and testing requirements, along with it and that the Order will not have a material impact on our cash flows. Subsequently, on May 7, 2014, themore severe penalties for violations. The DOT issued a Safety Advisory warning rail shippersadditional rules and carriers against the use of older design “111” rail cars for shipments of crude oil from the Bakken region. We do not expect this Safety Advisory will affect our operations because all of the rail cars utilized in crude oil service are the newer designed “CPC-1232” rail cars. Also on May 7, 2014, the DOT issued an order requiringregulations that require rail carriers to provide certain notifications to State agencies along routes utilized by trains over a certain length carrying crude oil. The required notifications do not affect our unloading operations. In addition, in November 2014, the DOT issued a final rule regardingoil, enhance safety training standards under the Rail Safety Improvement Act of 2008. The rule required2008, require each railroad or contractor to develop and submit a training program to perform regular oversight and annual written reviews. Recently, on May 1, 2015 the Pipelinereviews and Hazardous Materials Safety Administration and the Federal Railroad Administration issued new final rules forestablish enhanced tank car standards and operational controls for high-hazard flammable trains. While these newThese rules have just been issued and we are still evaluating the impact of these new rules, we do not believe the new rules will have a material impact on our operations or financial position and we believe we will be able to comply with the new rules without a material impact. Ifany further changes in law, regulations or industry standards occur that result in requirementsrequire us to reduce the volatile or flammable constituents in crude oil that is transported by rail, alter the design or standards for rail cars we use, change the routing or scheduling of trains carrying crude oil, or any other changes that detrimentally affect the economics of delivering North American crude oil by rail to our, or subsequently to third partythird-party, refineries, could increase our costs, could increase, which could have a material adverse effect on our financial condition, results of operations, cash flows and our ability to service our indebtedness.

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We could incur substantial costs or disruptions in our business if we cannot obtain or maintain necessary permits and authorizations or otherwise comply with health, safety, environmental and other laws and regulations.
Our operations require numerous permits and authorizations under various laws and regulations. These authorizations and permits are subject to revocation, renewal or modification and can require operational changes to limit impacts or potential impacts on the environment and/or health and safety. A violation of authorization or permit conditions or other legal or regulatory requirements could result in substantial fines, criminal sanctions, permit revocations, injunctions, and/or facility shutdowns. In addition, major modifications of our operations could require modifications to our existing permits or upgrades to our existing pollution control equipment. Any or all of these matters could have a negative effect on our business, results of operations and cash flows.
We may incur significant liability under, or costs and capital expenditures to comply with, environmental and health and safety regulations, which are complex and change frequently.
Our operations are subject to federal, state and local laws regulating, among other things, the handling of petroleum and other regulated materials, the emission and discharge of materials into the environment, waste management, and remediation of discharges of petroleum and petroleum products, characteristics and composition of gasoline and distillates and other matters otherwise relating to the protection of the environment. Our operations are also subject to extensive laws and regulations relating to occupational health and safety.
We cannot predict what additional environmental, health and safety legislation or regulations may be adopted in the future, or how existing or future laws or regulations may be administered or interpreted with respect to our operations. Many of these laws and regulations are becoming increasingly stringent, and the cost of compliance with these requirements can be expected to increase over time.


Certain environmental laws impose strict, and in certain circumstances joint and several liability for, costs of investigation and cleanup of such spills, discharges or releases on owners and operators of, as well as persons who arrange for treatment or disposal of regulated materials at contaminated sites. Under these laws, we may incur liability or be required to pay penalties for past contamination, and third parties may assert claims against us for damages allegedly arising out of any past or future contamination. The potential penalties and clean-up costs for past or future releases or spills, the failure of prior owners of our facilities to complete their clean-up obligations, the liability to third parties for damage to their property, or the need to address newly-discovered information or conditions that may require a response could be significant, and the payment of these amounts could have a material adverse effect on our business, financial condition and results of operations.
Our operating results are seasonal and generally lower in the first and fourth quarters of the year for our refining operations. We depend on favorable weather conditions in the spring and summer months.
Demand for gasoline products is generally higher during the summer months than during the winter months due to seasonal increases in highway traffic and construction work. Varying vapor pressure requirements between the summer and winter months also tighten summer gasoline supply. As a result, the operating results of our refining segment are generally lower for the first and fourth quarters of each year.
Our pending Torrance Acquisition may not close when we expect, or at all.
The consummation of the Torrance Acquisition is subject to satisfaction of customary closing conditions. If these conditions are not satisfied or waived, the acquisition will not be consummated. Additionally, as a condition of closing, the Torrance refinery is required to be restored to full working order with respect to the event that occurred on February 18, 2015 resulting in damage to the electrostatic precipitator and related systems and shall have operated as required under the acquisition agreement for a period of at least fifteen days after such restoration. The Torrance refinery’s ability to restart its FCC unit and thus return to full operation is contingent upon review and approval by the California Division of Occupational Safety and Health (“Cal/OSHA”) and the South Coast Air Quality Management District (“SCAQMD”). There is no certainty regarding the timing of the approval to restart Torrance’s FCC unit or that such approval will be granted at all by Cal/OSHA and SCAQMD, which ultimately may affect the timing and/or our ability to close the Torrance Acquisition. There can be no assurance that we will complete the Torrance Acquisition on the timeframe that we anticipate or under the terms set forth in

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the purchase agreement, or at all. Failure to complete the Torrance Acquisition or any delays in completing the acquisition could have an adverse impact on our future business and operations. In addition, we will have incurred significant acquisition-related expenses without realizing the expected benefits.
We may not be able to successfully integrate the Chalmette Refinery or the Torrance Refinery into our business, or realize the anticipated benefits of these acquisitions.
Following the completion of the Chalmette Acquisition, and if the Torrance Acquisition is completed, the integration of these businesses into our operations may be a complex and time-consuming process that may not be successful. Prior to the completion of the Chalmette Acquisition we did not have any operations in the Gulf Coast and currently do not have any operations in the West Coast, and this may add complexity to effectively overseeing, integrating and operating these refineries and related assets. Even if we successfully integrate these businesses into our operations, there can be no assurance that we will realize the anticipated benefits and operating synergies. Our estimates regarding the earnings, operating cash flow, capital expenditures and liabilities resulting from these pending acquisitions may prove to be incorrect. These acquisitions involve risks, including:

unexpected losses of key employees, customers and suppliers of the acquired operations;
challenges in managing the increased scope, geographic diversity and complexity of our operations;
diversion of management time and attention from our existing business;
liability for known or unknown environmental conditions or other contingent liabilities and greater than anticipated expenditures required for compliance with environmental, safety or other regulatory standards or for investments to improve operating results; and
the incurrence of additional indebtedness to finance acquisitions or capital expenditures relating to acquired assets.

In connection with our recently completed Chalmette Acquisition and pending Torrance Acquisition, we did not have access to the type of historical financial information that we may require regarding the prior operation of the refineries. As a result, it may be difficult for investors to evaluate the probable impact of these significant acquisitions on our financial performance until we have operated the acquired refineries for a substantial period of time.
We have entered into transition services agreements with the sellers of the Chalmette Acquisition and we may enter into transition services agreements with the sellers of our pending Torrance Acquisition. Such services may not be performed timely and effectively, and any significant disruption in such transition services or unanticipated costs related to such services could adversely affect our business and results of operations.
Risks Related to Our Indebtedness
Our substantial indebtedness could adversely affect our financial condition and prevent us from fulfilling our obligations under our indebtedness.
Our substantial indebtedness may significantly affect our financial flexibility in the future. As of December 31, 2015,2018, we have total long-term debt including the Delaware Economic Development Authority Loan and intercompany notes payable, of $1,743.0$1,290.9 million, excluding deferred debt issuance costs substantially all of which is secured,$30.5 million, and we could incur an additional $682.3$1,080.1 million of senior secured indebtedness under our existing debt agreements.credit facility. We may incur additional indebtedness in the future. Our strategy includes executing future refinery and logistics acquisitions. Any significant acquisition would likely require us to incur additional indebtedness in order to finance all or a portion of such acquisition. The level of our indebtedness has several important consequences for our future operations, including that:
a significant portion of our cash flow from operations will be dedicated to the payment of principal of, and interest on, our indebtedness and will not be available for other purposes;
under certain circumstances, covenants contained in our existing debt arrangements limit our ability to borrow additional funds, dispose of assets and make certain investments;

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in certain circumstances these covenants also require us to meet or maintain certain financial tests, which may affect our flexibility in planning for, and reacting to, changes in our industry, such as being able to take advantage of acquisition opportunities when they arise;
our ability to obtain additional financing for working capital, capital expenditures, acquisitions, general corporate and other purposes may be limited; and
we may be at a competitive disadvantage to those of our competitors that are less leveraged; and we may be more vulnerable to adverse economic and industry conditions.
Our substantial indebtedness increases the risk that we may default on our debt obligations, certain of which contain cross-default and/or cross-acceleration provisions. We have significant principal payments due under our debt instruments. Our, and our subsidiaries’, ability to meet theirfuture principal obligations will be dependent upon our future performance, which in turn will be subject to general economic conditions, industry cycles and financial, business and other factors affecting our operations, many of which are beyond our control. Our business may not continue to generate sufficient cash flow from operations to repay our substantial indebtedness. If we are unable to generate sufficient cash flow from operations, we may be required to sell assets, to refinance all or a portion of our indebtedness or to obtain additional financing. Refinancing may not be possible and additional financing may not be available on commercially acceptable terms, or at all.
Despite our level of indebtedness, we and our subsidiaries may be able to incur substantially more debt, which could exacerbate the risks described above.
We and our subsidiaries may be able to incur substantial additional indebtedness in the future including additional secured or unsecured debt. Although our debt instruments and financing arrangements contain restrictions on the incurrence of additional indebtedness, these restrictions are subject to a number of qualifications and exceptions, and the indebtedness incurred in compliance with these restrictions could be substantial. To the extent new debt is added to our currently anticipated debt levels, the substantial leverage risks described above would increase. Also, these restrictions do not prevent us from incurring obligations that do not constitute indebtedness.


Restrictive covenants in our debt instruments may limit our ability to undertake certain types of transactions.
Various covenants in our debt instruments and other financing arrangements may restrict our and our subsidiaries’ financial flexibility in a number of ways. Our indebtedness subjects us to significant financial and other restrictive covenants, including restrictions on our ability to incur additional indebtedness, place liens upon assets, pay dividends or make certain other restricted payments and investments, consummate certain asset sales or asset swaps, conduct businesses other than our current businesses, or sell, assign, transfer, lease, convey or otherwise dispose of all or substantially all of our assets. Some of these debt instruments also require our subsidiaries to satisfy or maintain certain financial condition tests in certain circumstances. Our subsidiaries’ ability to meet these financial condition tests can be affected by events beyond our control and they may not meet such tests.
Provisions in our indentures could discourage an acquisition of us by a third party.third-party.
Certain provisions of our indentures could make it more difficult or more expensive for a third partythird-party to acquire us. Upon the occurrence of certain transactions constituting a “change in control” as described in the indentures governing the Senior Secured Notes (as defined below), holders of our notes could require us to repurchase all outstanding notes at 101% of the principal amount thereof, plus accrued and unpaid interest, if any, at the date of repurchase.

Our future credit ratings could adversely affect the cost of our borrowing as well as our ability to obtain credit in the future.
37Our Senior Notes (as defined below) are rated BB by Standard & Poor’s Rating Services and B1 by Moody’s Investors Service. Any adverse effect on our credit rating may increase our cost of borrowing or hinder our ability to raise financing in the capital markets, which would impair our ability to grow our business and make cash distributions to our members.



Risks Related to Our Organizational Structure
Under a tax receivable agreement, PBF Energy is required to pay the pre-IPO owners of PBF LLC for certain realized or assumed tax benefits it may claim arising in connection with its initial public offering and future exchanges of PBF LLC Series A Units for shares of its Class A common stock and related transactions.transactions (the “Tax Receivable Agreement”). The indentureindentures governing the notes allowsSenior Notes allow us, under certain circumstances, to make distributions sufficient for PBF Energy to pay its obligations arising from the tax receivable agreement,Tax Receivable Agreement, and such amounts are expected to be substantial.
PBF Energy entered into a tax receivable agreementTax Receivable Agreement that provides for the payment from time to time (“On-Going Payments”) by PBF Energy to the holders of PBF LLC Series A Units and PBF LLC Series B Units for certain tax benefits it may claim arising in connection with its prior offerings and future exchanges of PBF LLC Series A Units for shares of its Class A Common Stock and related transactions, and the amounts it may pay could be significant.
PBF Energy’s payment obligations under the tax receivable agreementTax Receivable Agreement are PBF Energy’s obligations and not obligations of PBF Holding, PBF Finance, or any of PBF Holding’s other subsidiaries. However, because PBF Energy is primarily a holding company with limited operations of its own, its ability to make payments under the tax receivable agreementTax Receivable Agreement is dependent on our ability to make future distributions to it. The indentures governing the Senior Secured Notes allow us to make tax distributions (as defined in the indenture), and it is expected that PBF Energy’s share of these tax distributions will be in amounts sufficient to allow PBF Energy to make On-Going Payments. The indentures governing the Senior Secured Notes also allow us to make a distribution sufficient to allow PBF Energy to make any payments required under the tax receivable agreementTax Receivable Agreement upon a change in control, so long as we offer to purchase all of the Senior Secured Notes outstanding at a price in cash equal to 101% of the aggregate principal amount thereof, plus accrued and unpaid interest thereon, if any. If PBF Energy’s share of the distributions it receives under these specific provisions of the indentures is insufficient to satisfy its obligations under the tax receivable agreement,Tax Receivable Agreement, PBF Energy may cause us to make distributions in accordance with other provisions of the indentures in order to satisfy such obligations. In any case, based on our estimates of PBF Energy’s obligations


under the tax receivable agreement,Tax Receivable Agreement, the amount of our distributions on account of PBF Energy’s obligations under the tax receivable agreementTax Receivable Agreement are expected to be substantial.
For example, with respect to On-Going Payments, assuming no material changes in the relevant tax law, and that PBF Energy earns sufficient taxable income to realize all tax benefits that are subject to the tax receivable agreement,Tax Receivable Agreement, we expect that PBF Energy On-Going Payments under the tax receivable agreementTax Receivable Agreement relating to exchanges that occurred prior to that date to aggregate $661.4$373.5 million and to range over the next 5five years from approximately $37.5$15.0 million to $56.6$65.0 million per year and decline thereafter. Further On-Going Payments by PBF Energy in respect of subsequent exchanges of PBF LLC Series A Units would be in addition to these amounts and are expected to be substantial as well. With respect to the Change of Control Payment, assuming that the market value of a share of PBF Energy’s Class A common stock equals $36.81$32.67 per share of Class A common stock (the closing price on December 31, 2015)2018) and that LIBOR were to be 1.85%, we estimate as of December 31, 20152018 that the aggregate amount of these accelerated payments would have been approximately $625.4$327.7 million if triggered immediately on such date. Our existing indebtedness may limit our ability to make distributions to PBF LLC, and in turn to PBF Energy to pay these obligations. These provisions may deter a potential sale of our Companyus to a third partythird-party and may otherwise make it less likely a third partythird-party would enter into a change of control transaction with PBF Energy or us.
The foregoing numbers are merely estimates—the actual payments could differ materially. For example, it is possible that future transactions or events could increase or decrease the actual tax benefits realized and the corresponding payments. Moreover, payments under the tax receivable agreementTax Receivable Agreement will be based on the tax reporting positions that PBF Energy determines in accordance with the tax receivable agreement.Tax Receivable Agreement. Neither PBF Energy nor any of its subsidiaries will be reimbursed for any payments previously made under the tax receivable agreementTax Receivable Agreement if the Internal Revenue Service subsequently disallows part or all of the tax benefits that gave rise to such prior payments.

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Risks Related to Our Affiliation with PBFX
We depend upon PBFX for a substantial portion of our refineries’ logistics needs and have obligations for minimum volume commitments in our commercial agreements with PBFX.
We depend on PBFX to receive, handle, store and transfer crude oil, and petroleum products and natural gas for us from our operations and sources located throughout the United States and Canada in support of certain of our four refineries under long-term, fee-based commercial agreements with us. These commercial agreements have an initial term of approximately sevenranging from one to tenfifteen years and generally include minimum quarterly commitments and inflation escalators. If we fail to meet the minimum commitments during any calendar quarter, we will be required to make a shortfall payment quarterly to PBFX equal to the volume of the shortfall multiplied by the applicable fee.
PBFX’s operations are subject to all of the risks and operational hazards inherent in receiving, handling, storing and transferring crude oil, and petroleum products and natural gas, including: damages to its facilities, related equipment and surrounding properties caused by floods, fires, severe weather, explosions and other natural disasters and acts of terrorism; mechanical or structural failures at PBFX’s facilities or at third-party facilities on which its operations are dependent; curtailments of operations relative to severe seasonal weather; inadvertent damage to our facilities from construction, farm and utility equipment; and other hazards. Any of these events or factors could result in severe damage or destruction to PBFX’s assets or the temporary or permanent shut-down of PBFX’s facilities. If PBFX is unable to serve our logistics needs, our ability to operate our refineries and receive crude oil and distribute products could be adversely impacted, which could adversely affect our business, financial condition and results of operations.


All of the executive officers and a majority of the initial directors of PBF GP are also current or former officers or directors of PBF Energy. Conflicts of interest could arise as a result of this arrangement.
PBF Energy indirectly owns and controls PBF GP, and appoints all of its officers and directors. All of the executive officers and a majority of the initial directors of PBF GP are also current or former officers or a directordirectors of PBF Energy. These individuals will devote significant time to the business of PBFX. Although the directors and officers of PBF GP have a fiduciary duty to manage PBF GP in a manner that is beneficial to PBF Energy, as directors and officers of PBF GP they also have certain duties to PBFX and its unit holders.unitholders. Conflicts of interest may arise between PBF Energy and its affiliates, including PBF GP, on the one hand, and PBFX and its unit holders,unitholders, on the other hand. In resolving these conflicts of interest, PBF GP may favor its own interests and the interests of PBFX over the interests of PBF Energy and its subsidiaries. In certain circumstances, PBF GP may refer any conflicts of interest or potential conflicts of interest between PBFX, on the one hand, and PBF Energy, on the other hand, to its conflicts committee (which must consist entirely of independent directors) for resolution, which conflicts committee must act in the best interests of the public unit holdersunitholders of PBFX. As a result, PBF GP may manage the business of PBFX in a way that may differ from the best interests of PBF Energy or us.its stockholders.

ITEM 1B. UNRESOLVED STAFF COMMENTS
None.

ITEM 2. PROPERTIES
See “Item 1. Business”.

ITEM 3. LEGAL PROCEEDINGS
The Delaware City Rail Terminal and DCR West Rack are collocated with the Delaware City refinery, and are located in Delaware's coastal zone where certain activities are regulated under the Delaware Coastal Zone act. On June 14, 2013, two administrative appeals were filed by the Sierra Club and Delaware Audubon (collectively the “Appellants”) regarding an air permit Delaware City Refining Company LLC (“Delaware City Refining” or “DCR”) obtained to allow loading of crude oil onto barges. The appeals allege that both the loading of crude oil onto barges and the operation of the Delaware City Rail Terminal violate Delaware’s Coastal Zone Act. The first appeal is Number 2013-1 before the State Coastal Zone Industrial Control Board (the “CZ Board”), and the second appeal is before the Environmental Appeals Board (the “EAB”) and appeals Secretary’s Order No. 2013-A-0020.

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The CZ Board held a hearing on the first appeal on July 16, 2013, and ruled in favor of Delaware City Refining and the State of Delaware and dismissed the Appellants’ appeal for lack of standing. The Appellants appealed that decision to the Delaware Superior Court, New Castle County, Case No. N13A-09-001 ALR, and Delaware City Refining and the State of Delaware filed cross-appeals. A hearing on the second appeal before the EAB, case no. 2013-06, was held on January 13, 2014, and the EAB ruled in favor of DCR and the State and dismissed the appeal for lack of jurisdiction. The Appellants also filed a Notice of Appeal with the Superior Court appealing the EAB’s decision. On March 31, 2015 the Superior Court affirmed the decisions by both the CZ Board and the EAB stating they both lacked jurisdiction to rule on the Appellants' appeal. The Appellants appealed to the Delaware Supreme Court, and, on November 5, 2015, the Delaware Supreme Court affirmed the Superior Court decision.
On July 24, 2013, the Delaware Department of Natural Resources and Environmental Control (“DNREC”)DNREC issued a Notice of Administrative Penalty Assessment and Secretary’s Order to Delaware City Refining for alleged air emission violations that occurred during the re-start of the refinery in 2011 and subsequent to the re-start. The penalty assessment seeks $460,200 in penalties and $69,030 in cost recovery for DNREC’s expenses associated with investigation of the incidents. We dispute the amount of the penalty assessment and allegations made in the order, and are in discussions with DNREC to resolve the assessment.this assessment in addition to other NOV that have occurred since July 24, 2013 and associated Title V Permit deviations. It is possible that DNREC will assess a penaltypenalties in this matterrelation to these matters but any such amount is not expected to be material to us.
At the company.
As of November 1, 2015,time we acquired the Company acquired Chalmette Refining, whichrefinery it was in discussions withsubject to 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.Order issued by 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 includeto negotiate the resolution of deviations outsideon or before December 31, 2014. On May 18, 2018 the periods coveredOrder
was settled by LDEQ and the Order. It is possible that LDEQ will assessChalmette refinery for an administrative penalty of $741,000, of which $100,000 has been paid in cash and the remainder has been spent on beneficial environmental projects.
On April 7, 2015, DNREC issued a NOV (W-15-SWD-01) alleging violations of the Delaware City refinery’s NPDES discharge permit during the period between December 12, 2014 through January 4, 2015. On March 5, 2018, a settlement agreement was finalized resolving the alleged violations contained in the April 7, 2015 Notice of Violation, as well as additional alleged violations occurring during the period between January 2014 through January 2018. Pursuant to this settlement agreement, the Delaware City refinery was either going to pay a penalty of $30,000 and fund an approved Environmental Improvement Project (“EIP”) in the amount of $88,000, or pay a penalty in the amount of $118,000. A cost recovery payment of $7,433 will be assessed in either case. The Delaware City refinery has elected to pay the $30,000 penalty and fund the EIP in the amount of $88,000. The Delaware City refinery has paid the penalty and the cost recovery payment and will fund the approved EIP as soon
as the project scope is finalized.


The Delaware City refinery appealed a Notice of Penalty Assessment and Secretary’s Order issued in March 2017, including a $150,000 fine, alleging violation of a 2013 Secretary’s Order authorizing crude oil shipment by barge. 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 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, the Delaware City refinery appealed the Notice of Penalty Assessment and Secretary’s Order. On March 5, 2018, Notice of Penalty Assessment was settled by DNREC, the Delaware Attorney General and Delaware City refinery for $100,000. The Delaware City refinery made no admissions with respect to the alleged violations and agreed to request a Coastal Zone Act status decision prior to making crude oil shipments to destinations other than Paulsboro. The Delaware City refinery has paid the penalty. The Coastal Zone Act status decision request was submitted to DNREC and the outstanding appeal was withdrawn as required under the settlement agreement.

On December 28, 2016, DNREC issued 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 Board held a public hearing and dismissed the appeal, determining that the appellants did not have standing. The appellants filed an appeal of the Coastal Zone Board’s decision with the Superior Court on March 30, 2017. On January 19, 2018, the Superior Court rendered an Opinion regarding the decision of the Coastal Zone Board to dismiss the appeal of the Ethanol Permit for the ethanol project. The judge determined that the record created by the Coastal Zone Board was insufficient for the Superior Court to make a decision, and therefore remanded the case back to the Coastal Zone Board to address the deficiency in the record. Specifically, the Superior Court directed the Coastal Zone Board to address any evidence concerning whether the appellants’ claimed injuries would be affected by the increased quantity of ethanol shipments. On remand, the Coastal Zone Board met on January 28, 2019 and reversed its previous decision on standing, ruling that the appellants have standing to appeal the issuance of the Ethanol Permit. DCR is currently evaluating its appeal options.
At the time we acquired the Toledo refinery, EPA had initiated an investigation into the compliance of the refinery with EPA standards governing flaring pursuant to Section 114 of the Clean Air Act. On February 1, 2013, EPA issued an Amended NOV, and on September 20, 2013, EPA issued a NOV and Finding of Violation to Toledo refinery, alleging certain violations of the Clean Air Act at its Plant 4 and Plant 9 flares since the acquisition of the refinery on March 1, 2011. Toledo refinery and EPA subsequently entered into tolling agreements pending settlement discussions. Although the resolution has not been finalized, the civil administrative penalty is anticipated to be approximately $645,000, including supplemental environmental projects. To the extent the administrative penalty exceeds such amount, it is not expected to be material to us.
In connection with the acquisition of the Torrance refinery and related logistics assets, we assumed certain pre-existing environmental liabilities related to certain environmental remediation obligations to address existing soil and groundwater contamination and monitoring activities, which reflect the estimated cost of the remediation obligations. In addition, in connection with the acquisition of the Torrance refinery and related logistics assets, we purchased a ten year, $100.0 million environmental insurance policy to insure against Chalmette Refining,unknown environmental liabilities. Furthermore, in connection with the acquisition, we assumed responsibility for certain specified environmental matters that occurred prior to our ownership of the refinery and logistics assets, including specified incidents and/or NOVs issued by regulatory agencies in various years before our ownership, including the SCAQMD and Cal/OSHA. In connection with the acquisition of the Torrance refinery and related logistics assets, we agreed to take responsibility for NOV No. P63405 that ExxonMobil had received from the SCAQMD for Title V deviations that are alleged to have occurred in 2015. On August 14, 2018, we received a letter from SCAQMD offering to settle this NOV for $515,250. We are currently in communication with SCAQMD to resolve this NOV.


Subsequent to the acquisition, further NOVs were issued by the SCAQMD, Cal/OSHA, the City of Torrance, the City of Torrance Fire Department, and the Los Angeles County Sanitation District related to alleged operational violations, emission discharges and/or flaring incidents at the refinery and the logistics assets both before and after our acquisition. EPA in November 2016 conducted a RMP inspection following the acquisition related to Torrance operations and issued preliminary findings in March 2017 concerning RMP potential operational violations. The Company is currently in communication with EPA to resolve the RMP preliminary findings. EPA and DTSC in December 2016 conducted a RCRA inspection following the acquisition related to Torrance operations and also issued in March 2017 preliminary findings concerning RCRA potential operational violations. In April 2017, EPA referred the RCRA preliminary findings to DTSC for final resolution. On March 1, 2018, we received a notice of intent to sue from Environmental Integrity Project, on behalf of Environment California, under RCRA with respect to the alleged RCRA violations from December 2016 EPA’s and DTSC’s inspection. On March 2, 2018, DTSC issued an order to correct alleged RCRA violations relating to the accumulation of oil bearing materials in roll off bins during 2016 and 2017. On June 14, 2018, the Torrance refinery and DTSC reached settlement regarding the oil bearing materials in the form of a stipulation and order, wherein the Torrance refinery agreed that it would recycle or properly dispose of the oil bearing materials by the end of 2018 and pay an administrative penalty of $150,000. The Torrance refinery has complied with these requirements. Following this settlement, in June 2018, DTSC referred the remaining alleged RCRA violations from EPA’s and DTSC’s December 2016 inspection to the California Attorney General for final resolution. The Torrance refinery and the California Attorney General are in discussions to resolve these alleged remaining RCRA violations. Other than the $150,000 DTSC administrative penalty, no other settlement or penalty demands have been received to date with respect to any of the other NOVs, preliminary findings, or order that are in excess of $100,000. As the ultimate outcomes are uncertain, we cannot currently estimate the final amount or timing of their resolution but any such amount is not expected to behave a material impact on our financial position, results of operations or cash flows, individually or in the aggregate.
On September 2, 2011, prior to our ownership of the Chalmette refinery, the plaintiff in Vincent Caruso, et al. v. Chalmette Refining, L.L.C., filed an action on behalf of himself and potentially several thousand other Louisiana residents who live or own property in St. Bernard Parish and Orleans Parish and whose property was allegedly contaminated and who allegedly suffered any property damages and clean-up costs as a result of an emission of spent catalyst from the Chalmette refinery on September 6, 2010. Plaintiffs claim to have suffered injuries, symptoms, and property damage as a result of the release, although the trial court has limited recovery to property damages and clean-up expenses. Plaintiffs seek to recover unspecified damages, interest and costs. In 2016, there was a mini-trial for four plaintiffs for property damage relating to home and vehicle cleaning and the trial court rendered judgment awarding damages related to the Company.cost for home cleaning and vehicle cleaning to the four plaintiffs. The trial court found Chalmette Refining and co-defendant Eaton Corporation (“Eaton”), to be solidarily liable for the damages. Chalmette Refining and Eaton filed an appeal in August 2016 of the judgment on the mini-trial and on June 28, 2017, the appellate court unanimously reversed the judgment awarding damages to the plaintiffs, and plaintiffs request for rehearing was later denied. The parties reached a comprehensive settlement of this matter on December 3, 2018, which received final court approval on January 17, 2019. We presently believe this matter will not have a material impact on our financial position, results of operations or cash flows.
On December 5, 1990, prior to our ownership of the Chalmette refinery, the plaintiff in Adam Thomas, et al. v. Exxon Mobil Corporation and Chalmette Refining, L.L.C., filed an action on behalf of himself and potentially thousands of other individuals in St. Bernard Parish and Orleans Parish who were allegedly exposed to hydrogen sulfide and sulfur dioxide as a result of more than 100 separate flaring events that occurred between 1989 and 2007. This litigation is proceeding as a mass action with individually named plaintiffs as a result of a 2008 trial court decision, affirmed by the court of appeals, that denied class certification. The plaintiffs claim to have suffered physical injuries, property damage, and other damages as a result of the releases. Plaintiffs seek to recover unspecified compensatory and punitive damages, interest, and costs. Although no trial date has been set by the state trial court, the parties are preparing for a mini-trial of up to 10 plaintiffs, relating to 5 separate flaring events that occurred between 2002 and 2007. Because of the number of potential claimants is unknown and the differing events underlying the claims, the potential amount of the claims is not determinable. It is possible that an adverse outcome may have a material adverse effect on our financial position, results of operations, or cash flows.


On February 17, 2017, in Arnold Goldstein, et al. v. Exxon Mobil Corporation, et al., we and PBF Energy Company LLC, and our subsidiaries, PBF Energy Western Region LLC and Torrance Refining Company LLC and the manager of our 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 ExxonMobil. The operation of the Torrance refinery by the PBF entities subsequent to our acquisition in July 2016 is also referenced in the complaint. 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. On July 2, 2018, the Court granted leave to plaintiffs’ to file a Second Amended Complaint alleging groundwater contamination. With the filing of the Second Amended Complaint, Plaintiffs’ added an additional plaintiff. As this matter is in the class certification phase, we cannot currently estimate the amount or the timing of its resolution. We presently believe the outcome will not have a material impact on our financial position, results of operations or cash flows.
On September 18, 2018, in Michelle Kendig and Jim Kendig, et al. v. ExxonMobil Oil Corporation, et al., PBF Energy Limited and Torrance Refining Company LLC along with ExxonMobil Oil Corporation and ExxonMobil Pipeline Company were named as defendants in a class action and representative action complaint filed on behalf of Michelle Kendig, Jim Kendig and others similarly situated. The complaint was filed in the Superior Court of the State of California, County of Los Angeles and alleges failure to authorize and permit uninterrupted rest and meal periods, failure to furnish accurate wage statements, violation of the Private Attorneys General Act and violation of the California Unfair Business and Competition Law. Plaintiffs seek to recover unspecified economic damages, statutory damages, civil penalties provided by statute, disgorgement of profits, injunctive relief, declaratory relief, interest, attorney’s fees and costs. To the extent that plaintiffs’ claims accrued prior to July 1, 2016, ExxonMobil has retained responsibility for any liabilities that would arise from the lawsuit pursuant to the agreement relating to the acquisition of the Torrance refinery and logistics assets. On October 26, 2018, the matter was removed to the Federal Court, California Central District. As this matter is in the class certification phase, we cannot currently estimate the amount or the timing of its resolution. We presently believe the outcome will not have a material impact on our financial position, results of operations or cash flows.
On September 7, 2018, in Jeprece Roussell, et al. v. PBF Consultants, LLC, etal., the Plaintiff filed an action in the 19th Judicial District Court for the Parish of East Baton Rouge, alleges numerous causes of action, including wrongful death, premises liability, negligence, and gross negligence against PBF Holding Company LLC, PBFX Operating Company LLC, Chalmette Refining, L.L.C., two individual employees of the Chalmette Refinery (“the PBF Defendants”), two entities, PBF Consultants, LLC and PBF Investments, LLC that are Louisiana companies that are not associated with our companies, as well as Clean Harbors, Inc. and Clean Harbors Environmental Services, Inc. (collectively, “Clean Harbors”), Mr. Roussell’s employer. Mr. Roussell was fatally injured on March 31, 2018 while performing clay removal work activities inside a clay treating vessel located at the Chalmette Refinery. Plaintiff seeks unspecified compensatory damages for pain and suffering, past and future mental anguish, impairment, past and future economic loss, attorney’s fees and court costs. The PBF Defendants have issued a tender of defense and indemnity to Clean Harbors and its insurer pursuant to indemnity obligations contained in the associated services agreement. On September 25, 2018, the PBF Defendants filed an Answer in the state court action denying the allegations. On October 10, 2018, the PBF Defendants filed to remove the case to the United States District Court for the Middle District of Louisiana. On November 9, 2018, Plaintiff filed a motion to remand the matter back to state court and the PBF Defendants filed a response on November 30, 2018. On December 21, 2018, Plaintiff filed a motion for leave to file a reply memorandum and the reply memorandum was filed December 27, 2018. As this matter was recently filed, we cannot currently estimate the amount or the timing of its resolution. We presently believe the outcome will not have a material impact on our financial position, results of operations or cash flows.


We are subject to obligations to purchase RINs. On February 15, 2017, we received notification that EPA records indicated that PBF Holding used potentially invalid RINs that were in fact verified under EPA’s RIN Quality Assurance Program (“QAP”) by an independent auditor as QAP A RINs. Under the regulations use of potentially invalid QAP A RINs provided the user with an affirmative defense from civil penalties provided certain conditions are met. We have asserted the affirmative defense and if accepted by EPA will not be required to replace these RINs and will not be subject to civil penalties under the program. It is reasonably possible that EPA will not accept our defense and may assess penalties in these matters but any such amount is not expected to have a material impact on our financial position, results of operations or cash flows.
CERCLA, also known as “Superfund,” imposes liability, without regard to fault or the legality of the original conduct, on certain classes of persons who are considered to be responsible for the release of a “hazardous substance” into the environment. These persons include the current or former owner or operator of the disposal site or sites where the release occurred and companies that disposed of or arranged for the disposal of the hazardous substances. Under CERCLA, such persons may be subject to joint and several liability for investigation and the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. As discussed more fully above, certain of our sites are subject to these laws and we may be held liable for investigation and remediation costs or claims for natural resource damages. It is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the environment. Analogous state laws impose similar responsibilities and liabilities on responsible parties. In our current normal operations, we have generated waste, some of which falls within the statutory definition of a “hazardous substance” and some of which may have been disposed of at sites that may require cleanup under Superfund.

ITEM 4. MINE SAFETY DISCLOSURE
None.


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PART II

ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS, AND ISSUER PURCHASES OF EQUITY SECURITIES
Market Information
We are a privately-owned company with no established public trading market for our membership units.
Holders
At December 31, 2015,2018, 100% of our outstanding membership interests waswere held by PBF LLC. PBF Finance had 100 shares of common stock outstanding, all of which were held by us. None of the membership interests are publicly traded,publicly-traded, and none were issued or sold in 2015.2018.
Dividend and Distribution Policy
We made cash distributions to PBF LLC in the amount of $350.7$52.6 million during 2015,2018. PBF LLC used $141.3 million, which in turn madeincluded $39.5 million distributed by us, to make cash distributions (including tax distributions) of an equivalent amount to its members including PBF Energy.
We currently intend to make quarterly cash distributions in amounts sufficient for PBF LLC to make tax distributions to its members and may make additional distributions to the extent necessary for PBF Energy to declare and pay a quarterly cash dividend of approximately $0.30 per share on its Class A common stock. The declaration, amount and payment of this and any other future distributions by us will be at the sole discretion of our board of directors and the board of directors of PBF Energy, which is the sole managing member of our sole member (PBF LLC), and we are not obligated under any applicable laws, governing documents or any contractual agreements with PBF LLC'sLLC’s existing owners or otherwise to declare or pay any dividends or other distributions (other than the obligations of PBF LLC to make tax distributions to its members).
We are a holding company and all of our operations are conducted through our subsidiaries. We have no independent means of generating revenue other than through assets owned by our subsidiaries. In order for us to make any distributions, we will need to cause our subsidiaries to make distributions to us. We and our subsidiaries are generally prohibited under Delaware law from making a distribution to a member to the extent that, at the time of the distribution, after giving effect to the distribution, liabilities of the limited liability company (with certain exceptions) exceed the fair value of its assets. As a result, we may be unable to obtain cash from our subsidiaries to satisfy our obligations and make distributions to PBF LLC.
Our ability to pay dividends and make distributions to PBF LLC is, and in the future may be, limited by covenants in our asset based revolving credit agreement (the “Revolving Loan”),Revolving Credit Facility, our Senior Secured Notes and other debt instruments. Subject to certain exceptions, the Revolving LoanCredit Facility and the indentures governing the Senior Secured Notes prohibit us from making distributions to PBF LLC if certain defaults exist. In addition, both the indentures and the Revolving LoanCredit Facility contain additional restrictions limiting our ability to make distributions to PBF LLC.
Based upon our operating results for the year ended December 31, 2015,2018, we were permitted, under our Revolving Loan,Credit Facility, Senior Secured Notes and other debt instruments, to make distributions to PBF LLC so that PBF LLC could make tax distributions to its members and make quarterly distributions to its members in an amount sufficient for PBF Energy to declare and pay a quarterly dividend of $0.30 per share on its Class A common stock. Our ability to comply with the foregoing limitations and restrictions is, to a significant degree, subject to our operating results, which are dependent on a number of factors outside of our control. As a result, we cannot assure you that we will be able to continue to make distributions. See “Item 1A. Risk Factors”.
PBF Holding

We paid $350.7$52.6 million in distributions to PBF LLC during the year ended December 31, 2015.2018. PBF LLC used $112.8$39.5 million of this amount in total to makefund a portion of four separate non-tax distributions of $0.30 per unit ($1.20 per unit in total) to its members totaling $141.3 million, of which $106.6$139.3 million was distributed to PBF Energy and the balance was distributed to PBF LLC’s other members. PBF Energy used this $106.6$139.3 million to pay four separate equivalent

41



cash dividends of $0.30 per share of its Class A common stock on March 14, 2018, May 30, 2018, August 30, 2018 and November 25, 2015, August 10, 2015, May 27, 2015, and March 10, 2015. PBF LLC used the remaining $237.9 million from PBF Holding’s distribution to make tax distributions to its members, including $224.7 million to PBF Energy.30, 2018.

ITEM 6. SELECTED FINANCIAL DATA
The following table presents selected historical consolidated financial and other data of PBF Holding. The selected historical consolidated financial data for each of the fiscal years ended as of December 31, 2015, 2014,2018 and 2013, respectively,2017 and for each of the three years in the period ended December 31, 2018, have been derived from our audited consolidated financial statements.statements, included in this Annual Report on Form 10-K. The selected historical consolidated financial data as of December 31, 2016, 2015 and 2014 and for the years ended as of December 31, 20122015 and 20112014 have been derived from the audited financial statements of PBF Holding not included in this Annual Report on Form 10-K. As a result of the ToledoChalmette and ChalmetteTorrance acquisitions, the historical consolidated financial results of PBF Holding only include the results of operations for Toledothe Chalmette and ChalmetteTorrance refineries from March 1, 2011 and November 1, 2015 and July 1, 2016 forward, respectively.
The historical consolidated financial data and other statistical data presented below should be read in conjunction with “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.”Operations” and our consolidated financial statements and the related notes thereto, included in “Item 8. Financial Statements and Supplementary Data.”this Annual Report on Form 10-K.

42The consolidated financial information may not be indicative of our future financial condition, results of operations or cash flows.




The following tables reflect our financial and operating highlights (amounts in thousands) for the years ended December 31, 2018, 2017, 2016, 2015 2014, 2013, 2012 and 2011.2014.
  Year Ended December 31,
  2015 2014 2013 2012 2011
Statement of operations data:          
Revenues $13,123,929
 $19,828,155
 $19,151,455
 $20,138,687
 $14,960,338
Costs and expenses:          
Cost of sales, excluding depreciation 11,611,599
 18,514,054
 17,803,314
 18,269,078
 13,855,163
Operating expenses, excluding depreciation 889,368
 880,701
 812,652
 738,824
 658,831
General and administrative expenses (1)
 166,904
 140,150
 95,794
 120,443
 86,911
Gain on sale of asset (1,004) (895) (183) (2,329) 
Depreciation and amortization expense 191,110
 178,996
 111,479
 92,238
 53,743
Income (loss) from operations 265,952
 115,149
 328,399
 920,433
 305,690
Other (expense) income:          
Change in fair value of contingent consideration 
 
 
 (2,768) (5,215)
Change in fair value of catalyst lease obligation 10,184
 3,969
 4,691
 (3,724) 7,316
Interest (expense), net (88,194) (98,001) (94,214) (108,629) (65,120)
Income before income taxes 187,942
 21,117
 238,876
 805,312
 242,671
Income taxes 648
 
 
 
 
Net Income 187,294
 21,117
 238,876
 805,312
 242,671
Less income attributable to noncontrolling interest 274
 
 
 
 
Net income attributable to PBF Holding LLC 187,020
 21,117
 238,876
 805,312
 242,671
           
Balance sheet data (at end of period) :          
Total assets $5,082,722
 $4,013,762
 $4,192,504
 $4,085,264
 $3,607,129
Total long-term debt (2)
 1,272,937
 750,349
 747,576
 729,980
 804,865
Total equity 1,821,284
 1,630,516
 1,772,153
 1,751,654
 1,110,918
Other financial data :          
Capital expenditures (3)
 $414,177
 $625,403
 $415,702
 $222,688
 $574,883
  Year Ended December 31,
  2018 2017 2016 2015 2014
Revenues $27,164,008
 $21,772,478
 $15,908,537
 $13,123,929
 $19,828,155
Cost and expenses:          
Cost of products and other 24,744,619
 19,095,827
 13,765,088
 11,611,599
 18,514,054
Operating expenses (excluding depreciation and amortization expense as reflected below) (1)
 1,654,749
 1,626,440
 1,390,135
 887,651
 878,607
Depreciation and amortization expense 329,709
 254,271
 204,005
 181,422
 165,413
Cost of sales 26,729,077
 20,976,538
 15,359,228
 12,680,672
 19,558,074
General and administrative expenses (excluding depreciation and amortization expense as reflected below) (1) (2)
 253,834
 197,938
 149,510
 166,904
 140,150
Depreciation and amortization expense 10,634
 12,964
 5,835
 9,688
 13,583
Equity income in investee (17,819) (14,565) (5,679) 
 
(Gain) loss on sale of asset (43,094) 1,458
 11,374
 (1,004) (895)
Total cost and expenses 26,932,632
 21,174,333
 15,520,268
 12,856,260
 19,710,912
           
Income from operations 231,376
 598,145
 388,269
 267,669
 117,243
           
Other income (expense):          
Change in fair value of catalyst leases 5,587
 (2,247) 1,422
 10,184
 3,969
Debt extinguishment costs 
 (25,451) 
 
 
Interest expense, net (127,129) (122,628) (129,536) (88,194) (98,001)
Other non-service components of net periodic benefit cost (1)
 1,109
 (1,402) (580) (1,717) (2,094)
Income before income taxes 110,943
 446,417
 259,575
 187,942
 21,117
Income tax expense (benefit) 7,999
 (10,783) 23,689
 648
 
Net Income 102,944
 457,200
 235,886
 187,294
 21,117
Less: net income attributable to noncontrolling interest 44
 95
 269
 274
 
Net income attributable to PBF Holding Company LLC $102,900
 $457,105
 $235,617
 $187,020
 $21,117
           
Balance sheet data (at end of period) :          
Total assets $7,213,476
 $7,506,178
 $6,566,897
 $5,082,722
 $4,013,762
Total debt (3)
 1,290,907
 1,668,035
 1,601,836
 1,272,937
 750,349
Total equity 3,529,707
 3,184,102
 2,588,933
 1,821,284
 1,630,516
Other financial data :          
Capital expenditures (4)
 $560,341
 $642,913
 $1,498,191
 $979,481
 $625,403
 
(1)Amounts disclosed include the retrospective adjustments recorded as part of the adoption of ASU 2017-07, “Compensation—Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost”. As part of the adoption of this ASU in 2018, other non-service components of the net periodic benefit cost are disclosed separately outside of income from operations with retrospective adjustments made to the amounts previously recorded within Operating expenses and General and administrative expenses for all periods presented. Refer to “Note 2 - Summary of Significant Accounting Policies” of our Notes to Consolidated Financial Statements for further details.


(2)Includes acquisition related expenses consisting primarily of consulting and legal expenses related to the Chalmette Acquisitioncompleted and other pending Torrance Acquisition of $5.8 million in 2015 as well as the Paulsboro and Toledo acquisitions and non-consummated acquisitions of $0.7$0.5 million, $13.6 million and $5.8 million in 2011.
(2)Total long-term debt, excluding debt issuance costs2017, 2016 and intercompany notes payable, includes current maturities and our Delaware Economic Development Authority Loan.2015, respectively. There were no acquisition related expenses during 2018.
(3)Total debt, excluding debt issuance costs, includes current maturities, our Note payable and our Delaware Economic Development Authority Loan (which was fully converted to a grant as of December 31, 2016).
(4)Includes expenditures for acquisitions, construction in progress, property, plant and equipment (including railcar purchases), deferred turnaround costs and other assets, excluding the proceeds from sales of assets.




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ITEM 7. MANAGEMENT'SMANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following review of our results of operations and financial condition should be read in conjunction with Items 1, 1A, and 2, “Business,“Item 1. Business”, “Item 1A. Risk Factors, and Properties,” Item 6, “SelectedFactors”, “Item 2. Properties”, “Item 6. Selected Financial Data,” and Item 8, “Financial“Item 8. Financial Statements and Supplementary Data,” respectively, included in this Annual Report on Form 10-K.
CAUTIONARY STATEMENT FOR THE PURPOSE OF SAFE HARBOR PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995REGARDING FORWARD-LOOKING STATEMENTS
This Annual Report on Form 10-K contains certain “forward-looking statements”, as defined in the Private Securities Litigation Reform Act of 1995, of expected future developments that involve riskrisks and uncertainties. You can identify forward-looking statements because they contain words such as “believes,” “expects,” “may,” “should,” “seeks,” “approximately,” “intends,” “plans,” “estimates,” or “anticipates” or similar expressions that relate to our strategy, plans or intentions. All statements we make relating to our estimated and projected earnings, margins, costs, expenditures, cash flows, growth rates and financial results or to our strategies, objectives, intentions, resources and expectations regarding future industry trends are forward-looking statements. In addition, we, through our senior management, from time to time make forward-looking public statements concerning our expected future operations and performance and other developments. These forward-looking statements are subject to risks and uncertainties that may change at any time, and, therefore, our actual results may differ materially from those that we expected. We derive many of our forward-looking statements from our operating budgets and forecasts, which are based upon many detailed assumptions. While we believe that our assumptions are reasonable, we caution that it is very difficult to predict the impact of known factors, and, of course, it is impossible for us to anticipate all factors that could affect our actual results.
Important factors that could cause actual results to differ materially from our expectations, which we refer to as “cautionary statements,” are disclosed under “Item 1A. Risk Factors,” and “Item 7. Management'sManagement’s Discussion and Analysis of Financial Condition and Results of Operations” and elsewhere in this Annual Report on Form 10-K. All forward-looking information in this Annual Report on Form 10-K and subsequent written and oral forward-looking statements attributable to us, or persons acting on our behalf, are expressly qualified in their entirety by the cautionary statements. Some of the factors that we believe could affect our results include:
supply, demand, prices and other market conditions for our products, including volatility in commodity prices;
the effects of competition in our markets;
changes in currency exchange rates, interest rates and capital costs;
adverse developments in our relationship with both our key employees and unionized employees;
our ability to operate our businesses efficiently, manage capital expenditures and costs (including general and administrative expenses) and generate earnings and cash flow;
our substantial indebtedness;
our expectations and timing with respect to our acquisition activity;
our expectations with respect to our capital improvement and turnaround projects;
our supply and inventory intermediation arrangements expose us to counterparty credit and performance risk;


termination of our A&RInventory Intermediation Agreements with J. Aron, which could have a material adverse effect on our liquidity, as we would be required to finance our intermediate and refined products inventory covered by the agreements. Additionally, we are obligated to repurchase from J. Aron certain intermediates and finished products located at the Paulsboro and Delaware City refineries’ storage tanks upon termination of these agreements;
restrictive covenants in our indebtedness that may adversely affect our operational flexibility or ability to make distributions;
our assumptions regarding payments arising under PBF Energy's tax receivable agreementEnergy’s Tax Receivable Agreement and other arrangements relating to PBF Energy;
our expectations and timing with respect to our acquisition activity;
our expectations with respect to our capital improvement and turnaround projects;
the status of an air permit to transfer crude through the Delaware City refinery's dock;
the impact of disruptions to crude or feedstock supply to any of our refineries, including disruptions due to problems at PBFX or with third partythird-party logistics infrastructure or operations, including pipeline, marine and rail transportation;

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the impact of current and future laws, rulings and governmental regulations, including the implementation of rules and regulations regarding transportation of crude oil by rail;
the impact of the newly enacted federal income tax legislation on our business;
the effectiveness of our crude oil sourcing strategies, including our crude by rail strategy and related commitments;
adverse impactsimpact related to recent legislationregulation by the federal government lifting the restrictions on exporting U.S. crude oil;
adverse impacts from changes in our regulatory environment, such as the effects of compliance with the California Global Warming Solutions Act (also referred to as “AB32”), or from actions taken by environmental interest groups;
market risks related to the volatility in the price of Renewable Identification Numbers (“RINS”)RINs required to comply with the Renewable Fuel Standards;
adverse impacts from changes in our regulatory environment or actions taken by environmental interest groups;Standards and GHG emission credits required to comply with various GHG emission programs, such as AB32;
our ability to consummate the pending acquisition of the ownership interests of the Torrance refinery and related logistics assets, the timing for the closing of such acquisition and our plans for financing such acquisition;
our ability to complete the successful integration of thesuccessfully integrate recently completed acquisition of Chalmette Refining, and the pending Torrance Acquisitionacquisitions into our business and to realize the benefits from such acquisitions;
liabilities arising from the Chalmette Acquisition and/or Torrance Acquisitionrecent acquisitions that are unforeseen or exceed our expectations; and
any decisions we continue to make with respect to our energy-related logistical assets that may be transferred to PBFX.
We caution you that the foregoing list of important factors may not contain all of the material factors that are important to you. In addition, in light of these risks and uncertainties, the matters referred to in the forward-looking statements contained in this Annual Report on Form 10-K may not in fact occur. Accordingly, investors should not place undue reliance on those statements.
Our forward-looking statements speak only as of the date of this Annual Report on Form 10-K. Except as required by applicable law, including the securities laws of the United States, we do not intend to update or revise any forward-looking statements. All subsequent written and oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the foregoing.
Explanatory Note
This Annual Report on Form 10-K is filed by PBF Holding and PBF Finance. PBF Finance is a wholly-owned subsidiary of PBF Holding. PBF Holding is a wholly-owned subsidiary of PBF LLC and is the parent company for PBF LLC's refinery operating subsidiaries. PBF Holding is an indirect subsidiary of PBF Energy, which is the sole managing member of, and owner of an equity interest representing approximately 95.1% of the outstanding economic interests in PBF LLC as of December 31, 2015. PBF Energy operates and controls all of the business and affairs and consolidates the financial results of PBF LLC and its subsidiaries. PBF Holding, together with its consolidated subsidiaries, owns and operates oil refineries and related facilities in North America.
Unless the context indicates otherwise, the terms “we,” “us,” and “our” refer to PBF Holding and its consolidated subsidiaries.
Executive Summary
We were formed in March 2008 to pursue the acquisitions of crude oil refineries and downstream assets in North America. We currently own and operate fourfive domestic oil refineries and related assets located in Delaware City, Delaware, Paulsboro, New Jersey, Toledo, Ohio, and New Orleans, Louisiana.Louisiana and Torrance, California. Our refineries have a combined processing capacity, known as throughput, of approximately 730,000900,000 bpd, and a weighted average Nelson Complexity Index of 11.7. The Company’s four12.2. Our five oil refineries are all engaged in the refining of crude oil and other feedstocks into petroleum products, and are aggregated into one reportable segment.
The following table summarizes our history and key events:

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March 2008PBF was formed.
June 2010The idle Delaware City refinery and its related assets were acquired from Valero.
December 2010The Paulsboro refinery and its related assets were acquired from affiliates of Valero.
March 2011The Toledo refinery and its related assets were acquired from Sunoco.
October 2011The Delaware City refinery became operational.
February 2012We issued $675.5 million aggregate principal amount of 8.25% Senior Secured Notes due 2020.
December 2012PBF Energy completed the initial public offering of its common equity. In connection with the initial public offering, PBF Energy became the sole managing member of PBF LLC.
February 2013PBFX was formed by PBF Energy to own or lease, operate, develop and acquire crude oil and refined petroleum products terminals, pipelines, storage facilities and similar logistics assets.
May 2014PBFX completed its initial public offering of 15,812,500 common units at a price to the public of $23.00 per unit.
September 2014PBF Holding distributed to PBF LLC, which in turn contributed to PBFX, all of the equity interests of DCT II for total consideration from PBFX of $150.0 million consisting of $135.0 million of cash and $15.0 million of PBFX common units, or 589,536 common units.
December 2014PBF Holding distributed to PBF LLC, which in turn contributed to PBFX, all of the issued and outstanding limited liability company interests of Toledo Terminaling, for total consideration from PBFX of $150.0 million, consisting of $135.0 million of cash and $15.0 million of Partnership common units, or 620,935 common units.
February 2015Blackstone and First Reserve sold, in a secondary offering, their remaining shares of Class A common stock of PBF Energy.
May 2015PBF Holding distributed to PBF LLC, which in turn contributed to PBFX, all the equity interests of DPC and DCLC, for total consideration from PBFX of $143.0 million, consisting of $112.5 million of cash and $30.5 million of Partnership common units, or 1,288,420 common units.
September 2015PBF Energy announced the pending Torrance Acquisition.
October 2015PBF Energy completed a public offering of 11,500,000 shares of its Class A common stock.
November 2015The Chalmette refinery and its related assets were acquired from ExxonMobil and PDV Chalmette, Inc.
November 2015PBF Holding issued $500.0 million aggregate principal amount of 7.00% Senior Secured Notes due 2023.

Factors Affecting Comparability
Our results over the past three years have been affected by the following events, the understanding of which must be understoodwill aid in order to assessassessing the comparability of our period to period financial performance and financial condition.
Chalmette Acquisition
On November 1, 2015, the Company acquired from ExxonMobil Oil Corporation, Mobil Pipe Line Company and PDV Chalmette, Inc., 100% of the ownership interests of Chalmette Refining, which owns the Chalmette refinery and related logistics assets. The Chalmette refinery, located outside of New Orleans, Louisiana, is a dual-train coking refinery and is capable of processing both light and heavy crude oil. Subsequent to the closing of the Chalmette Acquisition, Chalmette Refining is a wholly-owned subsidiary of PBF Holding.
Chalmette Refining owns 100% of the MOEM Pipeline, providing access to the Empire Terminal, as well as the CAM Connection Pipeline, providing access to the Louisiana Offshore Oil Port facility through a third party pipeline. Chalmette Refining also owns 80% of each of the Collins Pipeline Company and T&M Terminal Company, both located in Collins, Mississippi, which provide a clean products outlet for the refinery to the Plantation and Colonial Pipelines. Also included in the acquisition are a marine terminal capable of importing waterborne feedstocks and loading or unloading finished products; a clean products truck rack which provides access to local markets; and a crude and product storage facility.

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The aggregate purchase price for the Chalmette Acquisition was $322.0 million in cash, plus estimated inventory and working capital of $243.3 million, which is subject to final valuation upon agreement by both parties. The transaction was financed through a combination of cash on hand and borrowings under the Company’s existing revolving credit line.
Initial Public Offering of PBFX
PBFX is a fee-based, growth-oriented, publicly traded Delaware master limited partnership formed by PBF Energy to own or lease, operate, develop and acquire crude oil and refined petroleum products terminals, pipelines, storage facilities and similar logistics assets. PBFX engages in the receiving, handling and transferring of crude oil and the receipt, storage and delivery of crude oil, refined products and intermediates from sources located throughout the United States and Canada for PBF Holding in support of its refineries. All of PBFX’s revenue is derived from long-term, fee-based commercial agreements with PBF Holding, which include minimum volume commitments, for receiving, handling, storing and transferring crude oil and refined products. PBF Energy also has agreements with PBFX that establish fees for certain general and administrative services and operational and maintenance services provided by PBF Holding to PBFX.
PBF GP serves as the general partner of PBFX. PBF GP is wholly-owned by PBF LLC. On May 14, 2014, PBFX completed its initial public offering. In connection with the PBFX Offering, PBF Holding contributed to PBFX the assets and liabilities of certain crude oil terminaling assets. The assets were owned and operated by PBF Holding’s subsidiaries Delaware City Refining and Toledo Refining. The initial assets distributed consisted of the Delaware City Rail Unloading Terminal (“DCR Rail Terminal”), which was part of DCR, and the Toledo Truck Unloading Terminal (“Toledo Truck Terminal”), which was part of TRC. In a series of transactions in 2014 and 2015, PBF Holding distributed certain additional assets to PBF LLC, which in turn contributed those assets to PBFX. These transactions included the Delaware City heavy crude unloading rack (the “DCR West Rack”) on September 30, 2014, a tank farm and related facilities, including a propane storage and loading facility at TRC (the “Toledo Storage Facility”) on December 11, 2014 and the Delaware City Products Pipeline and Truck Rack at DCR on May 14, 2015.
Contribution Agreements
On May 8, 2014, PBFX, PBF GP, PBF Energy, PBF LLC, PBF Holding, DCR, Delaware City Terminaling and TRC entered into the Contribution Agreement I. On May 14, 2014, concurrent with the closing of the PBFX Offering, the following transactions occurred pursuant to the Contribution Agreement I:

DCR distributed allEarly Return of the interests in Delaware City Terminaling and TRC distributed the Toledo Truck Terminal, in each case, to PBF Holding at their historical cost.
PBF Holding contributed, at their historical cost, (i) all of the interests in Delaware City Terminaling and (ii) the Toledo Truck Terminal to PBFX in exchange for (a) 74,053 common units and 15,886,553 subordinated units representing an aggregate 50.2% limited partner interest in PBFX, (b) all of PBFX’s incentive distribution rights, (c) the right to receive a distribution of $30.0 million from PBFX as reimbursement for certain preformation capital expenditures attributable to the contributed assets, and (d) the right to receive a distribution of $298.7 million; and in connection with the foregoing, PBFX redeemed PBF Holding’s initial partner interests in PBFX for $1.0 thousand.
PBF Holding distributed to PBF LLC (i) its interest in PBF GP, (ii) the common units, subordinated units and incentive distribution rights, (iii) the right to receive a distribution of $30.0 million as reimbursement for certain preformation capital expenditures, and (iv) the right to receive a distribution of $298.7 million.Railcars
On September 30, 2014, PBF LLC and PBFX closed2018, we agreed to voluntarily return a portion of railcars under an operating lease in order to rationalize certain components of our railcar fleet based on prevailing market conditions in the transaction contemplatedcrude oil by the Contribution Agreement II, dated September 16, 2014. Pursuant torail market. Under the terms of the Contribution Agreement II, PBF Holding distributed to PBF LLC alllease amendment, we will pay agreed amounts in lieu of the equity interestssatisfaction of DCT II, which assets consisted solely of the DCR West Rack, immediately prior to the transfer of such equity interests by PBF LLC to PBFX. The DCR West Rack was previously ownedreturn conditions (the “Early Termination Penalty”) and operated by PBF Holding’s subsidiary, DCT II, and is located at the Company's Delaware City, Delaware refinery. PBFX paid to PBF LLC total consideration of $150.0 million, consisting of $135.0 million of cash and $15.0 million of PBFX common units, or 589,536 common units, in exchange for the DCR West Rack.
On December 11, 2014, PBF Holding and PBF LLC closed the transaction contemplated by the Contribution Agreement III, dated December 2, 2014. Pursuant to the Contribution Agreement III, PBF Holding distributed to PBF LLC all of the issued and outstanding limited liability company interests of Toledo Terminaling, whose assets consist of the Toledo Storage Facility. PBF LLC then contributed to PBFX all of the equity interests of Toledo Terminaling for total consideration to PBF LLC of $150.0 million, consisting of $135.0 million of cash and $15.0 million of PBFX common units, or 620,935 common units.

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Effective May 14, 2015, PBF LLC contributed to PBFX all of the issued and outstanding limited liability company interests of DPC and DCLC, whose assets consist of the Delaware City Products Pipeline and Truck Rack, for total consideration of $143.0, consisting of $112.5 million of cash and $30.5 million of PBFX common units, or 1,288,420 common units.
Commercial Agreements
In connection with the contribution agreements described above, PBF Holding entered into long-term, fee-based commercial agreements with PBFX. Under these agreements, PBFX provides various rail and truck terminaling services, pipeline services, and storage services to PBF Holding and PBF Holding has committed to provide PBFX with minimum fees based on minimum monthly throughput volumes and storage capacity. The fees under each of these agreements are indexed for inflation and any increase in operating costs for providing such services to PBF Holding. Prior to the PBFX Offering, the DCR Rail Terminal, Toledo Truck Terminal, the DCR West Rack and the Toledo Storage Facility were owned, operated and maintained by PBF Holding's subsidiaries. Additionally, the Delaware City Products Pipeline and Truck Rack was owned, operated and maintained by PBF Holding's subsidiaries until May 15, 2015.Therefore, PBF Holding did not previouslywill pay a reduced rental fee forover the utilization of these facilities. Below is a summary of the agreements for the use of each of the assets.
2014 Commercial Agreements
Delaware City Rail Terminaling Services Agreement
On May 14, 2014, concurrent with the closing of the PBFX Offering, PBF Holding entered into the DCR Terminaling Agreement. Under the DCR Terminaling Agreement, PBF Holding is obligated to throughput aggregate volumes of crude oil of at least 85,000 bpd per quarter (calculated on a quarterly average basis) for a terminaling service fee of $2.00 per barrel, which will decrease to $0.50 per barrel for volumes that exceed the minimum throughput commitment. PBF Holding also pays PBFX for providing related ancillary services at the terminal that are specified in the agreement. The terminaling service fee is subject to (i) increase or decrease effective as of January 1 of each year, beginning with January 1, 2015, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) an adjustment by the amount of any increases in any operating costs that increase greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the DCR Terminaling Agreement. Effective January 1, 2015, the terminaling service fee was increased to $2.032 per barrel up to the minimum throughput commitment and $0.508 per barrel for volumes that exceed the minimum throughput commitment.
Toledo Truck Unloading & Terminaling Agreement
On May 14, 2014, concurrent with the closing of the PBFX Offering, PBF Holding entered into the Toledo Terminaling Agreement as amended. Under the Toledo Terminaling Agreement, PBF Holding is obligated to throughput aggregate volumes of crude oil of at least 4,000 bpd (calculated on a quarterly average basis) for a terminaling service fee of $1.00 per barrel. The Toledo Terminaling Agreement was amended and restated effective as of June 1, 2014, to among other things, increase the minimum throughput volume commitment from 4,000 bpd to 5,500 bpd beginning August 1, 2014. PBF Holding also pays PBFX for providing related ancillary services at the terminal which are specified in the Toledo Terminaling Agreement. The terminaling service fee is subject to (i) increase or decrease effective as of January 1 of each year, beginning on January 1, 2015, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) adjustment by the amount of any increase in operating costs greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the Toledo Terminaling Agreement. Effective January 1, 2015, the terminaling service fee was increased to $1.016 per barrel.
Delaware City West Ladder Rack Terminaling Services Agreement
On October 1, 2014, PBF Holding and DCT II entered into the West Ladder Rack Terminaling Agreement under which PBFX, through DCT II, provides rail terminaling services to PBF Holding. DCT II was merged with and into Delaware City Terminaling, a wholly-owned subsidiary of PBFX, with all property, rights, liabilities and obligations of DCT II vesting in Delaware City Terminaling as the surviving company. The agreement may be extended by PBF Holding for two additional five year periods. Under the West Ladder Rack Terminaling Agreement, PBF Holding is obligated to throughput aggregate volumes of crude oil of at least 40,000 bpd for a terminaling service fee equal to $2.20 per barrel for all volumes of crude oil throughput up to the minimum throughput commitment and $1.50 per barrel for all volumes of crude oil throughput in excess of the minimum throughput commitment, in any contract quarter. PBF Holding also pays PBFX for providing related ancillary services at the terminal which are specified in the West Ladder Rack Terminaling Agreement. The terminaling service fee is subject to (i) increase or decrease effective as of January 1 of each year, beginning

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on January 1, 2016, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) adjustment by the amount of any increase in operating costs greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the West Ladder Rack Terminaling Agreement.
Toledo Storage Facility Storage and Terminaling Services Agreement
On December 12, 2014, PBF Holding and Toledo Terminaling entered into the Toledo Storage Facility Storage and Terminaling Agreement under which PBFX, through Toledo Terminaling, will provide storage and terminaling services to PBF Holding. The Toledo Storage Facility Storage and Terminaling Agreement can be extended by PBF Holding for two additional five-year periods. Under the Toledo Storage Facility Storage and Terminaling Agreement, PBFX will provide PBF Holding with storage and throughput services in return for storage and throughput fees.
The storage lease requires PBFX to accept, redeliver and store all products tendered by PBF Holding in the tanks and load products at the storage facility on behalf of PBF Holding up to the effective operating capacity of each tank, the loading capacity of the products rack and the overall capacity of the Toledo Storage Facility. PBF Holding pays a lease fee of $0.50 per barrel of shell capacity dedicated and operable to PBF Holding under the Toledo Storage Facility Storage and Terminaling Agreement. The minimum throughput commitment for the propane storage and loading facility will be 4,400 bpd (calculated on a quarterly average basis) for a fee equal to $2.52 per barrel of product loaded up to the minimum throughput commitment with no fee reduction for barrels loaded in excess of the minimum throughput commitment. The storage and terminaling services fee is subject to (i) increase or decrease effective as of January 1 of each year, beginning on January 1, 2016, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) adjustment by the amount of any increases in operating costs greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services under the Toledo Storage Facility Storage and Terminaling Agreement.
PBFX is required to maintain the Toledo Storage Facility in a condition and with a capacity sufficient to store and handle a volume of PBF Holding's products at least equal to the current operating capacity for the storage facility as a whole subject to interruptions for routine repairs and maintenance and force majeure events. Failure to meet such obligations may result in a reduction of fees payable under the Toledo Storage Facility Storage and Terminaling Agreement.
2015 Commercial Agreements
Delaware Pipeline Services Agreement
On May 15, 2015, PBF Holding and Delaware Pipeline Company LLC entered into a pipeline services agreement (the “Delaware Pipeline Services Agreement”) under which PBFX provides pipeline services to PBF Holding. The initialremaining term of the Delaware Pipeline Services Agreement is approximately ten years, after which PBF Holding has the option to extend the agreement for two additional five year periods. Under the Delaware Pipeline Services Agreement, PBF Holding is obligated to throughput aggregate volumes on the Delaware Products Pipeline as follows:
The minimum throughput commitment is at least 50,000 bpd, at an initial fee equal to $0.5266 per barrel for all volumeslease. Certain of product received on the pipeline equal to at least the minimum throughput commitment, in any contract quarter.
The pipeline service fee is subject to (i) increase or decrease effectivethese railcars were idle as of July 1September 30, 2018 and the remaining railcars were taken out of each year, by the amount of any change in any inflationary index promulgated by the Federal Energy Regulatory Commission (“FERC”) in accordance with FERC’s indexing methodology or (ii) in the event that FERC terminates its indexing methodologyservice during the termfourth quarter of the agreement, by a percentage equal2018 and subsequently fully returned to the change inlessor. As a result, we recognized an expense of $52.3 million for the Consumer Price Index- All Urban Consumers (“CPI-U”). Effective July 1, 2015,year ended December 31, 2018 included within Cost of sales consisting of (i) a $40.3 million charge for the pipeline service fee was raised to $0.5507 per barrel, due to an increase in the FERC tariff.
Delaware City Truck Loading Services Agreement
On May 15, 2015, PBF Holding and Delaware City Logistics Company LLC entered into a terminaling services agreement (the “Delaware City Truck Loading Services Agreement”) under which PBFX provides terminaling services to PBF Holding. The initial term of the Delaware City Truck Loading Services Agreement is approximately ten years, after which PBF Holding has the option to extend the agreement for two additional five year periods.Under the Delaware City Truck Loading Services Agreement, PBF Holding is obligated to throughput aggregate volumes on the Delaware City Truck Rack as follows:

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The minimum throughput commitment is (i) at least 30,000 bpd of gasoline, diesel and heating oil for a fee equal to $0.462 per barrel;Early Termination Penalty and (ii) at least 5,000 bpd of LPGs for a fee equal to $2.52 for all volumes of product loaded into trucks at the product terminal equal to at least the minimum throughput commitment, in any contract quarter.
The terminaling service fee is subject to (i) increase or decrease effective as of January 1 of each year, commencing on January 1, 2016, by the amount of any change in the Producer Price Index provided that the fee may not be adjusted below the initial amount and (ii) adjustment by the amount of any increases in operating costs greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the Delaware City Truck Loading Services Agreement.
Operational Agreements
PBF Holding and certain related affiliates have entered into operational agreements with PBFX for the use of centralized corporate services. In accordance with such agreements, PBF Holding receives fees from PBFX for use of these services. Below is a summary of the agreements and corresponding fees that PBFX pays PBF Holding.
Third Amended and Restated Omnibus Agreement
On May 14, 2014, PBF Holding entered into the Omnibus Agreement by and among PBFX, PBF GP, PBF LLC and PBF Holding for the provision of executive management services and support for accounting and finance, legal, human resources, information technology, environmental, health and safety, and other administrative functions
The Omnibus Agreement addresses the following matters:

PBFX’s obligation to pay PBF Holding, an administrative fee, in the amount of $2.4$12.0 million per year, for the provision by PBF LLC of centralized corporate services (which fee is in addition to certain expenses of PBF GP and its affiliates that are reimbursed under the Partnership Agreement);
PBFX’s obligation to reimburse PBF Holding for the salaries and benefits costs of employees who devote more than 50% of their time to PBFX;
PBFX’s agreement to reimburse PBF Holding for all other direct or allocated costs and expenses incurred by PBF LLC on PBFX’s behalf;
PBF LLC’s agreement not to compete with PBFX under certain circumstances, subject to certain exceptions;
PBFX’s right of first offer for ten years to acquire certain logistics assets retained by PBF Energy following the PBFX Offering, including certain logistics assets that PBF LLC or its subsidiaries may construct or acquire in the future, subject to certain exceptions;
a license to use the PBF Logistics trademark and name; and
PBF Holding’s agreement to reimburse PBFX for certain expenditures up to $20.0 million per event (net of any insurance recoveries)charge related to the contributed assets for a period of five years after the closing of the PBFX Offering, and PBFX's agreement to bear the costsremaining lease payments associated with the expansionrailcars identified within the amended lease, all of which were idled and out of service as of December 31, 2018.
Torrance Land Sale
On August 7, 2018, we closed on a third-party sale of a parcel of real property acquired as part of the DCR Rail Terminal crude unloading capability. The liability arising from this agreement is classified as “Accounts Payable - Affiliate” on the PBF Holding consolidated balance sheet.
The Omnibus Agreement was amended and restated on September 30, 2014 in connection with the Contribution Agreement II and again on December 12, 2014 in connection with the Contribution Agreement III. The annual fee payable under the Amended and Restated Omnibus Agreement increased from $2.3 million to $2.5 million as a resultTorrance Refinery, but not part of the inclusionrefinery itself. The sale resulted in a gain of approximately $43.8 million included within (Gain) loss on sale of assets within the DCR West Rack, and was further increased under the Second Amended and Restated Omnibus Agreement to $2.7 million as a resultConsolidated Statements of the inclusion of the Toledo Storage Facility. Effective January 1, 2015, pursuant to the Omnibus Agreement as amended, the annual fee was reduced to $2.2 million. The Omnibus Agreement was last amended on May 15, 2015 to include the Delaware City Products Pipeline and Truck Rack. Pursuant to the Third Amended and Restated Omnibus Agreement, the annual administrative fee was increased to $2.4 million per year from $2.2 million per year.Operations.
Third Amended and Restated Operation and Management Services and Secondment Agreement
On May 14, 2014, PBF Holding and certain of its subsidiaries entered into the Services Agreement with PBFX, pursuant to which PBF Holding and its subsidiaries provide PBFX with the personnel necessary for PBFX to perform its obligations under its commercial agreements. Under the agreement, 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. In addition, PBFX pays an initial annual fee of $0.5 million to PBF Holding for the provision of such services pursuant to the Services Agreement. The Services Agreement will terminate upon the termination of the Second Amended and

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Restated Omnibus Agreement, provided that PBFX may terminate any service on 30 days’ notice. The Services Agreement was amended and restated in connection with the Contribution Agreement II and Contribution Agreement III. The annual fee payable under the Amended and Restated Services Agreement increased from $0.5 million to $0.8 million (indexed for inflation) as a result of the inclusion of the DCR West Rack and was further increased under the Second Amended and Restated Services Agreement to $4.4 million (indexed for inflation) as a result of the inclusion of the Toledo Storage Facility. The operation and management services and secondment agreement was amended, effective as of the closing of the Delaware City Products Pipeline and Truck Rack acquisition, increasing the annual fee to $4.5 million.
Amended and Restated Asset Based Revolving Credit Facility
On an ongoing basis,May 2, 2018, we and certain of our wholly-owned subsidiaries, as borrowers or subsidiary guarantors, replaced our existing asset-based revolving credit agreement dated as of August 15, 2014 (the “August 2014 Revolving Credit Agreement”) with the Revolving Loan isCredit Facility. Among other things, the Revolving Credit Facility increased the maximum commitment available to be usedus from $2.6 billion to $3.4 billion, extended the maturity date to May 2023, and redefined certain components of the Borrowing Base, as defined in the agreement governing the Revolving Credit Facility (the “Revolving Credit Agreement”), to make more funding available for working capital and other general corporate purposes. In 2012, we amended the Revolving Loan to increase the aggregate size from $500.0 million to $965.0 million. In addition, the Revolving Loan was amended and restated on October 26, 2012 to increase the maximum availability to $1.375 billion, extend the maturity date to October 26, 2017 and amend the borrowing base to include non-U.S. inventory. The agreement was expanded again in December 2012 and November 2013 to increase the maximum availability from $1.375 billion to $1.610 billion. On August 15, 2014, the agreement was amended and restated once more to, among other things, increase the maximum availability to $2.500 billion and extend its maturity to August 2019. The amended and restated Revolving Loan includes an accordion feature which allows for aggregate commitments of up to $2.750$3.5 billion. In November and December 2015, we increased the maximum availability under the Revolving Loan to $2.600 billion and $2.635 billion, respectively, in accordance with its accordion feature. The commitment fees on the unused portions,portion, the interest rate on advances and the fees for letters of credit have also been reducedare consistent with the August 2014 Revolving Credit Agreement and further described in “Note 8 - Credit Facility and Debt” of our Notes to Consolidated Financial Statements.
There were no outstanding borrowings on the amendedrevolver as of December 31, 2018. At December 31, 2017 and restatedDecember 31, 2016, there was $350.0 million outstanding under the August 2014 Revolving Loan.Credit Agreement, respectively.
Senior Secured Notes Offering
On November 24, 2015, PBF HoldingMay 30, 2017, we and PBF Finance Corporation issued $500.0$725.0 million, in aggregate, principal amount of the 20232025 Senior Notes. We used the net proceeds of $711.6 million to fund the cash tender offer (the “Tender Offer”) for any and all of the outstanding 8.25% senior secured notes due 2020 (the “2020 Senior Secured Notes. The net proceeds were approximately $490.0 millionNotes”), to pay the related redemption price and accrued and unpaid interest for any 2020 Senior Secured Notes that remained outstanding after deducting the initial purchasers’ discountcompletion of the Tender Offer, and offering expenses. The Company intends to use the proceeds for general corporate purposes, includingpurposes. As described in “Note 8 - Credit Facility and Debt” of our Notes to fund a portionConsolidated Financial Statements, upon the satisfaction and discharge of the purchase price for2020 Senior Secured Notes in connection with the pending acquisitionclosing of the Torrance refineryTender Offer and the redemption, the 2023 Senior Notes became unsecured and certain covenants were modified, as provided for in the indenture governing the 2023 Senior Notes and related logistics assets.documents.
PBF Rail Facility Revolving Credit FacilityTerm Loan
Effective March 25, 2014,On December 22, 2016, PBF Rail Logistics Company LLC (“PBF Rail”), an indirect wholly-owned subsidiary of PBF Holding, entered into a $250.0$35.0 million secured revolving credit agreementterm loan (the “Rail Facility”“PBF Rail Term Loan”). The primary purpose of with a bank previously party to the Rail Facility is to fund the acquisition byFacility. The PBF Rail of coiledTerm Loan amortizes monthly over its five-year term and insulated crude tank cars and non-coiled and non-insulated general purpose crude tank cars (the “Eligible Railcars”) before December 2015. The amount available to be advanced underbears interest at the Rail Facility equals 70.0% ofone month LIBOR plus the lesser of the aggregate Appraised Value of the Eligible Railcars, or the aggregate Purchase Price of such Eligible Railcars,margin as these terms are defined in the credit agreement.
On April 29, 2015,agreement governing the PBF Rail Facility was amended to,Term Loan (the “Rail Credit Agreement”). As security for the PBF Rail Term Loan, PBF Rail pledged, among other things, extend(i) certain Eligible Railcars (ii) the maturity from March 31, 2016 to April 29, 2017, reduce the total commitment from $250.0 million to $150.0 million, and reduce the commitment fee on the used portion ofDebt Service Reserve Account (as defined in the Rail Facility. At any time prior to maturityCredit Agreement); and (iii) our member interest in PBF Rail. Additionally, the Rail Credit Agreement 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.
The outstanding balance under the PBF Rail Term Loan was $21.6 million and re-borrow any advances without premium or penalty. $28.4 million as of December 31, 2018 and December 31, 2017, respectively.
Torrance Acquisition
On July 1, 2016, we acquired from ExxonMobil and its subsidiary, Mobil Pacific Pipeline Company, the first anniversaryTorrance refinery and related logistics assets. The Torrance refinery, located on 750 acres in Torrance, California, is a high-conversion


155,000 bpd, delayed-coking refinery with a Nelson Complexity Index of 14.9. 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 increased our total throughput capacity to approximately 900,000 bpd.
In addition to refining assets, the Torrance Acquisition included a number of high-quality logistics assets consisting of a sophisticated network of crude and products pipelines, product distribution terminals and refinery crude and product storage facilities. The most significant of the closinglogistics assets is a 189-mile 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 amendment,Ports of Long Beach and Los Angeles, as well as clean product outlets with a direct pipeline supplying jet fuel to the advance rate adjusts automatically to 65%.Los Angeles airport. The Torrance refinery also has crude and product storage facilities with approximately 8.6 million barrels of shell capacity.
J. AronThe purchase price for the assets was approximately $521.4 million in cash after post-closing purchase price adjustments, plus working capital of $450.6 million. The final purchase price and fair value allocation were completed as of June 30, 2017. The transaction was financed through a combination of cash on hand, including proceeds from certain PBF Energy equity offerings, and borrowings under our August 2014 Revolving Credit Agreement.
Inventory Intermediation Agreements
On May 29, 2015, PBF Holdingcertain dates subsequent to the inception of the Inventory Intermediation Agreements, we and our subsidiaries, DCR and PRC, entered into amended and restated inventory intermediation agreements (“A&R Intermediation Agreements”)amendments with J. Aron pursuant to which certain terms of the existing inventory intermediation agreementsInventory Intermediation Agreements were amended, including, among other things, pricing and an extension of the term. The most recent of these was on September 8, 2017 which extends the term for a period of two years from the original expiry date ofInventory Intermediation Agreement relating to DCR and PRC to July 1, 2015, subject to certain early termination rights. In addition, the A&R Intermediation Agreements include one-year renewal clauses2019 and December 31, 2019, respectively, which terms may be further extended by mutual consent of both parties.the parties to July 1, 2020 and December 31, 2020, respectively.
Pursuant to each A&RInventory Intermediation Agreement, J. Aron will continuecontinues to purchase and hold title to certain of the intermediate and finished productsProducts produced by the Paulsboro and Delaware City refineries, respectively,Refineries, and delivered into tanks at the refineries.Refineries. Furthermore, J. Aron agrees to sell the productsProducts back to Paulsboro refinery and Delaware City refinerythe Refineries as the productsProducts are discharged out of the refineries'Refineries’ tanks. J. Aron has the right to store the Products purchased in tanks under the A&RInventory Intermediation Agreements and will retain these storage rights for the term of the agreements. PBF Holding willWe continue to market and sell the productsProducts independently to third parties.

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Crude Oil Acquisition Agreement Terminations
Effective July 31, 2014, PBF Holding terminated the Amended and Restated Crude Oil Acquisition Agreement, dated as of March 1, 2012 as amended (the “Toledo Crude Oil Acquisition Agreement”) with MSCG.  Under the terms of the Toledo Crude Oil Acquisition Agreement, we previously acquired substantially all of our crude oil for our subsidiary's Toledo refinery from MSCG through delivery at various interstate pipeline locations. No early termination penalties were incurred by us as a result of the termination. We began sourcing our own crude oil needs for Toledo upon termination.
Effective December 31, 2015, our crude oil supply agreement with Statoil for the Delaware City refinery expired. Subsequent to the termination of the Statoil supply agreement, we purchase all of our crude and feedstock needs independently from a variety of suppliers, including Saudi Aramco and others, on the spot market or through term agreements. We have a contract with PDVSA for the supply of 40,000 to 60,000 bpd of crude oil that can be processed at any of our East or Gulf Coast refineries.
Renewable Fuels Standard
We have seen fluctuations in the cost of renewable fuel credits, known asare subject to obligations to purchase RINs required for complianceto comply with the RFS.Renewable Fuels Standard. Our overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by EPA. To the degree we are unable to blend the required amount of biofuels to satisfy our RINs obligation, RINs must be purchased on the open market to avoid penalties and fines. We record our RINs obligation on a net basis in Accrued expenses when our RINs liability is greater than the amount of RINs earned and purchased in a given period and in Prepaid and other current assets when the amount of RINs earned and purchased is greater than the RINs liability. We incurred approximately $171.6$143.9 million in RINs costs during the year ended December 31, 20152018 as compared to $115.7$293.7 million and $126.4$347.5 million during the years ended December 31, 20142017 and 2013,2016, respectively. The fluctuations in RINs costs are due primarily to volatility in prices for ethanol-linked RINs and increases in our production of on-road transportation fuels since 2012. Our RINs purchase obligation is dependent on our actual shipment of on-road transportation fuels domestically and the amount of blending achieved.
Crude Oil Acquisition Agreements
We have a contract with Saudi Aramco pursuant to which we have been purchasing up to approximately 100,000 bpd of crude oil from Saudi Aramco that is processed at our Paulsboro refinery. In connection with the Chalmette Acquisition we entered into a contract with PDVSA for the supply of 40,000 to 60,000 bpd of crude oil that can be processed at any of our East or Gulf Coast refineries. We have not sourced crude oil under this agreement since the third quarter of 2017 as PDVSA has suspended deliveries due to the parties’ inability to agree to mutually acceptable payment terms. In connection with the closing of the Torrance Acquisition, we entered into a crude supply agreement with ExxonMobil for approximately 60,000 bpd of crude oil that can be processed at our Torrance refinery. We currently purchase all of our crude and feedstock needs independently from a variety of suppliers on the spot market or through term agreements for our Delaware City and Toledo refineries.


Agreements with PBFX
PBFX is a fee-based, growth-oriented, publicly-traded Delaware MLP formed by our indirect parent company, PBF Energy, to own or lease, operate, develop and acquire crude oil, refined petroleum products terminals, pipelines, storage facilities and similar logistics assets. PBFX engages in the receiving, handling, storage and transferring of crude oil, refined products, natural gas and intermediates from sources located throughout the United States and Canada for us in support of our refineries, as well as for third-party customers.
Beginning with the completion of the PBFX Offering, we have entered into a series of agreements with PBFX, including contribution, commercial and operational agreements. Each of these agreements and their impact to our operations is described in “Item 1. Business” and “Note 10 - Related Party Transactions” of our Notes to Consolidated Financial Statements.
A summary of transactions with PBFX is as follows (in thousands):
  Year Ended December 31,
  2018 2017 2016
Reimbursements under affiliate agreements:      
Services Agreement $7,477
 $6,626
 $5,121
Omnibus Agreement 7,468
 6,899
 4,805
Total expenses under affiliate agreements 259,426
 240,654
 175,448
Factors Affecting Operating Results
Overview
Our earnings and cash flows from operations are primarily affected by the relationship between refined product prices and the prices for crude oil and other feedstocks. The cost to acquire crude oil and other feedstocks and the price of refined petroleum products ultimately sold depends on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline, diesel and other refined petroleum products, which, in turn, depend on, among other factors, changes in global and regional economies, weather conditions, global and regional political affairs, production levels, the availability of imports, the marketing of competitive fuels, pipeline capacity, prevailing exchange rates and the extent of government regulation. Our revenue and operating income from operations fluctuate significantly with movements in industry refined petroleum product prices, our materials cost fluctuate significantly with movements in crude oil prices and our other operating expenses fluctuate with movements in the price of energy to meet the power needs of our refineries. In addition, the effect of changes in crude oil prices on our operating results is influenced by how the prices of refined products adjust to reflect such changes.
Crude oil and other feedstock costs and the prices of refined petroleum products have historically been subject to wide fluctuation. Expansion and upgrading of existing facilities and installation of additional refinery distillation or conversion capacity, price volatility, governmental regulations, international political and economic developments and other factors beyond our control are likely to continue to play an important role in refining industry economics. These factors can impact, among other things, the level of inventories in the market, resulting in price volatility and a reduction or increase in product margins. Moreover, the industry typically experiences seasonal fluctuations in demand for refined petroleum products, such as for gasoline and diesel, during the summer driving season and for home heating oil during the winter.
Benchmark Refining Margins
In assessing our operating performance, we compare the refining margins (revenue less materials cost) of each of our refineries against a specific benchmark industry refining margin based on crack spreads. Benchmark refining margins take into account both crude and refined petroleum product prices. When these prices are combined in a formula they provide a single value—a gross margin per barrel—that, when multiplied by throughput, provides an approximation of the gross margin generated by refining activities.
The performance of our East Coast refineries generally follows the Dated Brent (NYH) 2-1-1 benchmark refining margin. Our Toledo refinery generally follows the WTI (Chicago) 4-3-1 benchmark refining margin. Our Chalmette refinery generally follows the LLS (Gulf Coast) 2-1-1 benchmark refining margin. Our Torrance refinery generally follows the ANS (West Coast) 4-3-1 benchmark refining margin.


While the benchmark refinery margins presented below under “Results of Operations—Market Indicators” are representative of the results of our refineries, each refinery’s realized gross margin on a per barrel basis will differ from the benchmark due to a variety of factors affecting the performance of the relevant refinery to its corresponding benchmark.

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These factors include the refinery’s actual type of crude oil throughput, product yield differentials and any other factors not reflected in the benchmark refining margins, such as transportation costs, storage costs, credit fees, fuel consumed during production and any product premiums or discounts, as well as inventory fluctuations, timing of crude oil and other feedstock purchases, a rising or declining crude and product pricing environment and commodity price management activities. As discussed in more detail below, each of our refineries, depending on market conditions, has certain feedstock-cost and product-value advantages and disadvantages as compared to the refinery’s relevant benchmark.
Credit Risk Management
Credit risk refers to the risk that a counterparty will default on its contractual obligations resulting in financial loss to us. Our exposure to credit risk is reflected in the carrying amount of the receivables that are presented in our consolidated balance sheet. To minimize credit risk, all customers are subject to extensive credit verification procedures and extensions of credit above defined thresholds are to be approved by the senior management. Our intention is to trade only with recognized creditworthy third parties. In addition, receivable balances are monitored on an ongoing basis. We also limit the risk of bad debtsdebt by obtaining security such as guarantees or letters of credit.
Other Factors
We currently source our crude oil for the Paulsboro, Delaware City and Chalmetteour refineries on a global basis through a combination of market purchases and short-term purchase contracts, and through our crude oil supply agreements with Saudi Aramco and PDVSA. Our crude oil supply agreement with Statoil for Paulsboro was terminated effective March 31, 2013, at which time we began to source Paulsboro’s crude oil and feedstocks independently. Our crude oil supply agreement with Statoil for Delaware City expired on December 31, 2015. Subsequent to the termination of the Statoil supply agreement, we purchase all of our crude and feedstock needs independently from a variety of suppliers, including Saudi Aramco and others, on the spot market or through term agreements. We have been purchasing up to approximately 100,000 bpd of crude oil from Saudi Aramco that is processed at Paulsboro. We have a contract with PDVSA for the supply of 40,000 to 60,000 bpd of crude oil that can be processed at any of our East or Gulf Coast refineries. Prior to the termination of the Toledo Crude Oil Acquisition Agreement, our Toledo refinery sourced domestic and Canadian crude oil through similar market purchases through this crude supply contract with MSCG. Subsequently, our Toledo refinery has sourced its crude oil and feedstocks independently. We believe purchases based on market pricing has given us flexibility in obtaining crude oil at lower prices and on a more accurate “as needed” basis. Since our Paulsboro and Delaware City refineries access their crude slates from the Delaware River via ship or barge and through our and PBFX's rail facilities at Delaware City, these refineries have the flexibility to purchase crude oils from the Mid-Continent and Western Canada, as well as a number of different countries. We have not sourced crude oil under our crude supply arrangement with PDVSA since the third quarter of 2017 as PDVSA has suspended deliveries due to our inability to agree to mutually acceptable payment terms.
Since 2012,In the past several years, we have expanded and upgraded the existing on-site railroad infrastructure at ourthe Delaware City refinery, including the expansion of the crude rail unloading facilities.refinery. Currently, crude oil delivered by rail to this facility is consumed at our Delaware City refinery. We may also transport some of the crude delivered by rail from Delaware City via barge to ourand Paulsboro refinery or other third party destinations. In 2014, we and PBFX completed a project to expand the Delaware City heavy crude rail unloading facility.refineries. The Delaware City rail unloading facility,facilities, which was transferredwere sold to PBFX in 2014, allowsallow our East Coast refineries to source WTI-based crude oiloils from Western Canada and the Mid-Continent, which we believe, at times, may provide cost advantages versus traditional Brent-based international crude oils.
During 2012 and January 2013, In support of this rail strategy, we have at times entered into agreements to lease or purchase 5,900 crude railcars which will enable us to transport crude oil by rail to each of our refineries. A portionrailcars. Certain of these railcars were purchased via the Rail Facility entered into during 2014. Additionally, we have purchased a portion of these railcars and subsequently sold them to a third party,third-party, which has leased the railcars back to us for periods of between four and seven years. As of December 31, 2015 and 2014,In subsequent periods we have purchasedsold or returned railcars to optimize our railcar portfolio. As discussed in “Note 7 - Accrued expenses” of our Notes to Consolidated Financial Statements, on September 30, 2018, we agreed to voluntarily return a portion of railcars under an operating lease in order to rationalize certain components of our railcar fleet based on prevailing market conditions in the crude oil by rail market. Under the terms of the lease amendment, we agreed to pay the Early Termination Penalty and subsequently leased back 1,122 and 1,403 railcars, respectively.will pay a reduced rental fee over the remaining term of the lease. Our railcar fleet, at times, provides transportation flexibility within our crude oil sourcing strategy that allows our East Coast refineries to process cost advantaged crude from Canada and the Mid-Continent.
Our operating cost structure is also important to our profitability. Major operating costs include costs relating to employees and contract labor, energy, maintenance and environmental compliance and renewable fuel credits, known asemission control regulations, including the cost of RINs required for compliance with the Renewable Fuels Standard. The predominant variable cost is energy, in particular, the price of utilities, natural gas electricity and chemicals.electricity.
Our operating results are also affected by the reliability of our refinery operations. Unplanned downtime of our refinery assets generally results in lost margin opportunity and increased maintenance expense. The financial impact of planned downtime, such as major turnaround maintenance, is managed through a planning process that considers such things as the margin environment, the availability of resources to perform the needed maintenance and feed logistics, whereas unplanned downtime does not afford us this opportunity.

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Refinery-Specific Information
The following section includes refinery-specific information related to our operations, crude oil differentials, ancillary costs, and local premiums and discounts.
Delaware City Refinery. The benchmark refining margin for the Delaware City refinery is calculated by assuming that two barrels of the benchmark Dated Brent crude oil are converted into one barrel of gasoline and one barrel of ULSD.diesel. We calculate this refining marginbenchmark using the NYH market value of gasolinereformulated blendstock for oxygenate blending (“RBOB”) and ultra-low sulfur diesel (“ULSD”) against the market value of Dated Brent crude oil and refer to the benchmark as the Dated Brent (NYH) 2-1-1 benchmark refining margin. Our Delaware City refinery has a product slate of approximately 55% gasoline, 33%32% distillate, (consisting of ULSD, marketed as ULSD or low sulfur heating oil, and conventional heating oil), 1%2% high-value petrochemicals, with the remaining portion of the product slate comprised of lower-value products (4%(5% petroleum coke, 4%3% LPGs, 2% black oil and 3%1% other). For this reason, we believe the Dated Brent (NYH) 2-1-1 is an appropriate benchmark industry refining margin. The majority of Delaware City revenues are generated off NYH-based market prices.
The Delaware City refinery’s realized gross margin on a per barrel basis has historically differed from the Dated Brent (NYH) 2-1-1 benchmark refining margin due to the following factors:
the Delaware City refinery processes a slate of primarily medium and heavy and sour crude oil,oils, which has constituted approximately 65%55% to 70%65% of total throughput. The remaining throughput consists of sweet crude oil and other feedstocks and blendstocks. In addition, we have the capacitycapability to process a significant volume of light, sweet price-advantaged crude oil which may affect our overall crude slate depending on market conditions. Our total throughput costs have historically priced at a discount to Dated Brent; and
as a result of the heavy, sour crude slate processed at Delaware City, we produce lowlower value products including sulfur, carbon dioxide and petroleum coke. These products are priced at a significant discount to gasoline, ULSDRBOB and heating oil and represent approximately 5% to 7% of our total production volume.ULSD.
Paulsboro Refinery. The benchmark refining margin for the Paulsboro refinery is calculated by assuming that two barrels of the benchmark Dated Brent crude oil are converted into one barrel of gasoline and one barrel of ultra-low sulfur diesel. We calculate this refining marginbenchmark using the New York HarborNYH market value of gasolineRBOB and ultra-low sulfur dieselULSD against the market value of Dated Brent crude oil and refer to the benchmark as the Dated Brent (NYH) 2-1-1 benchmark refining margin. Our Paulsboro refinery has a product slate of approximately 40%42% gasoline, 37.5%33% distillate (comprised of jet fuel, ULSD and heating oil), 4.5%4% high-value Group I lubricants, with the remaining portion of the product slate comprised of lower-value products (2%(14% black oil, 3% petroleum coke, 4%2% LPGs 3% fuel oil, 8.5% asphalt and 0.5%2% other). For this reason, we believe the Dated Brent (NYH) 2-1-1 is an appropriate benchmark industry refining margin. The majority of Paulsboro revenues are generated off NYH-based market prices.
The Paulsboro refinery’s realized gross margin on a per barrel basis has historically differed from the Dated Brent (NYH) 2-1-1 benchmark refining margin due to the following factors:
the Paulsboro refinery has generally processedprocesses a slate of primarily medium and heavy and sour crude oil,oils, which has historically constituted approximately 65%75% to 70%85% of total throughput. The remaining throughput consists of sweet crude oil and other feedstocks and blendstocks;
as a result of the heavy, sour crude slate processed at Paulsboro, we produce lowlower value products including sulfur and petroleum coke and fuel oil.coke. These products are priced at a significant discount to gasolineRBOB and heating oil and represent approximately 5% to 7% of our total production volume;ULSD; and
the Paulsboro refinery produces Group I lubricants which through an extensive production process, have a low volume yield on throughput but carry a premium sales price.price to RBOB and ULSD.
Toledo Refinery. The benchmark refining margin for the Toledo refinery is calculated by assuming that four barrels of benchmark WTI crude oil are converted into three barrels of gasoline, one-half barrel of ULSD and one-half barrel of jet fuel. We calculate this refining margin using the Chicago market values of gasolineconventional blendstock for oxygenate blending (“CBOB”) and ULSD and the United States Gulf Coast value of jet fuel against the market value of WTI crude oil and refer to this benchmark as the WTI (Chicago) 4-3-1 benchmark refining margin. Our Toledo refinery has a product slate of approximately 52%55% gasoline, 36%33% distillate, (comprised of jet fuel and ULSD), 5% high-value petrochemicals (including nonene, tetramer, benzene, xylene and toluene) with the remaining portion of the product slate comprised of lower-value products (5%(4% LPGs and 2%3% other). For this reason, we believe the WTI (Chicago) 4-3-1 is an appropriate benchmark industry refining margin. The majority of Toledo revenues are generated off Chicago-based market prices.

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The Toledo refinery’s realized gross margin on a per barrel basis has historically differed from the WTI (Chicago) 4-3-1 benchmark refining margin due to the following factors:


the Toledo refinery processes a slate of domestic sweet and Canadian synthetic crude oil. Historically, Toledo’s blended average crude costs have been higher thandiffered from the market value of WTI crude oil;
the Toledo refinery configuration enables it to produce more barrels of product than throughput which generates a pricing benefit; and
the Toledo refinery generates a pricing benefit on some of its refined products, primarily its petrochemicals.

Chalmette Refinery. The benchmark refining margin for the Chalmette refinery is the LLS (Gulf Coast)2-1-1 crack spread, which is a benchmark that approximates the per barrel refining margin resulting from processingcalculated by assuming two barrels of Light Louisiana Sweet (“LLS”) crude oil to produceare converted into one barrel of gasoline and one barrel of ultra-low sulfur diesel. We calculate this refining marginbenchmark using the US Gulf Coast Conventional market value of 87 conventional gasoline and ultra-low sulfur dieselULSD against the market value of LLS crude oil and refer to this benchmark as the LLS (Gulf Coast) 2-1-1 benchmark refining margin. Our Chalmette refinery has a product slate of approximately 55%50% gasoline 33%and 30% distillate, (comprised of ULSD, LSD, Heating Oil, and light crude oil), 5% high-value petrochemicals (including benzene and xylenes) with the remaining portion of the product slate comprised of lower-value products (3%(10% black oil, 4% petroleum coke, 3% LPGs and 1%3% other). For this reason, we believe the LLS (Gulf Coast) 2-1-1 is an appropriate benchmark industry refining margin. The majority of Chalmette revenues are generated off Gulf Coast-based market prices.
The Chalmette refinery’s realized gross margin on a per barrel basis has historically differed from the LLS (USGC) 2-1-1 benchmark refining margin due to the following factors:
the Chalmette refinery has generally processed a slate of primarily medium and heavy sour crude oils, which has historically constituted approximately 55% to 65% of total throughput. The remaining throughput consists of sweet crude oil and other feedstocks and blendstocks; and
as a result of the heavy, sour crude slate processed at Chalmette, we produce lower-value products including sulfur and petroleum coke. These products are priced at a significant discount to 87 conventional gasoline and ULSD.
The PRL (pre-treater, reformer, light ends) project was completed in 2017 which has increased high-octane, ultra-low sulfur reformate and chemicals production. The new crude oil tank was also commissioned in 2017 and is allowing additional gasoline and diesel exports, reduced RINs compliance costs and lower crude ship demurrage costs.
Additionally, we are in the process of restarting our idled 12,000 barrel per day coker unit to increase the refinery’s long-term feedstock flexibility and to be better positioned to benefit from potential dislocations in the price for heavy and high-sulfur feedstocks. The unit is expected to be in service by the end of 2019 and will increase the refinery’s total coking capacity to approximately 42,000 barrels per day.
Torrance Refinery. The benchmark refining margin for the Torrance refinery is calculated by assuming that four barrels of Alaskan North Slope (“ANS”) crude oil are converted into three barrels of gasoline, one-half barrel of diesel and one-half barrel of jet fuel. We calculate this benchmark using the West Coast Los Angeles market value of California reformulated blendstock for oxygenate blending (CARBOB), California Air Resources Board (CARB) diesel and jet fuel and refer to the benchmark as the ANS (WCLA) 4-3-1 benchmark refining margin. Our Torrance refinery has a product slate of approximately 60% gasoline and 26% distillate with the remaining portion of the product slate comprised of lower-value products (9% petroleum coke, 2% LPG, 2% black oil and 1% other). For this reason, we believe the ANS (West Coast) 4-3-1 is an appropriate benchmark industry refining margin. The majority of Torrance revenues are generated off West Coast Los Angeles-based market prices.
The Torrance refinery’s realized gross margin on a per barrel basis has historically differed from the ANS (WCLA) 4-3-1 benchmark refining margin due to the following factors:
the Torrance refinery has generally processed a slate of primarily heavy sour crude oils, which has historically constituted approximately 80% to 90% of total throughput. The Torrance crude slate has the lowest API gravity (typically an American Petroleum Institute (“API”) gravity of less than 20 degrees) of all of our refineries. The remaining throughput consists of other feedstocks and blendstocks; and
as a result of the heavy, sour crude slate processed at Torrance, we produce lower-value products including petroleum coke and sulfur. These products are priced at a significant discount to gasoline and diesel.



Results of Operations

The following tables reflect our consolidated financial and operating highlights for the years ended December 31, 2015, 20142018, 2017 and 20132016 (amounts in thousands).  
  Year Ended December 31,
  2015 2014 2013
Revenue $13,123,929
 $19,828,155
 $19,151,455
Cost of sales, excluding depreciation 11,611,599
 18,514,054
 17,803,314
  1,512,330
 1,314,101
 1,348,141
Operating expenses, excluding depreciation 889,368
 880,701
 812,652
General and administrative expenses 166,904
 140,150
 95,794
Gain on sale of asset (1,004) (895) (183)
Depreciation and amortization expense 191,110
 178,996
 111,479
Income from operations 265,952
 115,149
 328,399
Change in fair value of catalyst leases 10,184
 3,969
 4,691
Interest income (expense), net (88,194) (98,001) (94,214)
Income before income taxes 187,942
 21,117
 238,876
Income tax expense 648
 
 
Net Income 187,294
 21,117
 238,876
Less: net income attributable to noncontrolling interest 274
 
 
Net income attributable to PBF Holding LLC $187,020
 $21,117
 $238,876
       
Gross refining margin (1) $1,512,330
 $1,314,101
 $1,348,141
Gross margin 441,539
 267,987
 436,867
  Year Ended December 31,
  2018 2017 2016
Revenues $27,164,008
 $21,772,478
 $15,908,537
       
Cost and expenses:      
Cost of products and other 24,744,619
 19,095,827
 13,765,088
Operating expenses (excluding depreciation and amortization expense as reflected below) 1,654,749
 1,626,440
 1,390,135
Depreciation and amortization expense 329,709
 254,271
 204,005
Cost of sales 26,729,077
 20,976,538
 15,359,228
General and administrative expenses (excluding depreciation and amortization expense as reflected below) 253,834
 197,938
 149,510
Depreciation and amortization expense 10,634
 12,964
 5,835
Equity income in investee (17,819) (14,565) (5,679)
(Gain) loss on sale of assets (43,094) 1,458
 11,374
Total cost and expenses 26,932,632
 21,174,333
 15,520,268
       
Income from operations 231,376
 598,145
 388,269
       
Other income (expense):      
Change in fair value of catalyst leases 5,587
 (2,247) 1,422
Debt extinguishment costs 
 (25,451) 
Interest expense, net (127,129) (122,628) (129,536)
Other non-service components of net periodic benefit cost 1,109
 (1,402) (580)
Income before income taxes 110,943
 446,417
 259,575
Income tax expense (benefit) 7,999
 (10,783) 23,689
Net income 102,944
 457,200
 235,886
Less: net income attributable to noncontrolling interests 44
 95
 269
Net income attributable to PBF Holding Company LLC $102,900
 $457,105
 $235,617
       
Consolidated gross margin $434,931
 $795,940
 $549,309
Gross refining margin (1)
 2,419,389
 2,676,651
 2,143,449
 ——————————

(1)
See Non-GAAP financial measures below.



55



Operating Highlights
 Year Ended December 31,
 2015 2014 2013 Year Ended December 31,
       2018 2017 2016
Key Operating Information            
Production (barrels per day in thousands) 511.9
 452.1
 451.0
Crude oil and feedstocks throughput (barrels per day in thousands) 516.4
 453.1
 452.8
Production (bpd in thousands) 854.5
 802.9
 734.3
Crude oil and feedstocks throughput (bpd in thousands) 849.7
 807.4
 727.7
Total crude oil and feedstocks throughput (millions of barrels) 188.4
 165.4
 165.3
 310.0
 294.7
 266.4
Consolidated gross margin per barrel of throughput $1.39
 $2.70
 $2.06
Gross refining margin, excluding special items, per barrel of throughput (1) $10.29
 $12.11
 $8.16
 $9.09
 $8.08
 $6.09
Operating expense, excluding depreciation, per barrel of throughput $4.72
 $5.34
 $4.92
Refinery operating expense, per barrel of throughput $5.34
 $5.52
 $5.22
            
Crude and feedstocks (% of total throughput) (2):      
Heavy Crude 14% 14% 15%
Medium Crude 49% 44% 42%
Light Crude 26% 33% 35%
Crude and feedstocks (% of total throughput) (2)
      
Heavy 36% 34% 26%
Medium 30% 30% 37%
Light 21% 21% 25%
Other feedstocks and blends 11% 9% 8% 13% 15% 12%
Total throughput 100% 100% 100% 100% 100% 100%
            
Yield (% of total throughput):      
Yield (% of total throughput)      
Gasoline and gasoline blendstocks 49% 47% 46% 50% 50% 50%
Distillates and distillate blendstocks 35% 36% 37% 32% 30% 31%
Lubes 1% 2% 2% 1% 1% 1%
Chemicals 3% 3% 3% 2% 2% 3%
Other 12% 12% 12% 16% 16% 15%
Total yield 100% 100% 100% 101% 99% 100%
      
_________________      
(1) See Non-GAAP Financial measures below.(1) See Non-GAAP Financial measures below.
(1) See Non-GAAP Financial measures below.
(2) We define heavy crude oil as crude oil with American Petroleum Institute (API) gravity less than 24 degrees. We define medium crude oil as crude oil with API gravity between 24° and 35°. We define light crude oil as crude oil with API gravity higher than 35°.
(2) We define heavy crude oil as crude oil with American Petroleum Institute (API) gravity less than 24 degrees. We define medium crude oil as crude oil with API gravity between 24 and 35 degrees. We define light crude oil as crude oil with API gravity higher than 35 degrees.
(2) We define heavy crude oil as crude oil with American Petroleum Institute (API) gravity less than 24 degrees. We define medium crude oil as crude oil with API gravity between 24 and 35 degrees. We define light crude oil as crude oil with API gravity higher than 35 degrees.








56



The table below summarizes certain market indicators relating to our operating results as reported by Platts.
 Year Ended December 31, Year Ended December 31,
 2015 2014 2013 2018 2017 2016
 (dollars per barrel, except as noted) (dollars per barrel, except as noted)
Dated Brent Crude $52.56
 $98.95
 $108.66
Dated Brent crude oil $71.34
 $54.18
 $43.91
West Texas Intermediate (WTI) crude oil $48.71
 $93.28
 $97.99
 $65.20
 $50.79
 $43.34
Light Louisiana Sweet (LLS) crude oil $52.36
 $96.92
 $107.31
 $70.23
 $54.02
 $45.03
Alaska North Slope (ANS) crude oil $71.54
 $54.43
 $43.67
Crack Spreads            
Dated Brent (NYH) 2-1-1 $16.35
 $12.92
 $12.34
 $13.17
 $14.74
 $13.49
WTI (Chicago) 4-3-1 $17.91
 $15.92
 $20.09
 $14.84
 $15.88
 $12.38
LLS (Gulf Coast) 2-1-1 $14.39
 $16.95
 $11.54
 $12.30
 $13.57
 $10.75
ANS (West Coast) 4-3-1 $15.48
 $17.43
 $16.46
Crude Oil Differentials            
Dated Brent (foreign) less WTI $3.85
 $5.66
 $10.67
 $6.14
 $3.39
 $0.56
Dated Brent less Maya (heavy, sour) $8.45
 $13.08
 $11.38
 $8.70
 $7.16
 $7.36
Dated Brent less WTS (sour) $3.59
 $11.62
 $13.31
 $13.90
 $4.37
 $1.42
Dated Brent less ASCI (sour) $4.57
 $6.49
 $6.67
 $4.64
 $3.66
 $3.92
WTI less WCS (heavy, sour) $11.87
 $19.45
 $24.62
 $26.93
 $12.24
 $12.57
WTI less Bakken (light, sweet) $2.89
 $5.47
 $5.12
 $2.86
 $(0.26) $1.32
WTI less Syncrude (light, sweet) $(1.45) $2.25
 $0.63
 $6.84
 $(1.74) $(2.01)
WTI less LLS (light, sweet) $(5.03) $(3.23) $(1.69)
WTI less ANS (light, sweet) $(6.34) $(3.63) $(0.33)
Natural gas (dollars per MMBTU) $2.63
 $4.26
 $3.73
 $3.07
 $3.02
 $2.55

20152018 Compared to 20142017
Overview— NetOur net income for PBF Holding was $187.3$102.9 million for the year ended December 31, 20152018 compared to $21.1$457.2 million for the year ended December 31, 2014.2017.
Our results for the year ended December 31, 20152018 were negatively impacted by special items consisting of a non-cash special item consisting of anLCM inventory LCM adjustment of approximately $427.2$351.3 million whereasand the early return of certain leased railcars, resulting in a charge of $52.3 million. These unfavorable impacts were partially offset by a special item related to a gain on the Torrance land sale of $43.8 million. Our results for the year ended December 31, 2017 were positively impacted by an LCM inventory adjustment of approximately $295.5 million, which was partially offset by a special item related to debt extinguishment costs of $25.5 million associated with the early retirement of our 2020 Senior Secured Notes. Excluding the impact of special items, our results for the year ended December 31, 20142018 were negativelypositively impacted by an inventory LCM adjustmentfavorable movements in crude differentials, higher throughput volumes and barrels sold across the majority of approximately $690.1 million. These LCM chargesour refineries and reduced regulatory compliance costs, offset by lower crack spreads realized at the majority of our refineries, which were recordedfavorably impacted in the prior year by the hurricane-related effect on refining margins due to significant declines in the price of crude oil and refined products in 2015 and 2014. Our throughput rates during the year ended December 31, 2015 compared to December 31, 2014 were higher due to the acquisition of the Chalmette refinery on November 1, 2015 as well as an approximate 40-day plant-wide planned turnaround at our Toledo Refinery completed in the fourth quarter of 2014.tightening product inventories, specifically distillates. Our results for the year ended December 31, 20152018 were positivelynegatively impacted by higher throughput volumes, lower non-cash special items for LCM chargesgeneral and higher crack spreads for the East Coastadministrative costs and in the Mid-Continent partially offset by unfavorable movements in certain crude differentials.increased depreciation and amortization expense.
Revenues— Revenues totaled $13.1$27.2 billion for the year ended December 31, 20152018 compared to $19.8$21.8 billion for the year ended December 31, 2014, a decrease2017, an increase of approximately $6.7$5.4 billion or 33.8%24.8%. Revenues per barrel were $77.01 and $64.86 for the years ended December 31, 2018 and 2017, respectively, an increase of 18.7% directly related to higher hydrocarbon commodity prices. For the year ended December 31, 2015, the total throughput rates in the East Coast and Mid-Continent refineries averaged approximately 330,700 bpd and 153,800 bpd, respectively. For the period from its acquisition on November 1, 2015 through December 31, 2015, our Gulf Coast refinery's throughput averaged 190,800 bpd. For the year ended December 31, 2014,2018, the total throughput rates at our East Coast, Mid-Continent, Gulf Coast and Mid-ContinentWest Coast refineries averaged approximately 325,300344,700 bpd, 149,600 bpd, 185,600 bpd and 127,800169,800 bpd, respectively. For the year ended December 31, 2017, the total throughput rates at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 338,200 bpd, 145,200 bpd, 184,500 bpd and 139,500 bpd, respectively. The increasethroughput rates at our East Coast, Mid-Continent and West Coast refineries were higher in the year ended December 31, 2018 compared to the same period in 2017. Throughput rates at our Gulf Coast refinery were in line with the prior year despite planned downtimes during the first half of 2018. The throughput rates at our East Coast refineries in 2015 compared to 2014 was primarilyincreased due to higher run rates as a result of favorable market economics partially offset by unplannedplanned downtime at our Delaware City refinery in 2015.during 2017, whereas our Mid-Continent refinery ran at modestly higher rates during the year taking advantage of a relatively strong margin environment. The increase in


throughput rates at our Mid-ContinentWest Coast refinery in 2015 compared to 2014 was primarilyincreased due to an approximate 40-day plant-wide planned turnaround completeddowntime in the fourth quarterprior year as part of 2014.the first significant turnaround of the refinery under our ownership and improved refinery performance experienced in the current year. For the year ended December 31, 2015,2018, the total refined product barrels sold at our East Coast, Mid-Continent, Gulf Coast and Mid-ContinentWest Coast refineries averaged approximately 366,100372,700 bpd, 161,800 bpd, 233,700 bpd and 162,600198,100 bpd, respectively. For the year ended December 31, 2014,2017, the total refined product barrels sold at our East Coast, Mid-Continent, Gulf Coast and Mid-ContinentWest Coast refineries averaged approximately 350,800363,800 bpd, 160,400 bpd, 227,200 bpd and 144,100168,300 bpd, respectively. For the period from its acquisition on November 1, 2015 through December 31, 2015, the total refined product barrels sold at our Gulf Coast refinery averaged 216,100 bpd. Total refined product barrels sold were higher than throughput rates, reflecting sales from inventory as well as sales and purchases of refined products outside the refineries.
Consolidated Gross Margin— Consolidated gross margin totaled $434.9 million, or $1.39 per barrel of throughput, for the year ended December 31, 2018, compared to $795.9 million, or $2.70 per barrel of throughput for the year ended December 31, 2017, a decrease of approximately $361.0 million. Gross refining margin (as defined below in Non-GAAP Financial Measures) totaled $1,512.3$2,419.4 million, or $8.02 per barrel of throughput (or $1,939.6 million or $10.29 per barrel of throughput excluding the impact of

57



special items) for the year ended December 31, 2015 compared to $1,314.1 million, or $7.94 per barrel of throughput (or $2,004.2 million or $12.11 per barrel of throughput excluding the impact of special items) for the year ended December 31, 2014. Gross margin, including refinery operating expenses and depreciation, totaled $441.5 million, or $2.34$7.79 per barrel of throughput, for the year ended December 31, 2015,2018 compared to $268.0$2,676.7 million, or $1.60$9.08 per barrel of throughput for the year ended December 31, 2014, an increase2017, a decrease of $173.6approximately $257.3 million. Excluding the impact ofGross refining margin excluding special items gross refining margin decreased due to the narrowing of certain crude differentials partially offset by higher throughput rates, reflecting the impact from the Chalmette Acquisition, and favorable movements in crack spreads. Excluding the impact of special items, gross margin was relatively consistent with the prior year.
Average industry refining margins in the U.S. Mid-Continent were generally improved during the year ended December 31, 2015, as compared to the same period in 2014. The WTI (Chicago) 4-3-1 industry crack spread was approximately $17.91 per barrel, or 12.5% higher, in the year ended December 31, 2015, as compared to the same period in 2014. The price of WTI versus Dated Brent and other crude discounts narrowed during the year ended December 31, 2015, and our refinery specific crude slate in the Mid-Continent faced an adverse WTI/Syncrude differential, which averaged a premium of $1.45 per barrel for the year ended December 31, 2015 as compared to a discount of $2.25 per barrel in the same period in 2014.
The Dated Brent (NYH) 2-1-1 industry crack spread was approximately $16.35 per barrel, or 26.5% higher, in the year ended December 31, 2015, as compared to the same period in 2014. However, the WTI/Dated Brent differential was $1.81 lower in the year ended December 31, 2015, as compared to the same period in 2014, and the WTI/Bakken differential was $2.58 per barrel less favorable for the same periods. The Dated Brent/Maya differential was approximately $4.63 per barrel less favorable in the year ended December 31, 2015 as compared to the same period in 2014. Additionally, the decrease in the Dated Brent/Maya crude differential, our proxy for the light/heavy crude differential, had a negative impact on our East Coast refineries, which can process a large slate of medium and heavy, sour crude oil that is priced at a discount to light, sweet crude oil. However, the lower flat price of crude oil during 2015 as compared to 2014 resulted in improved margins on certain lower value products we produce.
Operating Expenses— Operating expenses totaled $889.4$2,823.0 million or $4.72$9.09 per barrel of throughput, for the year ended December 31, 20152018 compared to $880.7$2,381.1 million, or $8.08 per barrel of throughput, for the year ended December 31, 2017, an increase of $441.9 million.
Consolidated gross margin and gross refining margin were negatively impacted in the current year by special items. For the year ended December 31, 2018, special items impacting our margin calculations included a non-cash LCM inventory adjustment of approximately $351.3 million resulting from a decrease in crude oil and refined product prices in comparison to the prices at the end of 2017 and a $52.3 million charge resulting from costs associated with the early return of certain leased railcars. The non-cash LCM inventory adjustment increased consolidated gross margin and gross refining margin by approximately $295.5 million in the year ended December 31, 2017. Excluding the impact of special items, consolidated gross margin and gross refining margin increased due to generally favorable movements in crude differentials and higher throughput volumes and barrels sold across all of our refineries.
Additionally, our results continue to be impacted by significant costs to comply with RFS, although at a reduced level from the prior year. Total RFS costs were $143.9 million for the year ended December 31, 2018 in comparison to $293.7 million for the year ended December 31, 2017.
Average industry margins were weaker during the year ended December 31, 2018 in comparison to the prior year, primarily as a result of 2017 being favorably impacted by the hurricane-related effect on refining margins in the second half of the year due to tightening product inventories, specifically distillates. Crude oil differentials were generally favorable in comparison to the prior year, with beneficial differentials experienced across the East Coast and Mid-Continent, partially offset by marginally unfavorable impacts related to our refinery specific crude slate in the Gulf and West Coast.
On the East Coast, the Dated Brent (NYH) 2-1-1 industry crack spread was approximately $13.17 per barrel, or 10.7% lower, in the year ended December 31, 2018, as compared to $14.74 per barrel in the same period in 2017. Our margins were positively impacted from our refinery specific slate on the East Coast by an improving Dated Brent/WTI differential, which increased $2.75 per barrel in comparison to the prior year and increases in the Dated Brent/Maya and WTI/Bakken differentials, which increased $1.54 per barrel and $3.12 per barrel, respectively, in comparison to the prior year. In addition, the WTI/WCS differential widened significantly to $26.93 per barrel in 2018 compared to $12.24 in 2017 which favorably impacted our cost of heavy Canadian crude.
Across the Mid-Continent, the WTI (Chicago) 4-3-1 industry crack spread was $14.84 per barrel, or 6.5% lower, in the year ended December 31, 2018, as compared to $15.88 per barrel in the same period in 2017. Our margins were positively impacted from our refinery specific slate in the Mid-Continent by an improving WTI/Bakken differential, which was approximately $2.86 per barrel in the year ended December 31, 2018, as compared to a premium of $0.26 per barrel in the same period in 2017. Additionally, the WTI/Syncrude differential averaged a discount of $6.84 per barrel for the year ended December 31, 2018 as compared to a premium of $1.74 per barrel in the same period in 2017.
In the Gulf Coast, the LLS (Gulf Coast) 2-1-1 industry crack spread was $12.30 per barrel, or 9.4% lower, in the year ended December 31, 2018 as compared to $13.57 per barrel in the same period in 2017. Margins in the Gulf Coast were negatively impacted from our refinery specific slate by a declining WTI/LLS differential, which averaged a premium of $5.03 for the year ended December 31, 2018 as compared to an average premium of $3.23 experienced in the prior year.
On the West Coast, the ANS (West Coast) 4-3-1 industry crack spread was $15.48 per barrel, or 11.2% lower, in the year ended December 31, 2018 as compared to $17.43 per barrel in the same period in 2017. Margins on the West Coast were negatively impacted from our refinery specific slate by a declining WTI/ANS differential, which averaged a premium of $6.34 for the year ended December 31, 2018 as compared to an average premium of $3.63 experienced in the prior year.


Favorable movements in these benchmark crude differentials typically result in lower crude costs and positively impact our earnings while reductions in these benchmark crude differentials typically result in higher crude costs and negatively impact our earnings.
Operating Expenses— Operating expenses totaled $1,654.7 million, or $5.34 per barrel of throughput, for the year ended December 31, 2014,2018 compared to $1,626.4 million, or $5.52 per barrel of throughput, for the year ended December 31, 2017, an increase of $8.7$28.3 million, or 1.0%1.7%. The increase in operating expenses isoverall in comparison to the prior year was mainly attributable to an increase of approximately $45.8 million in maintenance costs, primarily driven by the Chalmette Acquisition in 2015 and general repairs at the Delaware City and Paulsboro refineries, an increase of $17.3 million in employee compensation primarily driven by additional headcount and $14.9 million of increased catalyst and chemicals costs partially offset by net reducedhigher energy and utility costs of $64.4 million due to lower natural gas prices and $4.4 million lower other fixed charges. Our operating expenses principally consist of salaries and employee benefits, maintenance, energy and catalyst and chemicals costs at our refineries. Although operating expenses increased on an overall basis, refinery operating expenses per barrel decreased as a result of higher throughput volumes.natural gas pricing and overall increased throughput. This increase was slightly offset by a decrease in supplies and materials due to our Torrance refinery experiencing higher costs in 2017 related to its turnaround.
General and Administrative Expenses— General and administrative expenses totaled $166.9$253.8 million for the year ended December 31, 2015,2018, compared to $140.2$197.9 million for the year ended December 31, 2014,2017, an increase of $26.7$55.9 million or 19.1%28.2%. The increase in general and administrative expenses primarily relatesfor the year ended December 31, 2018 in comparison to higher employee compensation expense of $13.3 million, mainlythe year ended December 31, 2017 primarily related to higher headcount and higheremployee-related expenses, including incentive compensation expenses, higher outside services fees of $3.0 million related to professional, legal and engineering consultants attributable to the Chalmette Acquisition, and higher equity compensation expense of $1.3 million.retirement benefits. Our general and administrative expenses are comprised of the personnel, facilities and other infrastructure costs necessary to support our refineries.refineries and related logistical assets.
Gain(Gain) loss on Sale of AssetsGain on sale of assets for the year ended December 31, 2015There was $1.0 million which related to the sale of railcars which were subsequently leased back to us, compared to a net gain of $0.9$43.1 million for the year ended December 31, 2014,2018 mainly attributable to a $43.8 million gain related to the Torrance land sale. There was a loss of $1.5 million for the year ended December 31, 2017 relating to the sale of railcars.non-operating refining assets.
Depreciation and Amortization Expense— Depreciation and amortization expense totaled $191.1$340.3 million for the year ended December 31, 2015,2018 (including $329.7 million recorded within Cost of sales), compared to $179.0$267.2 million for the year ended December 31, 2014,2017 (including $254.3 million recorded within Cost of sales), an increase of $12.1$73.1 million. The increase was largely driven bya result of additional depreciation expense associated with a general increase in our increased fixed asset base due to capital projects and turnarounds completed during 20142018 and 2015 as well as2017, which included the acquisition of the Chalmettefirst significant Torrance refinery in 2015. These general increases were partially offset by reduction in impairment charges. In 2014, we recorded a $28.5 million impairment related to an abandoned capital project atturnaround under our Delaware City refinery during that year whereas we did not record any significant impairment charges in the year ended December 31, 2015.ownership.
Change in Fair Value of Catalyst Leases— Change in the fair value of catalyst leases represented a gain of $10.2$5.6 million for the year ended December 31, 2015,2018, compared to a gainloss of $4.0$2.2 million for the year ended December 31, 2014.

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This gain relates2017. These gains and losses relate to the change in value of the precious metals underlying the sale and leaseback of our refineries’ precious metals catalyst,metal catalysts, which we are obligated to return or repurchase at fair market value on the lease termination dates.
Debt extinguishment costs—Debt extinguishment costs of $25.5 million incurred for the year ended December 31, 2017 relate to nonrecurring charges associated with debt refinancing activity calculated based on the difference between the carrying value of the 2020 Senior Secured Notes on the date that they were reacquired and the amount for which they were reacquired. There were no such costs incurred in the year ended December 31, 2018.
Interest Expense, net— Interest expense totaled $88.2$127.1 million for the year ended December 31, 2015,2018, compared to $98.0$122.6 million for the year ended December 31, 2014, a decrease2017, or an increase of $9.8$4.5 million. The decrease is mainly attributable to the termination of our crude and feeedstock supply agreement with MSCG, effective July 31, 2014.slight increase in 2018 was primarily driven by higher borrowing costs. Interest expense includes interest on long-term debt including the Senior Secured Notes and credit facility,notes payable, costs related to the sale and leaseback of our precious metals catalyst, interest expense incurred in connection with our crude and feedstock supply agreement with Statoil up to its expiration on December 31, 2015,metal catalysts, financing costs associated with the Inventory Intermediation Agreements with J. Aron, letter of credit fees associated with the purchase of certain crude oils and the amortization of deferred financing fees.costs.
Income Tax Expense— As PBF Holding iswe are a limited liability company treated as a “flow-through” entity for income tax purposes, our consolidated financial statements generally do not include a benefit or provisionexpense for income taxes for the years ended December 31, 20152018 and 20142017, respectively, apart from the income tax attributable to two subsidiaries acquired in connection with the Chalmette Acquisition in the fourth quarter of Chalmette Refining that2015 and our wholly-owned Canadian subsidiary, PBF Energy Limited (“PBF Ltd”). These subsidiaries are treated as C-Corporations for income tax purposes. An income tax expense of $8.0 million was recorded for the year ended December 31, 2018 in comparison to income tax benefit of $10.8 million recorded for the year ended December 31, 2017 primarily attributable to volatility in the results of our taxable subsidiaries.


20142017 Compared to 20132016
Overview—NetOur net income was $21.1$457.2 million for the year ended December 31, 20142017 compared to $238.9$235.9 million for the year ended December 31, 2013.2016.
Our results for the year ended December 31, 20142017 were negativelypositively impacted by a non-cash special item consisting of ana LCM inventory LCM chargeadjustment of approximately $690.1$295.5 million and a charge related to debt extinguishment costs of $25.5 million related to the retirement of our 2020 Senior Secured Notes. Our results for the year ended December 31, 2016 were positively impacted by a LCM inventory adjustment of approximately $521.3 million. The LCM inventory adjustments were recorded due to a significant declinemovements in the price of crude oil and refined products during the second half of 2014 into early 2015. Our throughput rates during the year ended December 31, 2014 compared to December 31, 2013 were relatively flat. The throughput rates during 2014 in the Mid-Continent were affected by an approximate 40-day plant-wide planned turnaround completed in the fourth quarter of 2014. On January 31, 2013 there was a brief fire within the fluid catalytic cracking complex at the Toledo refinery that resulted in that unit being temporarily shutdown. The refinery resumed running at planned rates on February 18, 2013. During the fourth quarter of 2013, our Delaware City Refinery was impacted by 40-day planned turnaround of the coker unit.periods presented. Excluding the impact of the LCM charge of $690.1 million,these special items, our results for the year ended December 31, 20142017 were positively impacted by higher throughput volumes favorable movementsat the majority of our refineries and higher crack spreads realized at each of our refineries which were impacted by the hurricane-related reduction in certain crude differentialsrefining throughput in the Gulf Coast region and tightening product inventories, specially distillates, in the second half of the year as well as lower costs related to compliancecomply with the RFS partially offset by unfavorable movements in certain product marginsRFS. Notably, we benefited from improved operating performance of our Chalmette and lower crack spreads in the Mid-Continent, higher energy costs and an impairment charge of $28.5 million.Torrance refineries.
Revenues—Revenues totaled $19.8$21.8 billion for the year ended December 31, 20142017 compared to $19.2$15.9 billion for the year ended December 31, 2013,2016, an increase of approximately $0.7$5.9 billion, or 3.5%36.9%. Revenues per barrel were $64.86 and $59.72 for the years ended December 31, 2017 and 2016, respectively, an increase of 8.6% directly related to higher hydrocarbon commodity prices. For the year ended December 31, 2014,2017, the total throughput rates in the East Coast, Mid-Continent, Gulf Coast and Mid-ContinentWest Coast refineries averaged approximately 325,300338,200 bpd, 145,200 bpd, 184,500 bpd and 127,800139,500 bpd, respectively. For the year ended December 31, 2013,2016, the total throughput rates at our East Coast, Mid-Continent and Mid-ContinentGulf Coast refineries averaged approximately 310,300327,000 bpd, 159,100 bpd and 142,500169,300 bpd, respectively. For the period from its acquisition on July 1, 2016 through December 31, 2016, our West Coast refinery’s throughput averaged 143,900 bpd. The increase in throughput rates at our East Coast and Gulf Coast refineries were higher in 20142017 compared to 20132016. Our West Coast refinery was primarily due to higher run rates, favorable economics and planned downtime at our Delaware City refinery in 2013.not acquired until the beginning of the third quarter of 2016. The decrease in throughput rates at our Mid-ContinentWest Coast refinery in 20142017 compared to 2013 was2016 is primarily due to an approximate 40-day plant-wide planned downtime at our Torrance refinery for its first significant turnaround under our ownership, which was completed early in the fourththird quarter of 2014.2017. However, our West Coast refinery throughput averaged 164,000 bpd for the last six months of the year upon completion of the turnaround. For the year ended December 31, 2014,2017, the total refined product barrels sold at our East Coast, Mid-Continent, Gulf Coast and Mid-ContinentWest Coast refineries averaged approximately 350,800363,800 bpd, 160,400 bpd, 227,200 bpd and 144,100168,300 bpd, respectively. For the year ended December 31, 2013,2016, the total refined product barrels sold at our East Coast, Mid-Continent and Mid-ContinentGulf Coast refineries averaged approximately 307,600364,100 bpd, 171,800 bpd and 153,700206,400 bpd, respectively. TotalFor the period from its acquisition on July 1, 2016 through December 31, 2016, the total refined product barrels sold at our Mid-ContinentWest Coast refinery are typicallyaveraged 179,200 bpd. Total refined product barrels sold were higher than throughput rates, reflecting sales from inventory as well as sales and purchases of refined products outside the refinery. Total barrels sold at our East Coast refineries typically reflect inventory movements in addition to throughput rates..
Consolidated Gross Margin— Consolidated gross margin totaled $795.9 million, or $2.70 per barrel of throughput, for the year ended December 31, 2017, compared to $549.3 million, or $2.06 per barrel of throughput, for the year ended December 31, 2016, an increase of $246.6 million. Gross refining margin (as defined below in Non-GAAP Financial Measures) totaled $1,314.1$2,676.7 million, or $7.94$9.08 per barrel of throughput, or ($2,004.22,381.1 million or $12.11$8.08 per barrel of throughput excluding the impact of special items) for the year ended December 31, 20142017 compared to $1,348.1$2,143.4 million, or $8.16$8.05 per barrel of throughput ($1,622.1 million, or $6.09 per barrel of throughput excluding the impact of special items) for the year ended December 31, 2016, an increase of approximately $533.2 million or an increase of approximately of $759.0 million excluding special items.
Consolidated gross margin and gross refining margin increased due to improved crack spreads across each of our refineries, reduced costs to comply with the RFS and positive margin contributions from our Torrance refinery following its first significant turnaround under our ownership, which was completed early in the third quarter of 2017. Costs to comply with our obligation under the RFS totaled $255.2 million for the year ended December 31, 2017 (excluding our West Coast refinery, whose cost to comply with RFS totaled $38.5 million for the year ended December 31, 2017) compared to $325.3 million for the year ended December 31, 2016 (excluding our West Coast refinery, whose costs to comply with RFS totaled $22.2 million for the year ended December 31, 2016). In addition, gross margin and gross refining margin were positively impacted by a non-cash LCM inventory adjustment of approximately $295.5 million on a net basis resulting from an increase in crude oil and refined product prices in comparison to the prices at the end of 2016. The non-cash LCM inventory adjustment increased consolidated gross margin and gross refining margin by approximately $521.3 million in the year ended December 31, 2016.


Average industry refining margins in the Mid-Continent were stronger during the year ended December 31, 2013. Gross margin, including2017, as compared to the same period in 2016. The WTI (Chicago) 4-3-1 industry crack spread was $15.88 per barrel or 28.3% higher, in the year ended December 31, 2017, as compared to $12.38 per barrel in the same period in 2016. Our margins were unfavorably impacted by our refinery operatingspecific crude slate in the Mid-Continent which was impacted by a declining WTI/Bakken differential partially offset by an improving WTI/Syncrude differential, which averaged a premium of $1.74 per barrel for the year ended December 31, 2017 as compared to a premium of $2.01 per barrel in the same period in 2016.
On the East Coast, the Dated Brent (NYH) 2-1-1 industry crack spread was approximately $14.74 per barrel, or 9.3% higher, in the year ended December 31, 2017 as compared to $13.49 per barrel in the same period in 2016. The Dated Brent/WTI differential was $2.83 higher in the year ended December 31, 2017, as compared to the same period in 2016, partially offset by year over year decreases in the Dated Brent/Maya differential and WTI/Bakken differential of $0.20 and $1.58, respectively.
Gulf Coast industry refining margins improved during the year ended December 31, 2017 as compared to the same period in 2016. The LLS (Gulf Coast) 2-1-1 industry crack spread was $13.57 per barrel, or 26.2% higher, in the year ended December 31, 2017 as compared to $10.75 per barrel in the same period in 2016. Crude differentials weakened with the WTI/LLS differential averaging a premium of $3.23 per barrel during the year ended December 31, 2017 as compared to a premium of $1.69 per barrel in the same period of 2016.
Additionally, we benefited from improvements in the West Coast industry refining margins during the year ended December 31, 2017 as compared to the same period in 2016. The ANS (West Coast) 4-3-1 industry crack spread was $17.43 per barrel, or 5.9% higher, in the year ended December 31, 2017 as compared to $16.46 per barrel in the same period in 2016. Partially offsetting the improved crack spreads, crude differentials weakened with the WTI/ANS differential averaging a premium of $3.63 per barrel during the year ended December 31, 2017 as compared to a premium of $0.33 per barrel in the same period of 2016. As the Torrance refinery was not acquired until the beginning of the third quarter of 2016, we did not benefit from the contribution of this refinery for the full twelve months of the prior year.
Favorable movements in these benchmark crude differentials typically result in lower crude costs and positively impact our earnings, while reductions in these benchmark crude differentials typically result in higher crude costs and negatively impact our earnings.
Operating Expenses— Operating expenses and depreciation, totaled $268.0$1,626.4 million, or $1.60$5.52 per barrel of throughput, for the year ended December 31, 2014,2017 compared to $436.9$1,390.1 million, or $2.64$5.22 per barrel of throughput, for the year ended December 31, 2013, a decrease2016, an increase of $168.9 million. Excluding the impact of special items, gross margin and gross refining margin increased due to higher throughput rates, favorable movements$236.3 million, or 17.0%. The increase in certain crude differentials and lower costs of compliance with RFS. Gross margin and gross refining margin were impacted by a non-cash LCM charge of approximately $690.1 million resulting from the significant decrease in crude oil and refined product prices during the second half of 2014 into early 2015.

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Average industry refining margins in the U.S. Mid-Continent were generally weaker during the year ended December 31, 2014, as comparedoperating expenses was mainly attributable to the same periodoperating expenses associated with our Torrance refinery and related logistics assets, which were included in 2013. The WTI (Chicago) 4-3-1 industry crack spread was approximately $15.92 per barrel or 20.8% lower in the year ended December 31, 2014, as compared to the same period in 2013. While the price of WTI versus Dated Brent and other crude discounts narrowed during the year ended December 31, 2014, our refinery specific crude slate in the Mid-Continent benefited from an improving WTI/Syncrude differential, which averaged a discount of $2.25 per barrelresults for the year ended December 31, 20142017 as compared to $0.63 per barrel in the same period in 2013.
The Dated Brent (NYH) 2-1-1 industry crack spread was approximately $12.92 per barrel, or 4.7%, higher inwith only six months of 2016. For the year ended December 31, 2014, as compared2017 the Torrance refinery and related logistics assets incurred operating expenses of approximately $475.9 million in comparison to $250.5 million for the same period in 2013. While the WTI/Dated Brent differential was $5.01 lower in the year endedfrom its acquisition on July 1, 2016 to December 31, 2014, as compared to the same period in 2013, the WTI/Bakken differential was $0.35 per barrel more favorable for the same periods. The Dated Brent/Maya differential was approximately $1.7 per barrel more favorable in the year ended December 31, 2014 as compared to the same period in 2013. While a decrease in the WTI/Dated Brent crude differential can unfavorably impact our East Coast refineries, we significantly increased our shipments of rail-delivered WTI-based crudes from the Bakken and Western Canada, which had the overall effect of reducing the cost of crude oil processed2016. Total operating expenses at our East Coast refineries, and increasingexcluding our gross refining margin and gross margin. Additionally, the increase in the Dated Brent/Maya crude differential, our proxy for the light/heavy crude differential, had a positive impact on our East Coast refineries, which can process a large slate of medium and heavy, sour crude oil that is priced at a discount to light, sweet crude oil.
Operating Expenses—Operating expenses totaled $880.7 million, or $5.34 per barrel of throughput,Torrance refinery, increased slightly for the year ended December 31, 2014 compared2017, primarily due to $812.7 million, or $4.92 per barrel of throughput, for the year ended December 31, 2013, an increase of $68.0 million, or 8.4%.higher energy costs and maintenance costs. The increase in operating expenses isenergy costs was mainly attributabledue to an increase of approximately $42.7 million in energy and utilities costs, primarily driven by higher natural gas prices $13.7 millionwhile the increase in increased personnelmaintenance costs and $1.9 million in higher outside engineering and consulting fees relatedwas mainly due to refinery capital and maintenance projects. Our operating expenses principally consisttiming of salaries and employee benefits, maintenance, energy and catalyst and chemicals costs at our refineries.repairs.
General and Administrative Expenses—General and administrative expenses totaled $140.2$197.9 million for the year ended December 31, 2014,2017, compared to $95.8$149.5 million for the year ended December 31, 20132017, an increase of $44.4$48.4 million or 46.3%32.4%. The The increase in general and administrative expenses primarily relates to higherincreased employee compensation expenserelated expenses of $43.5$58.2 million mainly related to increases indriven by higher incentive compensation costs in the year ended December 31, 2017 as compared to the same period in 2016, attributable to higher average employee headcount and severance costs.better operating performance. These increases were partially offset by lower costs associated with acquisition and integration related activities which were approximately $8.6 million lower in the year ended December 31, 2017 as compared to the same period in 2016. Our general and administrative expenses are comprised of the personnel, facilities and other infrastructure costs necessary to support our refineries.refineries and related logistical assets.
GainLoss (gain) on Sale of AssetsGainThere was a loss of $1.5 million on the sale of assets for the year ended December 31, 2014 was $0.9 million which related2017 relating to the sale of railcars which were subsequently leased back to us, compared tonon-refining assets. There was a gainloss of $0.2$11.4 million for the year ended December 31, 2013, for2016 related to the sale of railcars.non- operating refining assets.
Depreciation and Amortization Expense—Depreciation and amortization expense totaled $179.0$267.2 million for the year ended December 31, 2014,2017 ( including $254.3 million recorded within Cost of sales), compared to $111.5$209.8 million for the year ended December 31, 2013,2016 ( including $204.0 million recorded within Cost of sales), an increase of $67.5$57.4 million. The increase was impacted by an impairment chargea result of $28.5 million related to an abandoned capital project atadditional depreciation expense associated with the assets acquired in the Torrance Acquisition and a general increase in our Delaware City refinery during the year ended December 31, 2014. In addition, the increase isfixed asset base due to capital projects and turnarounds completed during the year including the expansion of crude rail infrastructure. We also completed turnarounds in late 2013since 2017 and early 2014 and other refinery optimization projects at Toledo.2016.


Change in Fair Value of Catalyst Leases— Change in the fair value of catalyst leases represented a gain of $4.0$2.2 million for the year ended December 31, 2014,2017, compared to a gain of $4.7$1.4 million for the year ended December 31, 2013. The2016. This gain relates to the change in value of the precious metals underlying the sale and leaseback of our refineries’ precious metals catalyst,metal catalysts, which we are obligated to return or repurchase at fair market value on the lease termination dates.
Debt extinguishment costs— Debt extinguishment costs of $25.5 million incurred in the year ended December 31, 2017 relate to nonrecurring charges associated with debt refinancing activity calculated based on the difference between the carrying value of the 2020 Senior Secured Notes on the date that they were reacquired and the amount for which they were reacquired. There were no such costs in the same period of 2016.
Interest Expense, net— Interest expense totaled $98.0$122.6 million for the year ended December 31, 2014,2017, compared to $94.2$129.5 million for the year ended December 31, 2013, an increase2016, a decrease of $3.8$6.9 million. The increase inThis net decrease is attributable to lower interest expense is primarily dueon a portion of our senior notes that were refinanced in May 2017 (see “Note 8 - Credit Facility and Debt” of our Notes to Consolidated Financial Statements, for additional details) and lower interest costs related to the affiliate notes payable partially offset by higher letter of credit fees.average borrowings under our Revolving Credit Facility. Interest expense includes interest on long-term debt, costs related to the sale and leaseback of our precious metals catalyst, interest expense incurred in connection with our crude and feedstock supply agreements with Statoil and MSCG,metal catalysts, financing costcosts associated with the Inventory Intermediation Agreements with J. Aron, letter of credit fees associated with the purchase of certain crude oils, and the amortization of deferred financing fees.costs.
Income Tax Expense— As PBF Holding iswe are a limited liability company treated as a “flow-through” entity for income tax purposes our consolidated financial statements generally do not include a benefit or provisionexpense for income taxes for the years ended December 31, 20142017 and 2013.2016 respectively, apart from the income tax attributable to two subsidiaries acquired in connection with the Chalmette Acquisition in the fourth quarter of 2015 and PBF Ltd. These subsidiaries are treated as C-Corporations for income tax purposes. An income tax benefit of $10.8 million was recorded for the year ended December 31, 2017 in comparison to income tax expense of $23.7 million recorded for the year ended December 31, 2016. Income tax expense for the year ended December 31, 2016 included a charge of $30.7 million related to a correction of prior periods.

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Non-GAAP Financial Measures
Management uses certain financial measures to evaluate our operating performance that are calculated and presented on the basis of methodologies other than in accordance with GAAP (“Non-GAAP”). These measures should not be considered a substitute for, or superior to, measures of financial performance prepared in accordance with GAAP, and our calculations thereof may not be comparable to similarly entitled measures reported by other companies.
Special Items
The non-GAAPNon-GAAP measures presented include EBITDA excluding special items and gross refining margin excluding special items. The specialSpecial items presented for the year ended December 31, 2018 relate to an LCM inventory adjustment, gain on the sale of assets related to the Torrance land sale and charges associated with the early return of certain leased railcars. Special items for the periods presentedyear ended December 31, 2017 relate to a LCM adjustment. LCM is a GAAP guideline related to inventory valuation that requires inventory to be stated at the lower of cost or market. Our inventories are stated at the lower of cost or market. Cost is determined by the last-in, first-out (“LIFO”) inventory valuation methodology, in which the most recently incurred costs are charged to cost of sales and inventories are valued at base layer acquisition costs. Market is determined based on an assessment of the current estimated replacement cost and net realizable selling price of the inventory. In periods where the market price of our inventory declines substantially, cost values of inventory may exceed market values. In such instances, we record an adjustment to write-down the value of inventory to market value in accordance with the GAAP. In the subsequent periods, the value of the inventory is reassessed and a LCM adjustment is recorded to reflect the net change in the LCM inventory reserve between the prior periodadjustment and the current period.debt extinguishment costs. See “Notes to Non-GAAP Financial Measures” below for more details on all special items disclosed. Although we believe that non-GAAPNon-GAAP financial measures, excluding the impact of special items, provide useful supplemental information to investors regarding the results and performance of our business and allow for more usefulhelpful period-over-period comparisons, such non-GAAPNon-GAAP measures should only be considered as a supplement to, and not as a substitute for, or superior to, the financial measures prepared in accordance with GAAP.
Gross Refining Margin and Gross Refining Margin Excluding Special Items
Gross refining margin is defined as consolidated gross margin excluding depreciation and operating expense related to the refineries. We believe both gross refining margin is anand gross refining margin excluding special items are important measuremeasures of operating performance and providesprovide useful information to investors because it is a betterthey are helpful metric comparison forcomparisons to the industry refining margin benchmarks, as the refining margin benchmarks do not include a charge for depreciation expense.refinery operating expenses and depreciation. In order to assess our operating performance, we compare our gross refining margin (revenue less cost of sales)products and other) to industry refining margin benchmarks and crude oil prices as describeddefined in the table above.below.
GrossNeither gross refining margin nor gross refining margin excluding special items should not be considered an alternative to consolidated gross margin, operating income from operations, net cash flows from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Gross refining margin and gross refining margin excluding special items presented by other companies may not be comparable to our presentation, since each company may define this termthese terms differently.


The following table presents our GAAP calculation of gross margin and a reconciliation of gross refining margin to the most directly comparable GAAP financial measure, consolidated gross margin, on a historical basis, as applicable, for each of the periods indicated:indicated (in thousands, except per barrel amounts):

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  Year Ended December 31,
  2015 2014 2013
  $per barrel of throughput $per barrel of throughput $per barrel of throughput
Reconciliation of gross margin to gross refining margin:         
Gross margin $441,539
$2.34
 $267,987
$1.60
 $436,867
$2.64
Add: Operating expense 889,368
4.72
 880,701
5.34
 812,652
4.92
Add: Refinery depreciation expense 181,423
0.96
 165,413
1.00
 98,622
0.60
Gross refining margin $1,512,330
$8.02
 $1,314,101
$7.94
 $1,348,141
$8.16
Special items:         
Less: Non-cash LCM inventory adjustment (1) 427,226
2.27
 690,110
4.17
 

Gross refining margin excluding special items $1,939,556
$10.29
 $2,004,211
$12.11
 $1,348,141
$8.16
(1) During the year ended December 31, 2015, the Company recorded an adjustment to value its inventory to the lower of cost or market, which resulted in a net impact of $427.2 million reflecting the change in the lower of cost or market inventory reserve from $690.1 million at December 31, 2014 to $1,117.3 million at December 31, 2015. During the year December 31, 2014, the Company recorded an adjustment to value its inventory to the lower of cost or market which resulted in a net impact of $690.1 million. The net impact of the LCM inventory adjustments are included in the operating income, but are excluded from the operating results presented in the table in order to make such information comparable between periods.
  Year Ended December 31,
  2018 2017 2016
  $per barrel of throughput $per barrel of throughput $per barrel of throughput
Calculation of consolidated gross margin:         
Revenues $27,164,008
$87.60
 $21,772,478
$73.88
 $15,908,537
$59.72
Less: Cost of Sales 26,729,077
86.21
 20,976,538
71.18
 15,359,228
57.66
Consolidated gross margin $434,931
$1.39
 $795,940
$2.70
 $549,309
$2.06
Reconciliation of consolidated gross margin to gross refining margin:         
Consolidated gross margin $434,931
$1.39
 $795,940
$2.70
 $549,309
$2.06
Add: Refinery operating expense 1,654,749
5.34
 1,626,440
5.52
 1,390,135
5.22
Add: Refinery depreciation expense 329,709
1.06
 254,271
0.86
 $204,0050.77
Gross refining margin $2,419,389
$7.79
 $2,676,651
$9.08
 $2,143,449
$8.05
Special items: (1)
         
Add: Non-cash LCM inventory adjustment 351,278
1.13
 (295,532)(1.00) (521,348)(1.96)
Add: Early railcar return expense 52,313
0.17



 

Gross refining margin excluding special items $2,822,980
$9.09
 $2,381,119
$8.08
 $1,622,101
$6.09
——————————
See Notes to Non-GAAP Financial Measures.
EBITDA, EBITDA Excluding Special Items and Adjusted EBITDA
Our management uses EBITDA (earnings before interest, income taxes, depreciation and amortization), EBITDA excluding special items and Adjusted EBITDA as measures of operating performance to assist in comparing performance from period to period on a consistent basis and to readily view operating trends, as a measure for planning and forecasting overall expectations and for evaluating actual results against such expectations, and in communications with our board of directors, creditors, analysts and investors concerning our financial performance. Our outstanding indebtedness for borrowed money and other contractual obligations also include similar measures as a basis for certain covenants under those agreements which may differ from the Adjusted EBITDA definition described below.
EBITDA, EBITDA excluding special items and Adjusted EBITDA are not presentations made in accordance with GAAP and our computation of EBITDA, EBITDA excluding special items and Adjusted EBITDA may vary from others in our industry. In addition, Adjusted EBITDA contains some, but not all, adjustments that are taken into account in the calculation of the components of various covenants in the agreements governing the Senior Secured Notesour senior notes and other credit facilities. EBITDA, EBITDA excluding special items and Adjusted EBITDA should not be considered as alternatives to operating income from operations or net income (loss) as measures of operating performance. In addition, EBITDA, EBITDA excluding special items and Adjusted EBITDA are not presented as, and should not be considered, an alternative to cash flows from operations as a measure of liquidity. Adjusted EBITDA is defined as EBITDA before equity-basedadjustments for items such as stock-based compensation expense, gains (losses) from certain derivative activities and contingent consideration, the non-cash change in the deferralfair value of gross profit related to the sale of certain finished products andcatalyst leases, the write down of inventory to the LCM. LCM, debt extinguishment costs related to refinancing activities and certain other non-cash items.


Other companies, including other companies in our industry, may calculate EBITDA, EBITDA excluding special items and Adjusted EBITDA differently than we do, limiting itstheir usefulness as a comparative measure.measures. EBITDA, EBITDA excluding special items and Adjusted EBITDA also hashave limitations as an analytical tooltools and should not be considered in isolation, or as a substitute for analysis of our results as reported under GAAP. Some of these limitations include that EBITDA, EBITDA excluding special items and Adjusted EBITDA:
doesdo not reflect depreciation expense or our cash expenditures, or future requirements, for capital expenditures or contractual commitments;
doesdo not reflect changes in, or cash requirements for, our working capital needs;
doesdo not reflect our interest expense, or the cash requirements necessary to service interest or principal payments, on our debt;
doesdo not reflect realized and unrealized gains and losses from certain hedging activities, which may have a substantial impact on our cash flow;
doesdo not reflect certain other non-cash income and expenses; and
excludesexclude income taxes that may represent a reduction in available cash.

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The following tables reconcile net income as reflected in our results of operations to EBITDA, EBITDA excluding special items and Adjusted EBITDA for the periods presented:presented (in thousands): 
 Year Ended December 31, Year Ended December 31,
 2015 2014 2013 2018 2017 2016
      
Reconciliation of net income to EBITDA:     
Reconciliation of Net income to EBITDA and EBITDA excluding special items:Reconciliation of Net income to EBITDA and EBITDA excluding special items:     
Net incomeNet income$187,294
 $21,117
 $238,876
Net income$102,944
 $457,200
 $235,886
Add: Depreciation and amortization expenseAdd: Depreciation and amortization expense191,110
 178,996
 111,479
Add: Depreciation and amortization expense340,343
 267,235
 209,840
Add: Interest expense, netAdd: Interest expense, net88,194
 98,001
 94,214
Add: Interest expense, net127,129
 122,628
 129,536
Add: Income tax expense (benefit)Add: Income tax expense (benefit)648
 
 
Add: Income tax expense (benefit)7,999
 (10,783) 23,689
EBITDAEBITDA$467,246
 $298,114
 $444,569
EBITDA$578,415
 $836,280
 $598,951
Special Items:     
Add: Non-cash LCM inventory adjustment (1)427,226
 690,110
 
Special Items: (1)
Special Items: (1)
     
Add: Non-cash LCM inventory adjustmentAdd: Non-cash LCM inventory adjustment351,278
 (295,532) (521,348)
Add: Debt extinguishment costsAdd: Debt extinguishment costs
 25,451
 
Add: Gain on Torrance land saleAdd: Gain on Torrance land sale(43,761) 
 
Add: Early railcar return expenseAdd: Early railcar return expense52,313
 
 
EBITDA excluding special itemsEBITDA excluding special items$894,472
 $988,224
 $444,569
EBITDA excluding special items$938,245
 $566,199
 $77,603
            
Reconciliation of EBITDA to Adjusted EBITDA:Reconciliation of EBITDA to Adjusted EBITDA:     Reconciliation of EBITDA to Adjusted EBITDA:     
EBITDAEBITDA$467,246
 $298,114
 $444,569
EBITDA$578,415
 $836,280
 $598,951
Add: Stock based compensationAdd: Stock based compensation9,218
 6,095
 3,753
Add: Stock based compensation20,212
 21,503
 18,296
Add: LCM adjustment427,226
 690,110
 
Add: Non-cash change in fair value of catalyst lease obligations(10,184) (3,969) (4,691)
Add: Non-cash change in fair value of inventory repurchase
obligations

 
 (12,985)
Add: Non-cash deferral of gross profit on
finished product sales

 
 (31,329)
Add: Non-cash change in fair value of catalyst leasesAdd: Non-cash change in fair value of catalyst leases(5,587) 2,247
 (1,422)
Add: Non-cash LCM inventory adjustment (1)
Add: Non-cash LCM inventory adjustment (1)
351,278
 (295,532) (521,348)
Add: Debt extinguishment costs (1)
Add: Debt extinguishment costs (1)

 25,451
 
Adjusted EBITDAAdjusted EBITDA$893,506
 $990,350
 $399,317
Adjusted EBITDA$944,318
 $589,949
 $94,477
(1) During the year ended December 31, 2015, the Company recorded an adjustment to value its inventory to the lower of cost or market, which resulted in a net impact of $427.2 million reflecting the change in the lower of cost or market inventory reserve from $690.1 million at December 31, 2014 to $1,117.3 million at December 31, 2015. During the year December 31, 2014, the Company recorded an adjustment to value its inventory to the lower of cost or market which resulted in a net impact of $690.1 million. The net impact of the LCM inventory adjustments are included in the operating income, but are excluded from the operating results presented in the table in order to make such information comparable between periods.

——————————
See Notes to Non-GAAP Financial Measures.



Notes to Non-GAAP Financial Measures
The following notes are applicable to the Non-GAAP Financial Measures above:
(1)Special items:
LCM inventory adjustment - LCM is a GAAP requirement related to inventory valuation that mandates inventory to be stated at the lower of cost or market. Our inventories are stated at the lower of cost or market. Cost is determined using the last-in, first-out (“LIFO”) inventory valuation methodology, in which the most recently incurred costs are charged to cost of sales and inventories are valued at base layer acquisition costs. Market is determined based on an assessment of the current estimated replacement cost and net realizable selling price of the inventory. In periods where the market price of our inventory declines substantially, cost values of inventory may exceed market values. In such instances, we record an adjustment to write down the value of inventory to market value in accordance with GAAP. In subsequent periods, the value of inventory is reassessed and an LCM inventory adjustment is recorded to reflect the net change in the LCM inventory reserve between the prior period and the current period. The net impact of these LCM inventory adjustments are included in income from operations, but are excluded from the operating results presented in the table below in order to make such information comparable between periods.
The following table includes the lower of cost or market inventory reserve as of each date presented (in thousands):
 2018 2017 2016
January 1,$300,456
 $595,988
 $1,117,336
December 31,651,734
 300,456
 595,988
    

The following table includes the corresponding impact of changes in the LCM inventory reserve on both income from operations and net income for the periods presented (in thousands):
63

 Year Ended December 31,
 2018 2017 2016
Net LCM inventory adjustment (charge) benefit in both income from operations and net income$(351,278) $295,532
 $521,348
Gain on Torrance land sale - During the year ended December 31, 2018 we recorded a gain on the sale of a parcel of real property acquired as part of the Torrance refinery, but not part of the refinery itself. The gain increased income from operations and net income by $43.8 million. There was no such gain in the years ended December 31, 2017 and December 31, 2016.

Early Return of Railcars - During the year ended December 31, 2018 we recognized certain expenses within Cost of sales associated with the voluntary early return of certain leased railcars. These charges decreased income from operations and net income by $52.3 million. There were no such expenses in the years ended December 31, 2017 and December 31, 2016.

Debt Extinguishment Costs - During the year ended December 31, 2017, we recorded debt extinguishment costs of $25.5 million related to the redemption of the 2020 Senior Secured Notes. There were no such costs in the years ended December 31, 2018 and December 31, 2016.

Liquidity and Capital Resources
Overview
Our primary sourcesources of liquidity isare our cash flows from operations and borrowing availability under our credit facilities, as more fully described below. We believe that our cash flows from operations and available capital resources will be sufficient to meet our and our subsidiariessubsidiaries’ capital expenditure, working capital needs, distribution payments and debt service requirements for the next twelve months. We expect to finance the planned Torrance Acquisition with a combination of cash on hand and proceeds from our 2023 Senior Secured Notes offering. However, our ability to generate sufficient cash flowflows from operations depends, in part, on petroleum oil market pricing and general economic, political and other factors beyond our control. We believe we could, during periods of economic downturn, access the capital markets and/or other available financial resources or reduce our capital and discretionary expenditure plans to strengthen our financial position. We are in compliance as of December 31, 2018 with all of the covenants, including financial covenants, forin all of our debt agreements.


Cash Flow Analysis
Cash Flows from Operating Activities
Net cash provided by operating activities was $652.4$695.0 million for the year ended December 31, 20152018 compared to net cash provided by operating activities of $495.7$471.1 million for the year ended December 31, 2014.2017. Our operating cash flows for the year ended December 31, 20152018 included our net income of $187.3 million, plus net non-cash charges relating to an LCM adjustment of $427.2$102.9 million, depreciation and amortization of $199.4$346.7 million, a non-cash charge of $351.3 million relating to an LCM inventory adjustment, pension and other post-retirement benefits costs of $47.4 million, stock-based compensation of $20.2 million, deferred income taxes of $7.2 million and distributions from our equity method investment in TVPC of $17.8 million, partially offset by a gain on sale of assets of $43.1 million, the change in the fair value of our inventory repurchase obligations of $31.8 million, income from our equity method investment in TVPC of $17.8 million and changes in the fair value of our catalyst leases of $5.6 million. In addition, net changes in operating assets and liabilities reflected uses of cash of $100.3 million driven by the timing of inventory purchases, payments for accrued expenses and accounts payable and collections of accounts receivable. Our operating cash flows for the year ended December 31, 2017 included our net income of $457.2 million, depreciation and amortization of $274.7 million, pension and other post-retirement benefits costs of $42.2 million, debt extinguishment costs of $25.5 million, equity-based compensation of $21.5 million, change in the fair value of our inventory repurchase obligations of $63.4$13.8 million, pension and other post retirement benefits costs$5.7 million of $27.0 million, and stock-based compensationnet distributions received in excess of $9.2 million, partially offset by theincome from our equity method investment in TVPC, changes in the fair value of our catalyst leaseleases of $10.2$2.2 million and gainloss on sale of assets of $1.0$1.5 million, partially offset by non-cash benefit of $295.5 million relating to an LCM inventory adjustment and deferred income taxes of $12.5 million. In addition, net changes in working capitaloperating assets and liabilities reflected uses of cash of $249.9$65.1 million driven by the timing of inventory purchases, payments for accrued expenses and accounts payable and collections of accounts receivables.receivable.
Net cash provided by operating activities was $471.1 million for the year ended December 31, 2017 compared to net cash provided by operating activities of $551.6 million for the year ended December 31, 2016. Our operating cash flows for the year ended December 31, 20142016 included our net income of $21.1 million, plus net non-cash charges relating to an LCM adjustment of $690.1$235.9 million, depreciation and amortization of $186.4$218.9 million, pension and other post retirement benefits costs of $22.6 million, and stock-based compensation of $6.1 million, partially offset by the change in the fair value of our inventory repurchase obligations of $93.2$29.5 million, pension and other post-retirement benefits costs of $38.0 million, deferred income taxes of $19.8 million, equity-based compensation of $18.3 million, a loss on sale of assets of $11.4 million, partially offset by net non-cash benefit relating to an LCM inventory adjustment of $521.3 million, equity income from our investment in TVPC of $5.7 million and changes in the fair value of our catalyst leaseleases of $4.0 million, and gain on sales of assets of $0.9$1.4 million. In addition, net changes in working capitaloperating assets and liabilities reflected usessources of cash of $332.5approximately $508.3 million driven by the timing of inventory purchases, payments for accrued expenses and accounts payable and collections of accounts receivables as well as payments associated with the terminations of the MSCG offtake and Statoil supply agreements.
Net cash provided by operating activities was $495.7 million for the year ended December 31, 2014 compared to net cash provided by operating activities of $311.3 million for the year ended December 31, 2013. Our operating cash flows for the year ended December 31, 2013 included our net income of $238.9 million, plus net non-cash charges relating to depreciation and amortization of $118.0 million, pension and other post retirement benefits of $16.7 million and stock-based compensation of $3.8 million, partially offset by the change in the fair value of our inventory repurchase obligations of $20.5 million, change in the fair value of our catalyst lease of $4.7 million, and gain on sales of assets of $0.2 million. In addition, net changes in working capital reflected uses of cash of $40.7 million in cash driven by increases in hydrocarbon purchases and sales volumes and their associated impact on inventory, accounts receivable, and hydrocarbon-related liabilities.receivable.
Cash Flows from Investing Activities
Net cash used in investing activities was $811.2$509.6 million for the year ended December 31, 20152018 compared to net cash used in investing activities of $422.7$641.6 million for the year ended December 31, 2014.2017. The net cash flows used in investing activities for the year ended December 31, 20152018 was comprised of $565.3 million used in the acquisition of the Chalemette refinery, capital expenditures totaling $352.4$277.3 million, expenditures for turnarounds of $53.6$266.0 million, and expenditures for other assets of $8.2$17.1 million, partially offset by $168.3proceeds of $48.3 million related to the Torrance land sale and a $2.4 million return of capital from our equity method investment in proceeds from the sale of railcars.TVPC. The net cash flows used in investing activities for the year ended December 31, 20142017 was comprised of capital expenditures totaling $470.5$232.7 million, expenditures for turnarounds of $137.7$379.1 million, and expenditures for other assets of $17.3$31.1 million, partially offset by $202.7a $1.3 million return of capital from our equity method investment in proceeds from the sale of assets.TVPC.
Net cash used in investing activities was $422.7$641.6 million for the year ended December 31, 20142017 compared to net cash used in investing activities of $313.3$1,473.5 million for the year ended December 31, 2013. Net2016. The net cash used in investing activities for the year ended December 31, 20132016 was comprised of cash outflows of $971.9 million used to fund the Torrance Acquisition, capital expenditures totaling $318.4$282.4 million, expenditures for turnarounds of $64.6$198.7 million, primarily at our Toledo refinery and expenditures for other assets of $32.7$42.5 million slightlyand the final working capital settlement related to the acquisition of the Chalmette refinery of $2.7 million, partially offset by $102.4$24.7 million in proceeds from the sale of assets.

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Cash Flows from Financing Activities
Net cash provided byused in financing activities was $855.2$149.8 million for the year ended December 31, 20152018 compared to net cash usedprovided by financial activities of $68.5$70.0 million for the year ended December 31, 2014.2017. For the year ended December 31, 2015,2018, net cash used in financing activities consisted primarily of net repayments of our Revolving Credit Facility of $350.0 million, distributions to members of $52.6 million, principal amortization payments of the PBF Rail Term Loan of $6.8 million, repayments of our note payable of $5.6 million, settlements of precious metal catalyst leases of $9.1 million and deferred financing costs and other of $12.7 million, partially offset by a contribution from our parent


of $287.0 million. For the year ended December 31, 2017, net cash provided by financing activities consisted primarily of $500.0a contribution from our parent of $97.0 million, inpayments received from affiliate notes receivable of $11.6 million, settlements of precious metal catalyst leases of $10.8 million and cash proceeds of $21.4 million from the 2023issuance of the 2025 Senior Notes net of cash paid to redeem the 2020 Senior Secured Notes, capital contributions of $345.0 million, proceeds from intercompany note payable of $347.8 million, and net proceeds from the Rail Facility of $30.1 million, partially offset by distributions to members of $350.7$61.1 million, distributions to T&M and Collins shareholders of $1.8 million, payments of principal under the PBF Rail Term Loan of $6.6 million and $17.1repayments of our note payable of $1.2 million. Additionally, during the year ended December 31, 2017, we borrowed and repaid $490.0 million under our Revolving Credit Facility resulting in no net change to amounts outstanding for the year ended December 31, 2017.
Net cash provided by financing activities was $70.0 million for deferredthe year ended December 31, 2017 compared to net cash provided by financing costs and other.activities of $633.8 million for the year ended December 31, 2016. For the year ended December 31, 2014,2016, net cash provided by financing activities consisted primarily of capital contributions of distributions of $328.7 million, proceeds from intercompany notes payable of $90.6 million, net proceeds from the RailRevolving Credit Facility of $37.3$350.0 million, a contribution from our parent of $450.3 million, proceeds from the PBF Rail Term Loan of $35.0 million and settlements of precious metal catalyst leases of $15.6 million, partially offset by distribution to members of $361.4$139.4 million, repayments of the Rail Facility of $67.5 million and net repayments of the Revolving Loan of $15.0 million and $11.7 million for deferred financing costs and other.
Net cash provided by financing activities was $68.5 million for the year ended December 31, 2014 compared to net cash used in financing activities of $175.3 million for the year ended December 31, 2013. For the year ended December 31, 2013, net cash used in financing activities consisted primarily of distributions of $215.8 million, payments of contingent consideration related to the Toledo acquisition of $21.4 million and $1.0 million for deferred financing costs and other, partially offset by $31.8 million of proceeds from intercompanyaffiliate notes payable $15.0 million of net proceeds from revolver borrowings, $14.3 million in proceeds from sale of catalyst, and $1.8 million of proceeds from members'$10.1 million.
Capitalization
Our capital contributions.
Senior Secured Notes
On February 9, 2012, PBF Holding and its wholly-owned subsidiary, PBF Finance Corporation, issued an aggregate principal amount of $675.5 millionstructure was comprised of the 2020 Senior Secured Notes. The net proceeds from the offering of approximately $665.8 million were used to repay our Paulsboro Promissory Note in the amount of $150.6 million, our Term Loan Facility in the amount of $123.8 million, our Toledo Promissory Note in the amount of $181.7 million, and to reduce indebtedness under the Revolving Loan.
On November 24, 2015, PBF Holding and PBF Finance Corporation issued $500.0 million in aggregate principal amount of the 2023 Senior Secured Notes. The net proceeds were approximately $490.0 million after deducting the initial purchasers’ discount and estimated offering expenses. The Company intends to use the proceeds for general corporate purposes, including to fund a portion of the purchase price for the pending acquisition of the Torrance refinery and related logistics assets.
The Senior Secured Notes are our senior obligations and payment is jointly and severally guaranteed on a senior secured basis by certain of our subsidiaries representing substantially all of our present assets. The 2020 Senior Secured Notes are, and the 2023 Senior Secured Notes are initially, secured, subject to certain exceptions and permitted liens, on a first-priority basis by substantially all of the present and future assets of the Company and its subsidiaries (other than assets securing the Revolving Loan), which also constitute collateral securing certain hedging obligations and any existing or future indebtedness which is permitted to be secured on a pari passu basis with the Senior Secured Notes to the extent of the value of the collateral.
At all times after (a) a covenant suspension event (which requires that the 2023 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, the 2023 Senior Secured Notes will become unsecured. A “Collateral Fall-Away Event” is defined as the first day on which the 2020 Notes are no longer secured by Liens on the Collateral, whether as a result of having been repaid in full or otherwise satisfied or discharged or as a result of such Liens being released in accordance with definitive documentation governing the 2020 Senior Secured Notes; provided that a Collateral Fall-Away Event shall not occur to the extent any Additional First Lien Obligations (other than Specified Secured Hedging Obligations) are outstanding at such time (capitalized terms not otherwise defined herein having the meaning set forth in the indenture governing the 2023 Senior Secured Notes).
The Company 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 indentures. The indentures contain customary terms, events of default and covenants for an issuer of non-investment grade debt securities. These covenants include limitations on the issuers’ 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

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payments to PBF Holding. These covenants are subject to a number of important exceptions and qualifications. Many of these covenants will cease to apply or will be modified during a covenant suspension event, including when the Senior Secured Notes are rated investment grade. Certain covenants for the 2023 Senior Secured Notes will also be modified following a Collateral Fall-Away Event.
PBF Holding is in compliance with the covenants as of December 31, 2015.2018 (in millions):
 December 31, 2018
Debt, including current maturities: 
2025 Senior Notes$725.0
2023 Senior Notes500.0
PBF Rail Term Loan21.6
Catalyst leases44.3
Total debt1,290.9
Unamortized deferred financing costs(30.5)
Total debt, net of unamortized deferred financing costs1,260.4
Total Equity3,529.7
Total Capitalization (1)
$4,790.1
Total Debt to Capitalization Ratio26%
____________________________
(1) Total Capitalization refers to the sum of debt plus total equity.
At December 31, 2017 our total debt to capitalization ratio was 34%.
2018 Debt Transactions
On May 2, 2018, we and certain of our wholly-owned subsidiaries, as borrowers or subsidiary guarantors, replaced the August 2014 Revolving Credit Facilities
Revolving Loan
In March, August, and September 2012, we amendedAgreement with the Revolving Loan to increase the aggregate size from $500.0 million to $965.0 million. In addition,Credit Facility. Among other things, the Revolving Loan was amended and restated on October 26, 2012 to increaseCredit Facility increased the maximum availabilitycommitment available to $1.375us from $2.6 billion extendto $3.4 billion, extended the maturity date to October 26, 2017May 2023, and amend the borrowing base to include non-U.S. inventory. The agreement was expanded again in December 2012 and November 2013 to increase the maximum availability from $1.375 billion to $1.610 billion. On August 15, 2014, the agreement was amended and restated once more to, among other things, increase the maximum availability to $2.500 billion 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 portionredefined certain components of the facility. The amended and restated Revolving Loan includes an accordion feature which allows for aggregate commitments of up to $2.750 billion. In November and December 2015, PBF Holding increased the maximum availability underBorrowing Base (as defined in the Revolving LoanCredit Agreement) to $2.600 billion and $2.635 billion, respectively, in accordance with its accordion feature. On an ongoing basis, the Revolving Loan ismake more funding available to be used for working capital and other general corporate purposes.
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.
As of December 31, 2015, the Revolving Loan provided for borrowings of up to an aggregate maximum of $2.635 billion, a portion of which was available in the form of letters of credit. The amount available for borrowings and letters of credit Borrowings under the Revolving Loan is calculated according to a “borrowing base” formula based on (1) 90% of the book value of eligible accounts receivable with respect to investment grade obligors plus (2) 85% of the book value of eligible accounts receivable with respect to non-investment grade obligors plus (3) 80% of the cost of eligible hydrocarbon inventory plus (4) 100% of cash and cash equivalents in deposit accounts subject to a control agreement. The borrowing base is subject to customary reserves and eligibility criteria and in any event cannot exceed $2.635 billion.
Advances under the Revolving Loan plus all issued and outstanding letters of credit may not exceed the lesser of $2.635 billion or the borrowing base, as defined in the agreement. The Revolving Loan can be prepaid at any time without penalty. Interest on the Revolving Loan is payable quarterly in arrears,Credit Facility bear interest at the option of PBF Holding, either at the AlternateAlternative Base Rate plus the Applicable Margin or at the Adjusted LIBOR Rate plus the Applicable Margin, all as defined in the agreement. PBF Holding is requiredRevolving Credit Agreement and further described in “Note 8 - Credit Facility and Debt” of our Notes to pay aConsolidated Financial Statements. In addition, an accordion feature allows for commitments of up to $3.5 billion. The LC Participation Fee ranges from 1.00% to 1.75% depending on the Company’s corporate credit rating and the Fronting Fee is capped at 0.25%.
The Revolving Credit Agreement contains customary covenants and restrictions on our activities, including, but not limited to, limitations on the incurrence of additional indebtedness, liens, negative pledges, guarantees, investments, loans, asset sales, mergers and acquisitions, prepayment of other debt, distributions, dividends and the repurchase of capital stock, transactions with affiliates and our ability to change the nature of our business or our fiscal year; all as defined in the agreement, on each outstanding letter of credit issued underRevolving Credit Agreement.


In addition, the Revolving Loan ranging from 1.25% to 2.0% depending on the Company's debt rating, plus a Fronting Fee equal to 0.25%. As of December 31, 2015, there were no outstanding borrowings under the Revolving Loan. Additionally, we had $351.5 million in standby letters of credit issued and outstanding as of that date.
The Revolving LoanCredit Agreement has a financial covenant which requires that if at any time Excess Availability as(as defined in the agreement,Revolving Credit Agreement) is less than the greater of (i) 10% of the lesser of the then existing borrowing baseBorrowing Base and the then aggregate Revolving Commitments of the Lenders (the “Financial Covenant Testing Amount”), and (ii) $100.0 million, and until such time as Excess Availability is greater than the Financial Covenant Testing Amount and $100.0 million for a period of 12 or more consecutive days, PBF Holdingwe will not permit the Consolidated Fixed Charge Coverage Ratio as(as defined in the agreementRevolving Credit Agreement) and determined as of the last day of the most recently completed quarter, to be less than 1.0 to 1.0. Previously the requirement was 1.1 to 1.0. As of December 31, 2015, we were in compliance with all our debt covenants under the Revolving Loan.
PBF Holding’sOur obligations under the Revolving LoanCredit Facility are (a) are guaranteed by each of itsour domestic operating subsidiaries that are not Excluded Subsidiaries (as defined in the agreement)Revolving Credit Agreement) and (b) are secured by a lien on (x)(i) PBF LLC’s equity interest in PBF Holdingus and (y)(ii) certain of our assets and those of PBF Holding and theour subsidiary guarantors, including all deposit accounts (other than zero balance accounts, cash collateral accounts, trust accounts and/or payroll accounts, all of which are excluded from the definition of collateral), all accounts receivable, all hydrocarbon inventory (other than the intermediate and finished products owned by J. Aron pursuant to the A&R Inventory Intermediation Agreements) and to the extent

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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.
Rail Facility Revolving Credit Facility Overview
Effective March 25, 2014, PBF Rail, an indirect wholly-owned subsidiaryOur primary sources of PBF Holding, entered into a $250.0liquidity are cash flows from operations with additional sources available under borrowing capacity from our revolving line of credit. As of December 31, 2018, we had $561.7 million securedof cash and cash equivalents and no outstanding balance under our Revolving Credit Facility. We believe available capital resources will be adequate to meet our capital expenditure, working capital and debt service requirements. We had available capacity under our revolving credit agreement. The primary purpose of the Rail Facility is to fund the acquisition by PBF Rail of Eligible Railcars. On April 29, 2015, the Rail Facility was amendedfacility as follows at December 31, 2018 (in millions):
  Total Commitment Amount Borrowed as of December 31, 2018 Outstanding Letters of Credit Available Capacity Expiration date
Revolving Credit Facility (a) $3,400.0
 $
 $400.7
 $1,080.1
 May 2023
(a)
The amount available for borrowings and letters of credit under the Revolving Credit Facility is calculated according to a “borrowing base” formula based on (i) 90% of the book value of Eligible Accounts with respect to investment grade obligors plus (ii) 85% of the book value of Eligible Accounts with respect to non-investment grade obligors plus (iii) 80% of the cost of Eligible Hydrocarbon Inventory plus (iv) 100% of Cash and Cash Equivalents in deposit accounts subject to a control agreement, in each case as defined in the Revolving Credit Agreement. The borrowing base is subject to customary reserves and eligibility criteria and in any event cannot exceed $3.400 billion.
Additional Information on Indebtedness
Our debt, including our revolving credit facility, term loan and senior notes, include certain typical financial covenants and restrictions on our subsidiaries’ ability to, among other things, extend the maturityincur or guarantee new debt, engage in certain business activities including transactions with affiliates and asset sales, make investments or distributions, engage in mergers or pay dividends in certain circumstances. These covenants are subject to April 29, 2017, reduce the total commitment from $250.0 milliona number of important exceptions and qualifications. For further discussion of our indebtedness and these covenants and restrictions, see “Note 8 - Credit Facility and Debt” of our Notes to $150.0 million, and reduce the commitment fee on the unused portion of the Rail Facility.Consolidated Financial Statements.
The amount available to be advanced under the Rail Facility equals 70.0% of the lesser of the aggregate Appraised Value of the Eligible Railcars, or the aggregate Purchase Price of such Eligible Railcars, as these termsWe are defined in the credit agreement. On the first anniversary of the closing, the advance rate adjusts automatically to 65.0%. The Rail Facility matures on April 29, 2017 and all outstanding advances must be repaid at that time. At any time prior to maturity PBF Rail may repay and re-borrow any advances without premium or penalty.
As of December 31, 2015, there was $67.5 million outstanding under the Rail facility. PBF Rail is in compliance with theour covenants under the Rail Facility as of December 31, 2015.2018.
Cash Balances
As of December 31, 2015,2018, our cash and cash equivalents totaled $914.7$561.7 million. We also had $1.5 million in restricted cash, which was included within deferred charges and other assets, net on our balance sheet.
Liquidity
As of December 31, 2015,2018, our total liquidity was approximately $1,514.5$1,641.8 million, compared to total liquidity of approximately $960.5$1,395.2 million as of December 31, 2014. Total2017. Our total liquidity is the sum of our cash and cash equivalents plusequal to the amount of excess availability under the Revolving Loan.Credit Facility, which includes our cash balance at December 31, 2018.
Working Capital
Working capital for PBF Holding at December 31, 20152018 was $1,120.6approximately $1,069.1 million, consisting of $2,580.9$3,200.9 million in total current assets and $1,460.3$2,131.8 million in total current liabilities. Working capital at December 31, 20142017 was $429.3$1,310.3 million, consisting of $1,907.3$3,749.0 million in total current assets and $1,478.0$2,438.7 million in total current liabilities. Working capital has decreased during the year ended December 31, 2018 primarily as a result of capital expenditures, including turnaround costs, partially offset by positive earnings and proceeds from the Torrance land sale.


Crude and Feedstock Supply Agreements
We have acquired crude oil for our Paulsboro and Delaware City refineries under supply agreements whereby Statoil generally purchased the crude oil requirements for each refinery on our behalf and under our direction. Our agreements with Statoil for Paulsboro and Delaware City were terminated effective March 31, 2013 and December 31, 2015, respectively, at which time we began to source Paulsboro’s and Delaware City's crude oil and feedstocks independently. Additionally, forCertain of our purchases of crude oil under our agreementagreements with Saudi Aramco, similar to our purchases of other foreign waterborne crudes,national oil companies require that we postedpost letters of credit and arrangedarrange for shipment. We paidpay for the crude when we were invoiced, andat which time the letters of credit wereare lifted.
We hadhave a similar supply agreementcontract with MSCG, which was terminated effective July 31, 2014,Saudi Aramco pursuant to supply the crude oil requirements for our Toledo refinery, under which we took titlehave been purchasing up to MSCG’s crude oil at certain interstate pipeline delivery locations. Payment for the crude oil under the Toledo supply agreement was due three days after it was processed by us or sold to third parties. We did not have to post letters of credit for these purchases and the Toledo supply agreement allowed us to price and pay for our crude oil as it was processed, which reduced the time we were exposed to market fluctuations. We recorded an accrued liability at each period-end for the amount we owed MSCG for the crude oil that we owned but had not processed. Subsequent to the term of the MSCG supply agreement, we have sourced all of our Toledo crude oil needs independently, which has increased the volumesapproximately 100,000 bpd of crude oil from Saudi Aramco that is processed at our Paulsboro refinery. In connection with the Chalmette Acquisition we own.
We have crude and feedstock supply agreementsentered into a contract with PDVSA tofor the supply of 40,000 to 60,000 bpd of crude oil that can be processed at any of our East andor Gulf Coast refineries. We have not sourced crude oil under this agreement since the third quarter of 2017 as PDVSA has suspended deliveries due to the parties’ inability to agree to mutually acceptable payment terms. In connection with the closing of the Torrance Acquisition, we entered into a crude supply agreement with ExxonMobil for approximately 60,000 bpd of crude oil that can be processed at our Torrance refinery. We currently purchase all of our crude and feedstock needs independently from a variety of suppliers on the spot market or through term agreements for our Delaware City and Toledo refineries.
Inventory Intermediation Agreements
WeOn May 4, 2017 and September 8, 2017, we and our subsidiaries, DCR and PRC, entered into two separateamendments to the Inventory Intermediation Agreements with J. Aron on June 26, 2013 which commenced upon the termination of the product offtake agreements with MSCG. On May 29, 2015, we entered into amended and

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restated inventory intermediation agreements (“A&R Intermediation Agreements”) with J. Aron, pursuant to which certain terms of the existing inventory intermediation agreements were amended, including, among other things, pricing and an extension of the terms. As a result of the amendments (i) the Inventory Intermediation Agreement by and among J. Aron, PBF Holding and PRC relating to the Paulsboro refinery extends 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 clausesDecember 31, 2019, which term may be further extended by mutual consent of both parties.the parties to December 31, 2020 and (ii) the Inventory Intermediation Agreement by and among J. Aron, PBF Holding and DCR relating to the Delaware City refinery extends the term to July 1, 2019, which term may be further extended by mutual consent of the parties to July 1, 2020.
Pursuant to each A&RInventory Intermediation Agreement, J. Aron will continuecontinues to purchase and hold title to certain of the intermediate and finished productsProducts produced by the Paulsboro and Delaware City refineries, respectively,Refineries, and delivered into tanks at the refineries.Refineries. Furthermore, J. Aron agrees to sell the productsProducts back to Paulsboro refinery and Delaware City refinerythe Refineries as the productsProducts are discharged out of the refineries'Refineries’ tanks. J. Aron has the right to store the productsProducts purchased in tanks under the A&RInventory Intermediation Agreements and will retain these storage rights for the term of the agreements. PBF Holding willWe continue to market and sell the products independently to third parties.
At December 31, 2015,2018, the LIFO value of intermediates and finished products owned by J. Aron included within inventoryInventory on our consolidated balance sheet was $411.4$334.7 million. We accrue a corresponding liability for such intermediates and finished products.
Capital Spending
Net capitalCapital spending excluding the Chalmette Acquisition, was $245.9$560.3 million for the year ended December 31, 2015,2018, which primarily included turnaround costs, safety related enhancements and facility improvements at the refineries.
The Chalmette Acquisition closed on November 1, 2015. The purchase price was $322.0 million plus estimated inventory and working capital of $243.3 million, which is subject to final valuation upon agreement of both parties. The transaction was financed through a combination of cash on hand and borrowings under our Revolving Loan.
We also entered into a Sale and Purchase Agreement to purchase the ownership interest of the Torrance refinery, and related logistic assets. The purchase price for the Torrance Acquisition is $537.5 million in cash, plus inventory and working capital to be valued at closing. The purchase price is also subject to other customary purchase price adjustments. The Torrance Acquisition is expected to close in the second quarter of 2016, subject to satisfaction of customary closing conditions. We expect to finance the transaction with a combination of cash on hand, and proceeds from the October 2015 Equity Offering and the offering of the 2023 Senior Secured Notes.
We currently expect to spend an aggregate of approximately between $475.0$625.0 million to $500.0$675.0 million in net capital expenditures during 20162019 for facility improvements and refinery maintenance and turnarounds, excluding any potential capital expenditure relatedthe majority of which is expected to be incurred during the pending Torrance Acquisition.first six months of 2019. Significant capital spending plans for 20162019 include turnarounds forof the coker at our Torrance refinery, the coker at our Delaware City refinery and the FCCcrude unit at our Paulsboro refinery, as well as expenditures to meet Tier 3environmental and regulatory requirements. Capital spending plans also include strategic capital expenditures for the restart of the idled Chalmette refinery coker and the Delaware City refinery hydrogen plant.

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Contractual Obligations and Commitments
The following table summarizes our material contractual payment obligations as of December 31, 2015:
2018 (in thousands):
  Payments due by period
  
 Total 
Less than
1 year
 1-3 Years 3-5 Years 
More than
5 years
Long-term debt (a) $1,744,840
 $17,252
 $552,088
 $675,500
 $500,000
Interest payments on debt facilities (a) 570,228
 105,365
 206,270
 153,593
 105,000
Delaware Economic Development Authority Loan (b) 
 
 
 
 
Operating Leases (c) 458,358
 96,229
 173,653
 130,193
 58,283
Purchase obligations (d):          
Crude Supply and Inventory Intermediation Agreements 2,333,615
 876,142
 731,853
 725,620
 
Other Supply and Capacity Agreements 990,365
 184,314
 285,829
 187,075
 333,147
Minimum volume commitments with PBFX (e) 1,016,143
 143,489
 286,315
 286,647
 299,692
Construction obligations 7,400
 7,400
 
 
 
Environmental obligations (f) 15,646
 2,284
 1,946
 1,768
 9,648
Pension and post-retirement obligations (g) 186,341
 11,957
 15,111
 15,735
 143,538
Total contractual cash obligations $7,322,936
 $1,444,432
 $2,253,065
 $2,176,131
 $1,449,308
 Payments due by period
  
Total 
Less than
1 year
 1-3 Years 3-5 Years 
More than
5 years
Long-term debt (a)$1,290,907
 $31,368
 $34,539
 $500,000
 $725,000
Interest payments on debt facilities (a)517,792
 88,431
 175,392
 175,125
 78,844
Operating Leases (b)1,244,168
 253,215
 363,206
 261,120
 366,627
Purchase obligations (c):         
Crude and Feedstock Supply and Inventory Intermediation Agreements4,980,498
 2,374,498
 2,579,756
 26,244
 
Other Supply and Capacity Agreements690,102
 189,821
 146,467
 97,030
 256,784
Minimum volume commitments with PBFX (d)416,959
 106,443
 213,965
 49,976
 46,575
Construction obligations89,526
 89,526
 
 
 
Environmental obligations (e)148,493
 6,425
 23,204
 22,360
 96,504
Pension and post-retirement obligations (f)237,393
 12,241
 25,659
 25,004
 174,489
Total contractual cash obligations$9,615,838
 $3,151,968
 $3,562,188
 $1,156,859
 $1,744,823

(a) Long-term Debt and Interest Payments on Debt Facilities
Long-term obligations represent (i) the repayment of the outstanding borrowings under the Revolving Loan;Credit Facility; (ii) the repayment of indebtedness incurred in connection with the Senior Secured Notes; (iii) the repayment of our catalyst lease obligations on their maturity dates; and (iv) the repayment of outstanding amounts under the PBF Rail Facility; and (v) the repayment of outstanding intercompany notes payable with PBF LLC and PBF Energy.Term Loan.
Interest payments on debt facilities include cash interest payments on the Senior Secured Notes, catalyst lease obligations, PBF Rail Facility, our intercompany notes payable with PBF Energy and PBF LLC,Term Loan, plus cash payments for the commitment fee on the unused portion on our Revolving LoanCredit Facility and letter of credit fees on the letters of credit outstanding at December 31, 2015.2018. With the exception of our catalyst leases and outstanding borrowings on thePBF Rail Facility,Term Loan, we have no long-term debt maturing before 20172023 as of December 31, 2015.2018.
(b) Delaware Economic Development Authority Loan
The Delaware Economic Development Authority Loan convertsOn May 2, 2018, we and certain of our wholly-owned subsidiaries, as borrowers or subsidiary guarantors, replaced our August 2014 Revolving Credit Agreement with the Revolving Credit Facility. Among other things, the Revolving Credit Facility increased the maximum commitment available to a grant in tranches of $4.0 million annually, starting atus from $2.6 billion to $3.4 billion, extended the one year anniversarymaturity date to May 2023, and redefined certain components of the Delaware City refinery’s “certified re-start date” provided we meet certain criteria, all asBorrowing Base (as defined in the loan agreement. We expect that we will meet the requirementsRevolving Credit Agreement) to convert the loan to a grantmake more funding available for working capital needs and that we will ultimately not be required to repay the $20.0 million loan. Our Delaware Economic Development Authority Loan is further explained in the Delaware Economic Development Authority Loan footnote in our consolidated financial statements, “Item 8. Financial Statements and Supplementary Data.”other general corporate purposes.
(c)(b) Operating Leases
We enter into operating leases in the normal course of business, some of these leases provide us with the option to renew the lease or purchase the leased item. Future operating lease obligations would change if we chose to exercise renewal options and if we enter into additional operating lease agreements. Certain of our lease obligations contain a fixed and variable component. The table above reflects the fixed component of our lease obligations.obligations, including leases with affiliates. The variable component could be significant. As described in “Note 2 - Summary of Significant Accounting Policies” of our Notes to Consolidated Financial Statements, we adopted new guidance on leases effective January 1, 2019 which will bring substantially all leases with initial terms of over twelve months onto our consolidated balance sheet. Our operating lease obligations are further explained in the“Note 11 - Commitments and Contingencies footnoteContingencies” of our Notes to Consolidated Financial Statements.
Included within our operating leases section of the contractual obligations and commitments are our obligations related to our financial statements, “Item 8. Financial Statements and Supplementary Data.” Weleased railcar fleet. In support of our rail strategy, we have at times entered into agreements to lease or purchase 5,900 crude railcars. Certain of these railcars which will enable us to transport this crude to each of our refineries. Any such leases will commence as the railcars are delivered. Of the 5,900 crude railcars, during 2015 and 2014 we purchased 1,122 and 1,403 railcars, respectively, andwere subsequently sold them to third parties, which hashave leased the railcars back to us for periods of between fivefour and seven years. As discussed in “Note 7 - Accrued expenses” of our notes to Consolidated Financial Statements, on September 30, 2018, we agreed to voluntarily return a portion of railcars under an operating lease in order to rationalize certain components of our railcar fleet based on prevailing market conditions in the crude oil by rail market. Under the terms of the lease amendment, we agreed to pay the Early Termination Penalty and will pay a reduced rental fee over the remaining term of the lease totaling $52.3 million. As of December 31, 2018, $30.4 million of our total $52.3 million charge has not yet been paid and is included within the table above.

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(d)Additionally, we enter into contractual obligations with third parties for the right to use property for locating pipelines and accessing certain of our assets (also referred to as land easements) in the normal course of business. Our obligations regarding such land easements are included within Operating Leases in the table above. As described in “Note 2 - Summary of Significant Accounting Policies” of our Notes to Consolidated Financial Statements, we elected the practical expedient to not evaluate land easements for lease consideration under the new lease guidance adopted on January 1, 2019.
(c) Purchase Obligations
We have obligations to repurchase crude oil, feedstocks, certain intermediates and refined products under separate crude supply and inventory intermediation agreements with J. Aron as further explained in the“Note 2 - Summary of Significant Accounting Policies, InventoriesPolicies”, “Note 4 - Inventories” and “Note 7 - Accrued Expenses footnotesexpenses” of our Notes to our financial statements, “Item 8.Consolidated Financial Statements and Supplementary Data.” Our agreements with Statoil for Paulsboro and Delaware City were terminated effective March 31, 2013 and December 31, 2015, respectively, at which time we began to source Paulsboro’s and Delaware City's crude oil and feedstocks independently.Statements. Additionally, purchase obligations under “Crude and Feedstock Supply and Inventory Intermediation Agreements” include commitments to purchase crude oil from certain counterparties under supply agreements entered into to ensure adequate supplies of crude oil for our refineries. These obligations are based on aggregate minimum volume commitments at 20152018 year end market prices.
Payments under “Other Supply and Capacity Agreements” include contracts for the transportation of crude oil and supply of hydrogen, steam, or natural gas to certain of our refineries, contracts for the treatment of wastewater, and contracts for pipeline capacity. We enter into these contracts to facilitate crude oil deliveries and to ensure an adequate supply of energy or essential services to support our refinery operations. Substantially all of these obligations are based on fixed prices. Certain agreements include fixed or minimum volume requirements, while others are based on our actual usage. The amounts included in this table are based on fixed or minimum quantities to be purchased and the fixed or estimated costs based on market conditions as of December 31, 2015.2018.
(e)(d) Minimum commitmentsVolume Commitments with PBFX
We have minimum obligations under our commercial agreements entered into with PBFX. PBFX receives, handles and transfers crude oil and receives, stores and delivers crude oil, refined products and intermediates from sources located throughout the United States and Canada in support of our three refineries. Refer to Note 12 “Related“Note 10 - Related Party Transactions” of our Notes to the Consolidated Financial Statements for a detailed explanation of each of these agreements.
Included in the table above are our obligations related to the minimum volume commitments required under these commercial agreements.agreements that were determined to not be leases under GAAP. Any incremental volumes above any minimumsminimum throughput under these agreements would increase our obligations. Our obligation with respect to the Toledo Tank Farm Storagecertain crude oil and Terminaling Agreementrefined product storage agreements is based on the estimated shell capacity of the storage tanks to be utilized.
(f)(e) Environmental Obligations
In connection with the Paulsboro acquisition,certain of our refinery acquisitions, we have assumed certain environmental remediation obligations to address existing soil and groundwater contaminationmatters that were outstanding at the site and recorded as a liabilitytime of such acquisitions. In addition, in the amount of $10.4 million which reflects the present value of the current estimated cost of the remediation obligations assumed based on investigative work to-date. The undiscounted estimated costs related to these environmental remediation obligations were $15.6 million as of December 31, 2015.
In connection with the acquisitionmost of the Delaware City assets, the prior owners remain responsible, subject to certain limitations, for certain pre-acquisition environmental obligations, including ongoing soil and groundwater remediation at the site.
In connection with the Delaware City assets and Paulsboro refinerythese acquisitions, we along with the seller,have purchased two individual ten-year, $75.0 million environmental insurance policies to insure against unknown environmental liabilities at each site.
In connection with the acquisition of Toledo, the seller initially retains, subject to certain limitations, remediation The obligations which will transition to us over a 20-year period.
In connection with the acquisition of the Chalmette refinery, the sellers provided $3.9 million financial assurance in the form of a surety bondtable above reflect our best estimate in cost and tenure to cover estimated site remediation costs associated with an agreed to Administrative Order of Consent with the EPA. Additionally, the Company purchased a ten year $100.0 million environmental insurance policy to insure against unknown environmental liabilities at the site.
In connection with the acquisition of all fourremediate our outstanding obligations and are further discussed in “Note 11 - Commitments and Contingencies” of our refineries, we assumed certain environmental obligations under regulatory orders uniqueNotes to each site, including orders regulating air emissions from each facility.Consolidated Financial Statements.

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(g)(f) Pension and Post-retirement Obligations
Pension and post-retirement obligations include only those amounts we expect to pay out in benefit payments and are further explained at thein “Note 14 - Employee Benefit Plans footnotePlans” of our Notes to our financial statements, “Item 8.Consolidated Financial Statements and Supplementary Data.”Statements.
(h) Tax Receivable Agreement Obligations
PBF Energy used a portion of the proceeds from our IPO to purchase PBF LLC Series A Units from the members of PBF LLC other than PBF Energy. In addition, the members of PBF LLC other than PBF Energy may (subject to the terms of the exchange agreement) exchange their PBF LLC Series A Units for shares of Class A common stock of PBF Energy on a one-for-one basis. As a result of both the purchase of PBF LLC Series A Units and subsequent secondary offerings and exchanges, PBF Energy is entitled to a proportionate share of the existing tax basis of the assets of PBF LLC. Such transactions have resulted in increases in the tax basis of the assets of PBF LLC that otherwise would not have been available. Both this proportionate share and these increases in tax basis may reduce the amount of tax that PBF Energy would otherwise be required to pay in the future. These increases in tax basis have reduced the amount of the tax that PBF Energy would have otherwise been required to pay and may also decrease gains (or increase losses) on the future disposition of certain capital assets to the extent tax basis is allocated to those capital assets. PBF Energy entered into a tax receivable agreement with the current and former members of PBF LLC other than PBF Energy that provides for the payment by PBF Energy to such members of 85% of the amount of the benefits, if any, that PBF Energy is deemed to realize as a result of (i) these increases in tax basis 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. These payment obligations are obligations of PBF Energy and not of PBF Holding or any of its subsidiaries.
PBF Energy expects to obtain funding for these payments by causing its subsidiaries to make cash distributions to PBF LLC, which, in turn, will distribute such amounts, generally as tax distributions, on a pro-rata basis to its owners, which as of December 31, 2015 include the members of PBF LLC other than PBF Energy holding a 4.9% interest and PBF Energy holding a 95.1% interest. The members of PBF LLC other than PBF Energy may continue to reduce their ownership in PBF LLC by exchanging their PBF LLC Series A Units for shares of PBF Energy Class A common stock. Such exchanges may result in additional increases in the tax basis of PBF Energy’s investment in PBF LLC and require PBF Energy to make increased payments under the tax receivable agreement. Required payments under the tax receivable agreement also may increase or become accelerated in certain circumstances, including certain changes of control.
The Contractual Obligations and Commitments Table above does not include tax distributions or other distributions that we expect to make on account of PBF Energy’s obligations under the tax receivable agreement that PBF Energy entered into with the membersTax Receivable Agreement. Refer to “Note 11 - Commitments and Contingencies” of PBF LLC other than PBF Energy in connection with PBF Energy’s initial public offering.our Notes to Consolidated Financial Statements for further details.
Off-Balance Sheet Arrangements
We have no off-balance sheet arrangements as of December 31, 2015,2018, other than outstanding letters of credit in the amount of approximately $351.5 million.
During 2015,$400.7 million and operating leases. As described in aggregate we sold 1,122“Note 2 - Summary of Significant Accounting Policies” of our owned crude railcars and concurrently entered into lease agreements for the same railcars. The lease agreements have varying terms from fiveNotes to seven years. We received an aggregate cash payment for the railcars of approximately $168.3 million and expectConsolidated Financial Statements, we adopted new guidance on leases effective January 1, 2019, which will require us to make payments totaling $99.4 million over the term of the lease for these railcars.
During the year ended December 31, 2015, we had additional railcarrecord substantially all leases outstanding with initial terms of up to 10 years. We expect to make lease payments of $59.6 million over the remaining term of these additional agreements.twelve months onto our consolidated balance sheet.


Critical Accounting Policies
The following summary provides further information about our critical accounting policies that involve critical accounting estimates and should be read in conjunction with Note“Note 2 - Summary of Significant Accounting Policies” of our Notes to our financial statements,Consolidated Financial Statements within “Item 8. Financial Statements and Supplementary Data.”
Use The following accounting policies involve estimates that are considered critical due to the level of Estimates
The preparationsubjectivity and judgment involved, as well as the impact on our financial position and results of financial statementsoperations. We believe that all of our estimates are reasonable. Unless otherwise noted, estimates of the sensitivity to earnings that would result from changes in accordance with GAAP requires managementthe assumptions used in determining our estimates is not practicable due to make estimatesthe number of assumptions and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilitiescontingencies involved, and the reported revenues and expenses. Actual results could differ from those estimates.

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Revenue and Deferred Revenuewide range of possible outcomes.
We sell various refined products and recognize 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.
Prior to July 1, 2013, the Company’s Paulsboro and Delaware City refineries sold light finished products, certain intermediates and lube base oils to MSCG under product offtake agreements with each refinery (the “Offtake Agreements”). As of July 1, 2013, the Company terminated the Offtake Agreements for the Company’s Paulsboro and Delaware City refineries. The Company entered into two separate Inventory Intermediation Agreements with J. Aron on June 26, 2013, which commenced upon the termination of the product offtake agreements with MSCG. On May 29, 2015, PBF Holding entered into amended and restated inventory intermediation agreements with J. Aron pursuant to which certain terms of the existing inventory intermediation agreements were amended, including, among other things, pricing and an extension of the term for a period of two years from the original expiry date of July 1, 2015, subject to certain early termination rights. In addition, the A&R Intermediation Agreements include one-year renewal clauses by mutual consent of both parties.
Pursuant to each A&R Intermediation Agreement, J. Aron will continue to purchase and hold title to certain of the intermediate and finished products produced by the Paulsboro and Delaware City refineries, respectively, and delivered into tanks at the Refineries. Furthermore, J. Aron agrees to sell the Products back to Paulsboro refinery and Delaware City refinery as the Products are discharged out of the Refineries' tanks. J. Aron has the right to store the Products purchased in tanks under the A&R Intermediation Agreements and will retain these storage rights for the term of the agreements. PBF Holding will continue to market and sell the Products independently to third parties.
Until December 31, 2015, our Delaware City refinery sold and purchased feedstocks under a supply agreement with Statoil. Statoil purchased the refinery’s production of certain feedstocks or purchased feedstocks from third parties on the refinery’s behalf. Legal title to the feedstocks was held by Statoil and the feedstocks were held in the refinery’s storage tanks until they were needed for further use in the refining process. At that time the feedstocks were drawn out of the storage tanks and purchased by us. These purchases and sales were settled monthly at the daily market prices related to those feedstocks. These transactions were considered to be made in the contemplation of each other and, accordingly, did not result in the recognition of a sale when title passed from the refinery to the counterparty. Inventory remained at cost and the net cash receipts resulted in a liability. The Statoil crude supply agreement with our Delaware City refinery terminated effective December 31, 2015, at which time we began to purchase from Statoil the feedstocks owned by them at that date that had been purchased on our behalf. The Statoil crude supply agreement with Paulsboro terminated effective March 31, 2013, at which time we began to purchase from Statoil the feedstocks owned by them at that date that had been purchased on our behalf.
InventoryInventories
Inventories are carried at the lower of cost or market. The cost of crude oil, feedstocks, blendstocks and refined products is determined under the LIFO method using the dollar value LIFO method with increments valued based on average cost during the year. The cost of supplies and other inventories is determined principally on the weighted average cost method.
Our Delaware City refinery acquired In addition, the use of the LIFO inventory method may result in increases or decreases to cost of sales in years that inventory volumes decline as the result of charging cost of sales with LIFO inventory costs generated in prior periods. At December 31, 2018 and 2017, market values had fallen below historical LIFO inventory costs and, as a result, we recorded lower of cost or market inventory valuation reserves of $651.7 million and $300.5 million, respectively. The lower of cost or market inventory valuation reserve, or a portion thereof, is subject to reversal as a reduction to cost of its crude oil from Statoil under our crude supply agreement whereby we took titleproducts sold in subsequent periods as inventories giving rise to the crude oil as it was deliveredreserve are sold, and a new reserve is established. Such a reduction to our processing units. We had risk of loss while the Statoil inventory was in our storage tanks. We were obligated to purchase all of the crude oil held by Statoil on our behalf upon termination of the agreements. As a result of the purchase obligations, we recorded the inventory of crude oil and feedstocks in the refinery’s storage facilities. The purchase obligations contained derivatives that changed in value based on changes in commodity prices. Such changes were included in our cost of sales. Our agreement with Statoil for our Delaware City refinery terminated effective December 31, 2015, at which time we beganproducts sold could be significant if inventory values return to source crude oil and feedstocks internally. Our agreement with Statoil for Paulsboro terminated effective March 31, 2013, at which time we beganhistorical cost price levels. Additionally, further decreases in overall inventory values could result in additional charges to source crude oil and feedstocks independently.
Prior to July 31, 2014, our Toledo refinery acquired substantially allcost of its crude oil from MSCG under a crude oil acquisition agreement whereby we took legal title toproducts sold should the crude oil at certain interstate pipeline delivery locations. We recorded an accrued liability at each period-end for the amount we owed MSCG for the crude oil that we owned but had not processed. The accrued liability was based on the period-endlower of cost or market value, as it represented our best estimate of what we would pay for the crude oil. We terminated this crude oil acquisition agreement effective July 31, 2014 and began to source our crude oil needs independently.inventory valuation reserve be increased.

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Environmental Matters
Liabilities for future clean-up costs are recorded when environmental assessments and/or clean-up 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 our own internal environmental policies. The actual settlement of our liability for environmental matters could materially differ from our 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.
Business Combinations
We use Additionally, in connection with the acquisition method of accounting for the recognition of assets acquired and liabilitiesTorrance Acquisition on July 1, 2016, we assumed in business combinations at their estimated fair values ascertain pre-existing environmental liabilities. While we believe that our current estimates of the date of acquisition. Any excess consideration transferred over the estimated fair valuesamounts and timing of the identifiable net assets acquired is recorded as goodwill. Significant judgment is required in estimatingcosts related to the fair valueremediation 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 assumptionsthese liabilities are reasonable, they are inherently uncertain. Unanticipated market or macroeconomic events and circumstances may occur, which could affect the accuracy or validitywe have had limited experience with these environmental obligations due to our short operating history. It is possible that our estimates of the estimatescosts and assumptions.
Long-Lived Assets and Definite-Lived Intangibles
We review our long and finite lived assets for impairment whenever events or changes in circumstances indicate their carrying value may not be recoverable. Impairment is evaluated by comparing the carrying valueduration of the long and finite lived assetsenvironmental remediation activities related to the estimated undiscounted future cash flows expected to result from the use of the assets and their ultimate disposition. If such analysis indicates that the carrying value of the long and finite 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, whichthese liabilities could produce different results.materially change.
Deferred Turnaround Costs
Refinery turnaround costs, which are incurred in connection with planned major maintenance activities at our refineries, are capitalized when incurred and amortized on a straight-line basis over the period of time estimated until the next turnaround occurs (generally three to five years). While we believe that the estimates of time until the next turnaround are reasonable, it should be noted that factors such as competition, regulation or environmental matters could cause us to change our estimates thus impacting amortization expense in the future.
Derivative Instruments
We are exposed to market risk, primarily related to changes in commodity prices for the crude oil and feedstocks we use in the refining process as well as the prices of the refined products we sell. 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. Non-derivative contracts are recorded at the time of delivery.
All derivative instruments that are not designated as normal purchases or sales are recorded in our consolidated 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 in income. Contracts qualifying for the normal purchases and sales exemption are accounted for upon settlement. We elect fair value hedge accounting for certain derivatives associated with our inventory repurchase obligations.


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; identification 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 earnings.

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Recent Accounting Pronouncements
In February 2015, the FASB issued ASU No. 2015-02, “Consolidations (Topic 810): AmendmentsRefer to the Consolidation Analysis” (“ASU 2015-02”), which amends current consolidation guidance including changes“Note 2 - Summary of Significant Accounting Policies” of our Notes to both the variable and voting interest models used by companies to evaluate whether an entity should be consolidated. The requirements from ASU 2015-02 are effectiveConsolidated Financial Statements, for interim and annual periods beginning after December 15, 2015, and early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.
In April 2015, the FASB issued ASU No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs” (“ASU 2015-03”), which requires debt issuance costs related to a recognized debt liability to be presented on the balance sheet as a direct deduction from the debt liability rather than as an asset. The standard is effective for interim and annual periods beginning after December 15, 2015 and early adoption is permitted. The Company early adopted the new standard in its consolidated financial statements and related disclosures, which resulted in a reclassification of $32.2 million and $30.1 million of deferred financing costs from other assets to long-term debt as of December 31, 2015 and December 31, 2014, respectively.
In August 2015, the FASB issued ASU No. 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date” (“ASU 2015-14”), which defers the effective date of ASU 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”) for all entities by one year. The guidance in ASU 2014-09 will replace most existing revenue recognition guidance in GAAP when it becomes effective. Under ASU 2015-14, this guidance becomes effective for interim and annual periods beginning after December 15, 2017 and permits the use of either the retrospective or cumulative effect transition method. Under ASU 2015-14, early adoption is permitted only as of annual reporting periods beginning after December 15, 2016, including interim reporting periods within that reporting period. The Company continues to evaluate the impact of this new standard on its consolidated financial statements and related disclosures.
In September 2015, the FASB issued ASU No. 2015-16, “Business Combinations (Topic 805): Simplifying theRecently Issued Accounting for Measurement-Period Adjustments” (“ASU 2015-16”), which requires (i) that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined, (ii) that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date, (iii) that an entity present separately on the face of the income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. Under ASU 2015-16, this guidance becomes effective for annual periods beginning after December 15, 2016 and interim periods within annual periods beginning after December 15, 2017 with prospective application with early adoption permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.Pronouncements.
In November 2015, the FASB issued ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes” (“ASU 2015-17”), which requires deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. Under ASU 2015-17, this guidance becomes effective for annual periods beginning after December 15, 2016 and interim periods within annual periods beginning after December 15, 2016 and interim periods within those years. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.
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

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a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.
In March 2016, the FASB issued ASU No. 2016-06, “Derivatives and Hedging (Topic 815) Contingent Put and Call Options in Debt Instruments No. 2016-06 March 2016 a consensus of the FASB Emerging Issues Task Force” (“ASU 2016-06”), to increase consistency in practice in applying guidance on determining if an embedded derivative is clearly and closely related to the economic characteristics of the host contract, specifically for assessing whether call (put) options that can accelerate the repayment of principal on a debt instrument meet the clearly and closely related criterion. The guidance in ASU 2016-06 applies to all entities that are issuers of or investors in debt instruments (or hybrid financial instruments that are determined to have a debt host) with embedded call (put) options. ASU 2016-06 is effective for interim and annual periods beginning after December 15, 2016, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.

Iran Sanctions Compliance Disclosure
Under the Iran Threat Reduction and Syrian Human Rights Act of 2012 (“ITRA”), which added Section 13(r) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), we are required to include certain disclosures in our periodic reports if we or any of our “affiliates” knowingly engaged in certain specified activities during the period covered by the report. Because the SEC defines the term “affiliate” broadly, it may include any entity controlled by us as well as any person or entity that controls us or is under common control with us (“control” is also construed broadly by the SEC). Neither we nor any of our affiliates or subsidiaries have knowingly engaged in any transaction or dealing reportable under Section 13(r) of the Exchange Act during the reporting period.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
We are exposed to market risks, including changes in commodity prices and interest rates. Our primary commodity price risk is associated with the difference between the prices we sell our refined products and the prices we pay for crude oil and other feedstocks. We may use derivative instruments to manage the risks from changes in the prices of crude oil and refined products, natural gas, interest rates, or to capture market opportunities.
Commodity Price Risk
Our earnings, cash flow and liquidity are significantly affected by a variety of factors beyond our control, including the supply of, and demand for, crude oil, other feedstocks, refined products and natural gas. The supply of and demand for these commodities depend on, among other factors, changes in domestic and foreign economies, weather conditions, domestic and foreign political affairs, planned and unplanned downtime in refineries, pipelines and production facilities, production levels, the availability of imports, the marketing of competitive and alternative fuels, and the extent of government regulation. As a result, the prices of these commodities can be volatile. Our revenues fluctuate significantly with movements in industry refined product prices, our cost of sales fluctuates significantly with movements in crude oil and feedstock prices and our operating expenses fluctuate with movements in the price of natural gas. We manage our exposure to these commodity price risks through our supply and offtake agreements as well as through the use of various commodity derivative instruments.
We may use non-trading derivative instruments to manage exposure to commodity price risks associated with the purchase or sale of crude oil and feedstocks, finished products and natural gas outside of our supply and offtake agreements. The derivative instruments we use include physical commodity contracts and exchange-traded and over-the-counter financial instruments. We mark-to-market our commodity derivative instruments and recognize the changes in their fair value in our statements of operations.
At December 31, 20152018 and 2014,2017, we had gross open commodity derivative contracts representing 44.27.4 million barrels and 49.324.3 million barrels, respectively, with an unrealized net gain (loss) of $46.1$7.2 million and $31.2net loss of $74.3 million, respectively. The open commodity derivative contracts as of December 31, 20152018 expire at various times during 2016.2019.
We carry inventories of crude oil, intermediates and refined products (“hydrocarbon inventories”) on our consolidated balance sheet, the values of which are subject to fluctuations in market prices. Our hydrocarbon inventories totaled approximately 26.830.5 million barrels and 18.630.1 million barrels at December 31, 20152018 and 2014,2017, respectively. The average cost of our hydrocarbon inventories was approximately $83.55$78.78 and $94.29$80.21 per barrel on a LIFO basis at December 31, 20152018 and 2014,2017, respectively, excluding the impact of the LCM inventory adjustments of approximately $1,117.3$651.7 million and $690.1$300.5 million,

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respectively. During 2015 and 2014, theIf market prices of our inventory declineddecline to a level below our average cost, and we wrotemay be required to write down the carrying value of our hydrocarbon inventories to market.
Our predominant variable operating cost is energy, which is comprised primarily of natural gas and electricity. We are therefore sensitive to movements in natural gas prices. Assuming normal operating conditions, we annually consume a total of approximately 52between 68 million and 73 million MMBTUs of natural gas amongst our four refineries.five refineries as of December 31, 2018. Accordingly, a $1.00 per MMBTU change in natural gas prices would increase or decrease our natural gas costs by approximately $52$68.0 million to $73.0 million.
Compliance Program Price Risk
We are exposed to market risks related to the volatility in the price of RINs required to comply with the Renewable Fuel Standard.RFS. Our overall RINs obligation is based on a percentage of our domestic shipments of on-road fuels as established by the EPA. To the degree we are unable to blend the required amount of biofuels to satisfy our RINs obligation, we must purchase RINs on the open market. To mitigate the impact of this risk on our results of operations and cash flows we may purchase RINs when the price of these instruments is deemed favorable.


In addition, we are exposed to risks associated with complying with federal and state legislative and regulatory measures to address greenhouse gas and other emissions. Requirements to reduce emissions could result in increased costs to operate and maintain our facilities as well as implement and manage new emission controls and programs put in place. For example, AB32 in California requires the state to reduce its GHG emissions to 1990 levels by 2020.
Interest Rate Risk
The maximum availabilitycommitment under our Revolving LoanCredit Facility is $2.6$3.4 billion. Borrowings under the Revolving LoanCredit Facility bear interest either at the Alternative Base Rate plus the Applicable Margin or at the Adjusted LIBOR Rate plus the Applicable Margin, all as defined in the Revolving Loan. The Applicable Margin ranges from 1.50% to 2.25% for Adjusted LIBOR Rate Loans and from 0.50% to 1.25% for Alternative Base Rate Loans, depending on the Company's debt rating.Credit Agreement. If this facility werewas fully drawn, a one percent1.0% change in the interest rate would increase or decrease our interest expense by approximately $26.0$20.6 million annually.
In addition, we entered into the PBF Rail Facility in 2014Term Loan, which bears interest at a variable rate, and exposes us to interest rate risk. Maximum availability under the Rail Facility is $150.0 million.had an outstanding principal balance of $21.6 million at December 31, 2018. A 1.0% change in the interest rate associated with the borrowings outstanding under this facility would result in a $1.5 million change inincrease or decrease our interest expense by approximately $0.2 million annually, assuming the $150.0 million available undercurrent outstanding principal balance on the PBF Rail Facility was fully drawn.Term Loan remained outstanding.
We also have interest rate exposure in connection with our J. Aron Inventory Intermediation Agreements under which we pay a time value of money charge based on LIBOR.
Credit Risk
We are subject to risk of losses resulting from nonpayment or nonperformance by our counterparties. We will continue to closely monitor the creditworthiness of customers to whom we grant credit and establish credit limits in accordance with our credit policy.
Concentration Risk
For the yearyears ended December 31, 20152018, 2017 and 2014,2016, no single customer accounted for 10% or more of our total sales.
Only one customer, ExxonMobil, accounted for 10% or more of our total accounts receivables as of December 31, 2015. Following the Chalmette Acquisition on November 1, 2015, ExxonMobil and its affiliates represented approximately 18% of our total trade accounts receivable as of December 31, 2015.
No single customer accounted for 10% or more of our total trade accounts receivable as of December 31, 2014.2018 and 2017, respectively.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The information required by this item is set forth beginning on page F-1 of this Annual Report on Form 10-K.


ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.


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ITEM 9A.  CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
Our management has evaluated,We conducted evaluations under the supervision and with the participation of our management, including the principal executive and principal financial officers, of the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act)Act of 1934 as amended (the “Exchange Act”)) as of the end of the period covered by this report, and has concluded that our disclosure controls and procedures are effective to provide reasonable assurance that information required to be disclosed by us inreport. Based upon these evaluations, the reports that we file or furnish under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC's rules and forms including, without limitation, controls and procedures designed to ensure that information required to be disclosed by us in the reports that we file or furnish under the Exchange Act is accumulated and communicated to our management, including our principal executive and principal financial officers as appropriate to allow timely decisions regarding required disclosures.concluded that the disclosure controls and procedures are effective.
Management'sManagement’s Report on Internal Control over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rule 13a-15(f) of the Exchange Act. The Company’sOur internal control system is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles in the United States of America. Due to its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.
On November 1, 2015, we completed the acquisition of Chalmette Refining. We are in the process of integrating Chalmette Refining's operations, including internal controls over financial reporting and, therefore, management's evaluation and conclusion as to the effectiveness of our disclosure controls and procedures as of the end of the period covered by this Annual Report on Form 10-K excludes any evaluation of the internal control over financial reporting of Chalmette Refining. We expect the integration of Chalmette Refining's operations, including internal controls over financial reporting to be complete in the year ending December 31, 2016. Chalmette Refining accounts for 9% of the Company's total assets and 5% of total revenues of the Company as of and for the year ended December 31, 2015.
Management assessed the effectiveness of our internal control over financial reporting as of December 31, 2015,2018, using the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in Internal Control — Integrated Framework (2013 framework)(2013). Based on such assessment, we conclude that as of December 31, 2015,2018, the Company’s internal control over financial reporting is effective.
This Annual Report on Form 10-K does not include an attestation report of our independent registered public accounting firm regarding internal control over financial reporting as permitted by Item 308(b) of Regulation S-K for non-accelerated filers.
Changes in Internal Control Over Financial Reporting
On November 1, 2015, we completed the acquisition of the Chalmette Refinery. We are in the process of integrating Chalmette's operations, including internal controls over financial reporting. There has been no other change in our internal controlscontrol over financial reporting during the quarter ended December 31, 20152018 that has materially affected, or is reasonably likely to materially affect, our internal controlscontrol over our financial reporting.

ITEM 9B.  OTHER INFORMATION
None.


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PART III
Explanatory Note:
We are a limited liability company wholly ownedwholly-owned and controlled by PBF LLC. PBF Energy is the sole managing member of PBF LLC. Our directors and executive officers are the executive officers of PBF Energy. The compensation paid to these executive officers is for services provided to both entities (i.e., they are not separately compensated for their services as an officer or director of PBF Holding). PBF Holding does not file a proxy statement. If the information were required it would be identical (other than as expressly set forth below) to the information contained in Items 10, 11, 12, 13 and 14 of Annual Report on Form 10-K of PBF Energy that will appear in the Proxy Statement of PBF Energy furnished to its stockholders in connection with its 20162019 Annual Meeting. Such information is incorporated by reference in this Annual Report on Form 10-K.



ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERANCE
Directors and Executive Officers of PBF Holding
The following is a list of our directors and executive officers as of February 29, 2016:
March 6, 2019: 
Name Age (as of December 31, 2018) Position
Thomas J. Nimbley 64
67
 Chief Executive Officer
Matthew C. Lucey
 42
45
 President
Erik Young 39
41
 Senior Vice President, Chief Financial Officer
Jeffrey DillPaul Davis 54
56
 President, Western Region
Thomas L. O'ConnorO’Connor 43
46
 Senior Vice President, Commercial
Herman Seedorf 64
67
 Senior Vice President, of Refining
Paul Davis53
Senior Vice President, Western Region Commercial Operations
Trecia Canty 46
49
 Senior Vice President, General Counsel & Corporate Secretary
Messrs. Nimbley and Lucey and DillMs. Canty serve as the sole directors of PBF Holding and PBF Finance. We believe that each of their experience as executive officers of PBF Holding make them qualified to serve as its directors.
Thomas J. Nimbley has served on the Board of Directors of PBF Energy since October 2014 and on our Board of Directors since October 2012 and during the period from April 2010 to January 2011. He has served as our and PBF Energy'sEnergy’s Chief Executive Officer since June 2010 and was Executive Vice President, Chief Operating Officer from March 2010 through June 2010. In his capacity as our Chief Executive Officer, Mr. Nimbley also serves as a director and the Chief Executive Officer of certain of our subsidiaries and our affiliates, including Chairman of the Board of PBF GP. Prior thereto, heto joining us, Mr. Nimbley served as a Principal for Nimbley Consultants LLC from June 2005 to March 2010, where he provided consulting services and assisted on the acquisition of two refineries. He previously served as Senior Vice President and head of Refining for Phillips Petroleum Company (“Phillips”) and subsequently Senior Vice President and head of Refining for ConocoPhillips (“ConocoPhillips”) domestic refining system (13 locations) following the merger of Phillips and Conoco Inc. Before joining Phillips at the time of its acquisition of Tosco Corporation (“Tosco”) in September 2001, Mr. Nimbley served in various positions with Tosco Corporation (“Tosco”) and its subsidiaries starting in April 1993.
Matthew C. Lucey has served as our and PBF Energy'sEnergy’s President since January 2015 and was our Executive Vice President from April 2014 to December 2014. Mr. Lucey served as our Senior Vice President, Chief Financial Officer from April 2010 to March 2014. Mr. Lucey joined us as Vice President, Finance in April 2008. Mr. Lucey hasis also served as onea director of our directors since joining us.certain of PBF Energy’s subsidiaries, including PBF GP. Prior thereto, Mr. Lucey served as a Managing Director

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of M.E. Zukerman & Co., a New York-based private equity firm specializing in several sectors of the broader energy industry, from 2001 to 2008. Before joining M.E. Zukerman & Co., Mr. Lucey spent six years in the banking industry.
Erik Young has served as our and PBF Energy'sEnergy’s Senior Vice President and Chief Financial Officer since April 2014 after joining us in December 2010 as Director, Strategic Planning where he was responsible for both corporate development and capital markets initiatives. Mr. Young is also a director of certain of PBF Energy’s subsidiaries, including PBF GP. Prior to joining the Company, Mr. Young spent eleven years in corporate finance, strategic planning and mergers and acquisitions roles across a variety of industries. He began his career in investment banking before joining J.F. Lehman & Company, a private equity investment firm, in 2001.
Jeffrey Dill has served as our and PBF Energy's President, PBF Energy Western Region LLC since September 2015 and was our and PBF Energy's Senior Vice President, General Counsel and Secretary for more than five years prior thereto. Previously he served as Senior Vice President, General Counsel and Secretary for Maxum Petroleum, Inc., a national marketer and logistics company for petroleum products and Vice President, General Counsel and Secretary at Neurogen Corporation, a drug discovery and development company, from March 2006 to December 2007. Mr. Dill has close to 20 years' experience providing business and legal support to refining, transportation and marketing organizations in the petroleum industry, including positions at Premcor, ConocoPhillips, Tosco and Unocal Corporation.
Thomas L. O’Connor has served as our and PBF Energy Senior Vice President, Commercial since September 2015. Mr. O'Connor joined us and PBF Energy as Senior Vice President in September 2014 with responsibility for business development and growing the business of PBFX, and from January to September 2015, served as Co-Head of commercial activities. Prior to joining the Company, Mr. O'Connor worked at Morgan Stanley since 2000 in various positions, most recently as a Managing Director and Global Head of Crude Oil Trading and Global Co-Head of Oil Flow Trading. Prior to joining Morgan Stanley, Mr. O'Connor worked for Tosco from 1995 to 2000 in the Atlantic Basin Fuel Oil and Feedstocks group.
Herman Seedorf serves as our and PBF Energy's Senior Vice President of Refining. Mr. Seedorf originally joined PBF Energy in February of 2011 as the Delaware City Refinery Plant Manager and became Senior Vice President, Eastern Region Refining, in September of 2013. Prior to 2011, Mr. Seedorf served as the refinery manager of the Wood River Refinery in Roxana, Illinois, and also as an officer of the joint venture between ConocoPhillips and Cenovus Energy Inc. Mr. Seedorf's oversight responsibilities included the development and execution of the multi-billion dollar upgrade project which enabled the expanded processing of Canadian crude oils. He also served as the refinery manager of the Bayway Refinery in Linden, New Jersey for four years during the time period that it was an asset of Tosco. Mr. Seedorf began his career in the petroleum industry with Exxon Corporation (“Exxon”) in 1980.
Paul Davis has served as our and PBF Energy’s President, PBF Energy Western Region LLC since September 2017. Mr. Davis joined us in April of 2012 and held various executive roles in our commercial operations, including Co-Head of Commercial, prior to serving as Senior Vice President, Western Region Commercial Operations sincefrom September 2015. Mr. Davis joined us in April 2012 and has been head of PBF's commercial operations related to crude oil and refinery feedstock sourcing since May of 2013 and, from January 2015 to September 2015, served as our Co-Head of Commercial.2017. Previously, Mr. Davis was responsible for managing the U.S. clean products commercial operations for Hess Energy Trading Company (“HETCO”) from 2006 to 2012. Prior to that, Mr. Davis was responsible for Premcor’s U.S. Midwest clean products disposition group. Mr. Davis has over 29 years of experience in commercial operations in crude oil and refined products, including 16 years with the ExxonMobil Corporation in various operational and commercial positions, including sourcing refinery feedstocks and crude oil and the disposition of refined petroleum products, as well as optimization roles within refineries.
Thomas L. O’Connor has served as our and PBF Energy Senior Vice President, Commercial since September 2015. Mr. O’Connor joined us and PBF Energy as Senior Vice President in September 2014 with responsibility for business development and growing the business of PBFX, and from January to September 2015, served as Co-Head of commercial activities. Prior to joining us, Mr. O’Connor worked at Morgan Stanley since 2000 in various positions, most recently as a Managing Director and Global Head of Crude Oil Trading and Global Co-Head of Oil Flow Trading. Prior to joining Morgan Stanley, Mr. O’Connor worked for Tosco from 1995 to 2000 in the Atlantic Basin Fuel Oil and Feedstocks group.
Herman Seedorf serves as our and PBF Energy’s Senior Vice President of Refining. Mr. Seedorf originally joined us in February of 2011 as the Delaware City Refinery Plant Manager and became Senior Vice President, Eastern Region Refining, in September of 2013. Prior to 2011, Mr. Seedorf served as the refinery manager of the Wood River Refinery in Roxana, Illinois, and also as an officer of the joint venture between ConocoPhillips and Cenovus Energy Inc. Mr. Seedorf’s oversight responsibilities included the development and execution of the multi-billion dollar upgrade project which enabled the expanded processing of Canadian crude oils. He also served as the refinery manager of the Bayway Refinery in Linden, New Jersey for four years during the time period that it was an asset of Tosco. Mr. Seedorf began his career in the petroleum industry with Exxon Corporation (“Exxon”) in 1980.
Trecia Canty has served as our Senior Vice President, General Counsel and Secretary since September 2015. In her role, Ms. Canty is responsible for the Legal Departmentlegal department and Contracts Administration.outside counsel, which provide a broad range of support for the Company’s business activities, including corporate governance, compliance, litigations and mergers and acquisitions. Previously, Ms. Canty was named Vice President, Senior Deputy General Counsel and Assistant Secretary in October 2014 and led the Company'sour commercial and finance legal operations since joining us in November 2012. Ms. Canty is also a director of certain of PBF Energy’s subsidiaries. Prior to joining the Company,us, Ms. Canty served as Associate General Counsel, Corporate and Assistant Secretary of Southwestern Energy Company, where her responsibilities included finance and mergers and acquisitions, securities and corporate compliance and corporate governance. She also provided legal support to the midstream marketing and logistics

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businesses. Prior to joining Southwestern Energy Company in 2004, she was an associate with Cleary, Gottlieb, Steen & Hamilton. Ms. Canty has over 20 years of experience focused on energy, mergers and acquisition, securities, finance and corporate matters. Ms. Canty has supported a broad range of functions across the PBF organization and has played a vital role in multiple financings, the Chalmette and Torrance acquisitions, and numerous commercial arrangements.
Mr. Thomas O'Malley is the uncle, by marriage, of Mr. Matthew Lucey.
Corporate Governance Matters
PBF Energy, our indirect parent, has adopted a Code of Business Conduct and Ethics that applies to our principal executive officer, principal financial officer and principal accounting officer. The Code of Business Conduct and Ethics is available at www.pbfenergy.com under the heading “Investors”. Any amendments to the Code of Business Conduct and Ethics or any grant of a waiver from the provisions of the Code of Business Conduct and Ethics requiring disclosure under applicable Securities and Exchange Commission rules will be disclosed on such website.
Additional information required by this Item will be contained in PBF Energy's 2016Energy’s 2019 Proxy Statement, incorporated herein by reference.



ITEM 11. EXECUTIVE COMPENSATION
Compensation of Directors of PBF Holding Company LLC
Directors of PBF Holding receive no separate compensation for service on the board of directors or committees thereof.
Additional information required under this Item will be contained in PBF Energy’s 20162019 Proxy Statement, incorporated herein by reference.


ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
As of December 31, 2015,2018, 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. Refer to Note 1412 “Equity Structure” of our Notes to Consolidated Financial Statements.
The stockholders of PBF Energy may be deemed to beneficially own an interest in our membership interests by virtue of their beneficial ownership of shares of Class A common stock of PBF Energy. PBF Energy reports separately on the beneficial ownership of its officers, directors and significant stockholders. For additional information, we refer you to PBF Energy’s 20162019 Proxy Statement, which is incorporated herein by reference.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
Refer to Note“Note 10 “Intercompany Notes Payable”, Note 12 “Related- Related Party Transactions” and Note 21 “Subsequent“Note 19 - Subsequent Events” of our Notes to Consolidated Financial Statements.



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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Deloitte & Touche LLP (“Deloitte”) is our independent registered public accounting firm. Our audit fees are determined as part of the overall audit fees for PBF Energy and are approved by the audit committee of the board of directors of PBF Energy. PBF Energy reports separately on the fees and services of its principal accountants. For additional information, we refer you to PBF Energy’s 20162019 Proxy Statement, which is incorporated herein by reference.
The following table presents fees billed for the years ended December 31, 20152018 and 20142017 for professional services performed by Deloitte.
201520142018 2017
Audit Fees and Expenses (1)
$3,365,000
$3,011,317
$4,572,000
 $4,299,000
Audit-related Fees (2)
2,001,184
2,269,518
248,000
 588,000
Tax Fees (3)
92,605
97,657
121,524
 
All Other Fees


 
Total Fees and Expenses$5,458,789
$5,378,492
$4,941,524
 $4,887,000
    
(1) Represents the aggregate fees for professional services rendered by Deloitte in connection with its audits of PBF Holding and its indirect parent, PBF Energy's consolidated financial statements, including the audits of internal control over financial reporting of PBF Energy, and reviews of the condensed consolidated financial statements included in Quarterly Reports on Form 10-Q.
(2) Represents fees for professional services rendered in connection with various filings for PBF Energy and its subsidiaries, audits performed (i) related to the Delaware City Products Pipeline and Truck Rack and PBF LLC (ii) services rendered in connection with the PBF Energy February Secondary Offering, October 2015 Equity Offering and the 2023 Senior Secured Notes offering, and consultations on accounting issues.
(1) Represents the aggregate fees for professional services rendered by Deloitte in connection with its audits of PBF Holding and its indirect parent, PBF Energy’s consolidated financial statements, including the audits of internal control over financial reporting of PBF Energy, reviews of the condensed consolidated financial statements included in Quarterly Reports on Form 10-Q and related accounting consultation services provided to support the performance of such audits.(1) Represents the aggregate fees for professional services rendered by Deloitte in connection with its audits of PBF Holding and its indirect parent, PBF Energy’s consolidated financial statements, including the audits of internal control over financial reporting of PBF Energy, reviews of the condensed consolidated financial statements included in Quarterly Reports on Form 10-Q and related accounting consultation services provided to support the performance of such audits.
(2) Represents fees for professional services rendered in connection with various filings for PBF Energy and its subsidiaries, including (i) services rendered in connection with the filling of multiple registration statements with the SEC, (ii) audits performed relating to subsequent asset contributions by PBF LLC to PBF Logistics LP, and (iii) attestation services performed in connection with certain regulatory filings.(2) Represents fees for professional services rendered in connection with various filings for PBF Energy and its subsidiaries, including (i) services rendered in connection with the filling of multiple registration statements with the SEC, (ii) audits performed relating to subsequent asset contributions by PBF LLC to PBF Logistics LP, and (iii) attestation services performed in connection with certain regulatory filings.
(3) Represents fees associated with tax services rendered for income tax planning and sales, use and excise tax matters.


PART IV

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a)   1. Financial Statements. The consolidated financial statements of PBF Holding Company LLC and subsidiaries, required by Part II, Item 8, are included in Part IV of this report. See Index to Consolidated Financial Statements beginning on page F-1.
2. Financial Statement Schedules and Other Financial Information. No financial statement schedules are submitted because either they are inapplicable or because the required information is included in the consolidated financial statements or notes thereto.
3. Exhibits. Filed as part of this Annual Report on Form 10-K are the following exhibits:
Number  Description
  
Contribution Agreement dated as of February 15, 2017 by and between PBF Energy Company LLC and PBF Logistics LP (incorporated by reference to Exhibit 2.1 of PBF Energy Inc.’s Current Report on Form 8-K (File No. 001-35764) filed on February 22, 2017).
Contribution Agreement dated as of August 31, 2016 by and between PBF Energy Company LLC and PBF Logistics LP (incorporated by reference to Exhibit 2.1 filed with PBF Energy Inc.’s Current Report on Form 8-K dated September 7, 2016 (File No. 001-35764)).
 Sale and Purchase Agreement by and between PBF Holding Company LLC and ExxonMobil Oil Corporation and its subsidiary, Mobil Pacific Pipeline Company as of September 29, 2015. (Incorporated2015 (incorporated by reference to Exhibit 2.1 filed with PBF Energy Inc.’s Current Report on Form 8-K dated October 1, 2015 (File No. 001-35764)).
   
2.2 Sale and Purchase Agreement by and between PBF Holding Company LLC, ExxonMobil Oil Corporation, Mobil Pipe Line Company and PDV Chalmette, L.L.C. as of June 17, 2015. (Incorporated2015 (incorporated by reference to Exhibit 2.1 filed with PBF Energy Inc.’s Current Report on Form 8-K dated June 17, 2015 (File No. 001-35764)).
   

81



 Certificate of Formation of PBF Holding Company LLC (Incorporated by reference to Exhibit 3.1 filed with PBF Holding Company LLC’s Registration Statement on Form S-4 dated January 14, 2013 (Registration No. 333-186007)).
  
 Limited Liability Company Agreement of PBF Holding Company LLC (Incorporated by reference to Exhibit 3.2 filed with PBF Holding Company LLC’s Registration Statement on Form S-4 (Registration No. 333-186007)).
  
 Certificate of Incorporation of PBF Finance Corporation (Incorporated by reference to Exhibit 3.3 filed with PBF Holding Company LLC’s Registration Statement on Form S-4 (Registration No. 333-186007)).
   
 Bylaws of PBF Finance Corporation (Incorporated by reference to Exhibit 3.4 filed with PBF Holding Company LLC’s Registration Statement on Form S-4 (Registration No. 333-186007)).
   
 Indenture dated as of November 24, 2015,May 30, 2017, among PBF Holding Company LLC, PBF Finance Corporation, the Guarantors named on the signature pages thereto, Wilmington Trust, National Association, as Trustee and Deutsche Bank Trust Company Americas, as Paying Agent, Registrar, Transfer Agent Authenticating Agent and Notes CollateralAuthenticating Agent and Form of 7.00%7.25% Senior Secured Note (included as Exhibit A) (Incorporated(incorporated by reference to Exhibit 4.1 filed withof PBF Energy Inc.’sHolding Company LLC’s Current Report on Form 8-K dated November 30, 2015 (File No. 001-35764)) filed on May 30, 2017).
   
4.2 Registration Rights Agreement dated November 24, 2015, among PBF Holding Company LLCEnergy Inc. Amended and PBF Finance Corporation, the Guarantors named therein and UBS Securities LLC, as Representative of the several Initial Purchasers (IncorporatedRestated 2012 Equity Incentive Plan (incorporated by reference to Exhibit 4.3DEF 14A filed with PBF Energy Inc.’s Current Report on Form 8-KProxy Statement dated November 30, 2015March 22, 2016 (File No. 001-35764)).


PBF Energy Inc. Amended and Restated 2017 Equity Incentive Plan (incorporated by reference to Appendix A to PBF Energy Inc.’s Definitive Proxy Statement on Schedule 14A filed on April 13, 2018 (File No. 001-35764)).
   
4.3

 Indenture, dated asForm of February 9, 2012, among PBF Holding Company LLC, PBF Finance Corporation, the Guarantors party thereto, Wilmington Trust, National Association and Deutsche Bank Trust Company Americas (Incorporated by reference to Exhibit 4.2 filed with PBF Energy Inc.’s Amendment No. 2 to Registration Statement on Form S-1 (Registration No. 333-177933))
4.4*First Supplemental Indenture, dated as of November 13, 2015, among Chalmette Refining, L.L.C., Wilmington Trust, National Association and Deutsche Bank Trust Company Americas.
4.5*Second Supplemental Indenture, dated as of November 16, 2015, by and among PBF Holding Company LLC, PBF Finance Corporation,Non-Qualified Stock Option Agreement under the Guarantors named on the signature page thereto and Wilmington Trust, National Association.
10.1**Third Amended and Restated Employment Agreement between PBF Investments LLC and Thomas D. O'Malley, Executive Chairman of the Board of Directors of PBF Energy Inc. as of September 8, 2015. (Incorporated2017 Equity Incentive Plan (incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s Current Report on Form 8-K dated September 11, 2015November 2, 2018 (File No. 001-35764)).
   
10.2

 FirstForm of PBF Energy Performance Share Unit Award Agreement under the Amended and Restated PBF Energy Inc. 2017 Equity Incentive Plan (incorporated by reference to Exhibit 10.2 filed with PBF Energy Inc.’s Current Report on Form 8-K dated November 2, 2018 (File No. 001-35764)).

Form of PBF Energy Performance Unit Award Agreement under the Amended and Restated PBF Energy Inc. 2017 Equity Incentive Plan (incorporated by reference to Exhibit 10.3 filed with PBF Energy Inc.’s Current Report on Form 8-K dated November 2, 2018 (File No. 001-35764)).
Form of Non-Qualified Stock Option Agreement under the PBF Energy Inc. 2012 Equity Incentive Plan (incorporated by reference to Exhibit 10.28 filed with PBF Energy Inc.’s Amendment No. 6 to LoanRegistration Statement on Form S-1 (Registration No. 333-177933)).
Form of Restricted Stock Award Agreement for Non-employee Directors under the PBF Energy Inc. 2012 Equity Incentive Plan. (incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s Quarterly Report on Form 10-Q dated asNovember 7, 2014 (File No. 001-35764)).
Form of April 29, 2015,2016 Restricted Stock Award Agreement for Non-employee Directors under PBF Energy Inc. 2012 Equity Incentive Plan (incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s Quarterly Report on Form 10-Q dated May 5, 2016 (File No. 001-35764)).
Form of Restricted Stock Agreement for Employees under PBF Energy Inc. Amended and among PBF Rail Logistics Company LLC + Credit Agricole Corporate and Investment Bank (IncorporatedRestated 2012 Equity Incentive Plan (incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s Current Report on Form 8-K dated April 29, 2015October 28, 2016 (File No. 001-35764)).
   
10.3 ContributionForm of Restricted Stock Agreement dated as of May 5, 2015 by and betweenfor Employees under PBF Energy Company LLCInc. 2012 Equity Incentive Plan (incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s Quarterly Report on Form 10-Q dated November 4, 2016 (File No. 001-35764)).
Form of Restricted Stock Agreement for Directors under the PBF Energy Inc. 2017 Equity Incentive Plan (incorporated by reference to Exhibit 10.4 filed with PBF Energy Inc.’s Quarterly Report on Form 10-Q dated August 3, 2017 (File No. 001-35764)).
Form of 2017 Equity Incentive Plan Restricted Stock Agreement (incorporated by reference to Exhibit 10.1 of PBF Energy Inc.’s Current Report on Form 8-K (File No. 001-35764) filed on October 31, 2017). 
Form of 2017 Equity Incentive Plan Non-Qualified Stock Agreement (incorporated by reference to Exhibit 10.2 of PBF Energy Inc.’s Current Report on Form 8-K (File No. 001-35764) filed on October 31, 2017). 
Form of Amended and Restated Non-Qualified Stock Option Agreement under the PBF Logistics LP (IncorporatedEnergy Inc. 2017 Equity Incentive Plan (incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s Current Report on Form 8-K dated May 5, 2015February 16, 2018 (File No. 001-35764)).
   
10.4 Third Amended and Restated OmnibusRestricted Stock Agreement dated as of May 15, 2015 among PBF Holding Company LLC,for non-employee Directors under the PBF Energy Company LLC, PBF Logistics GP LLC and PBF Logistics LP (IncorporatedInc. 2017 Equity Incentive Plan. (incorporated by reference to Exhibit 10.1 filed with10.3 of PBF Energy Inc.’s CurrentAnnual Report on Form 8-K dated May 12, 201510-K (File No. 001-35764)) filed on February 23, 2018). 
   
10.5 ThirdForm of Amended and Restated Restricted Stock Agreement under PBF Energy Inc. 2017 Equity Incentive Plan (incorporated by reference to Exhibit 10.7 of PBF Energy Inc.’s Annual Report on Form 10-K (File No. 001-35764) filed on February 23, 2018). 


Fifth Amended and Restated Operation and Management Services and Secondment Agreement dated as of May 15, 2015February 28, 2017 among PBF Holding Company LLC, Delaware City Refining Company LLC, Toledo Refining Company LLC, Torrance Refining Company LLC, Torrance Logistics Company LLC, PBF Logistics GP LLC , PBF Logistics LP, Delaware City Terminaling Company LLC, Delaware Pipeline Company LLC, Delaware City Logistics Company LLC, and Toledo Terminaling Company LLC, (IncorporatedPBFX Operating Company LLC, Paulsboro Refining Company LLC, Paulsboro Natural Gas Pipeline Company LLC and Chalmette Refining L.L.C. (incorporated by reference to Exhibit 10.210.1 of PBF Energy Inc.’s Current Report on Form 8-K (File No. 001-35764) filed on March 3, 2017).
Transportation Services Agreement dated as of August 31, 2016 among PBF Holding Company LLC and Torrance Valley Pipeline Company LLC (incorporated by reference to Exhibit 10.3 filed with PBF Energy Inc.’s Current Report on Form 8-K dated September 7, 2016 (File No. 001-35764)).
Pipeline Service Order dated as of August 31, 2016, by and between Torrance Valley Pipeline Company LLC, and PBF Holding Company LLC (incorporated by reference to Exhibit 10.4 filed with PBF Energy Inc.’s Current Report on Form 8-K dated September 7, 2016 (File No. 001-35764)).
Pipeline Service Order dated as of August 31, 2016, by and between Torrance Valley Pipeline Company LLC, and PBF Holding Company LLC (incorporated by reference to Exhibit 10.5 filed with PBF Energy Inc.’s Current Report on Form 8-K dated September 7, 2016 (File No. 001-35764)).
Dedicated Storage Service Order dated as of August 31, 2016, by and between Torrance Valley Pipeline Company LLC, and PBF Holding Company LLC (incorporated by reference to Exhibit 10.6 filed with PBF Energy Inc.’s Current Report on Form 8-K dated September 7, 2016 (File No. 001-35764)).
Throughput Storage Service Order dated as of August 31, 2016, by and between Torrance Valley Pipeline Company LLC, and PBF Holding Company LLC (incorporated by reference to Exhibit 10.7 filed with PBF Energy Inc.’s Current Report on Form 8-K dated September 7, 2016 (File No. 001-35764)).
Senior Secured Revolving Credit Agreement dated as of May 2, 2018 (incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s Current Report on Form 8-K dated May 12, 20157, 2018 (File No. 001-35764)).
Sixth Amended and Restated Operation and Management Services and Secondment Agreement dated as of July 31, 2018, among PBF Holding Company LLC, Delaware City Refining Company LLC, Toledo Refining Company LLC, Torrance Refining Company LLC, Torrance Logistics Company LLC, Chalmette Refining L.L.C., Paulsboro Refining Company LLC, PBF Logistics GP LLC, PBF Logistics LP, DCR Storage and Loading LLC, Delaware City Terminaling Company LLC, Toledo Terminaling Company LLC, Delaware Pipeline Company LLC, Delaware City Logistics Company LLC, Paulsboro Terminaling Company LLC, Paulsboro Natural Gas Pipeline Company LLC, Toledo Rail Logistics Company LLC, Chalmette Logistics Company LLC and PBFX Operating Company LLC (incorporated by reference to Exhibit 10.3 filed with PBF Logistics LP’s Quarterly Report on Form 10-Q dated October 31, 2018 (File No. 001-36446)).
Fifth Amended and Restated Omnibus Agreement dated as of July 31, 2018, among PBF Holding Company LLC, PBF Energy Company LLC, PBF Logistics GP LLC and PBF Logistics LP (incorporated by reference to Exhibit 10.2 filed with PBF Logistics LP’s Quarterly Report on Form 10-Q dated October 31, 2018 (File No. 001-36446)).
Amended and Restated Delaware City Rail Terminaling Services Agreement (incorporated by reference to Exhibit 10.1 filed with PBF Logistics LP’s Quarterly Report on Form 10-Q dated May 3, 2018 (File No. 001-36446)).
Amended and Restated Delaware City West Ladder Rack Terminaling Services Agreement (incorporated by reference to Exhibit 10.2 filed with PBF Logistics LP’s Quarterly Report on Form 10-Q dated May 3, 2018 (File No. 001-36446)).

82




10.6 Delaware Pipeline Services Agreement dated as of May 15, 2015 among PBF Holding Company LLC and Delaware Pipeline Company LLC (Incorporated(incorporated by reference to Exhibit 10.3 filed with PBF Energy Inc.’s Current Report on Form 8-K dated May 12, 2015 (File No. 001-35764)).
   
10.7 Delaware City Truck Loading Services Agreement dated as of May 15, 2015 among PBF Holding Company LLC and Delaware City Logistics Company LLC (Incorporated(incorporated by reference to Exhibit 10.4 filed with PBF Energy Inc.’s Current Report on Form 8-K dated May 12, 2015 (File No. 001-35764)).
   
10.8 **Employment Agreement dated as of September 4, 2014 between PBF Investments LLC and Thomas O'Connor (Incorporated by reference to Exhibit 10.9 filed with PBF Energy Inc.'s Annual Report on Form 10-K (File No. 001-35764))
10.9† Inventory Intermediation Agreement dated as of May 29, 2015 (as amended) between J. Aron & Company and PBF Holding Company LLC and Paulsboro Refining Company LLC (Incorporated(incorporated by reference to Exhibit 10.9 filed with PBF Energy Inc.'s June 30, 2015’s Quarterly Report on Form 10-Q dated August 6, 2015 (File No. 001-35764)).
   
10.10† Inventory Intermediation Agreement dated as of May 29, 2015 (as amended) between J. Aron & Company and PBF Holding Company LLC and Delaware City Refining Company LLC (Incorporated(incorporated by reference to Exhibit 10.10 filed with PBF Energy Inc.'s June 30, 2015’s Quarterly Report on Form 10-Q dated August 6, 2015 (File No. 001-35764)).
   
10.11 Consulting Services Agreement dated as of January 31, 2015 between PBF Investments LLC and Michael D. Gayda (Incorporated by referenceAmendment to Exhibit 10.1 filed with PBF Energy Inc.'s March 31, 2015 Form 10-Q (File No. 001-35764))
10.12Third Amended and Restated Revolving Credit Agreement, dated as of August 15, 2014, among PBF Holding Company LLC, Delaware City Refining Company LLC, Paulsboro Refining Company LLC, Toledo Refining Company LLC and UBS Securities LLC (Incorporated by reference to Exhibit 10.2 filed with PBF Energy Inc.'s September 30, 2014 Form 10-Q (File No. 001-35764))
10.13Revolving Credit Agreement, dated as of March 26, 2014, by and among PBF Rail Logistics Company LLC and Credit Agricole Corporate and Investment Bank (Incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.'s March 31, 2014 Form 10-Q (File No. 001-35764))
10.14Contribution, Conveyance and Assumptionthe Inventory Intermediation Agreement dated as of May 14, 2014 by and4, 2017, among PBF Logistics LP, PBF Logistics GP LLC, PBF Energy Inc., PBF EnergyJ. Aron & Company, LLC, PBF Holding Company LLC Delaware Cityand Paulsboro Refining Company LLC Delaware City Terminaling Company LLC and Toledo Refining Company LLC (Incorporated(incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s CurrentQuarterly Report on Form 8-K10-Q dated May 14, 2014August 3, 2017 (File No. 001-35764)).
   
10.15Amendment to the Inventory Intermediation Agreement dated as of May 4, 2017, among J. Aron & Company, PBF Holding Company LLC and Delaware City Refining Company LLC (incorporated by reference to Exhibit 10.2 filed with PBF Energy Inc.’s Quarterly Report on Form 10-Q dated August 3, 2017 (File No. 001-35764)).
Amendment to the Inventory Intermediation Agreement dated as of September 8, 2017, among J. Aron & Company, PBF Holding Company LLC and Delaware City Refining Company LLC (incorporated by reference to Exhibit 10.2 of PBF Energy Inc.’s Current Report on Form 8-K/A (File No. 001-35764) filed on September 18, 2017).
Amendment to the Inventory Intermediation Agreement dated as of September 8, 2017, among J. Aron & Company, PBF Holding Company LLC and Paulsboro Refining Company LLC (incorporated by reference to Exhibit 10.1 of PBF Energy Inc.’s Current Report on Form 8-K/A (File No. 001-35764) filed on September 18, 2017).
 Delaware City Rail Terminaling Services Agreement, dated as of May 14, 2014 (Incorporated(incorporated by reference to Exhibit 10.4 filed with PBF Energy Inc.’s Current Report on Form 8-K dated May 14, 2014 (File No. 001-35764)).
   
10.16 Amended and Restated Toledo Truck Unloading & Terminaling Agreement effective as of June 1, 2014 (Incorporated(incorporated by reference to Exhibit 10.10 filed with PBF Energy Inc.'s June 30, 2014’s Quarterly Report on Form 10-Q dated August 7, 2014 (File No. 001-35764)).
   
10.16.1 Assignment and Amendment of Amended and Restated Toledo Truck Unloading & Terminaling Agreement dated as of December 12, 2014 by and between PBF Holding Company LLC, PBF Logistics LP and Toledo Terminaling Company LLC (Incorporated(incorporated by reference to Exhibit 10.4 filed with PBF Logistics LP'sLP’s Current Report on Form 8-K filed ondated December 16, 2014 (File No. 001-36446)).
   
10.17 ContributionFirm Transportation Service Agreement dated as of September 16, 2014 among PBF EnergyAugust 3, 2017, by and between Paulsboro Natural Gas Pipeline Company LLC and PBF Logistics LP (IncorporatedPaulsboro Refining Company LLC (incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s CurrentLogistics LP’s Quarterly Report on Form 8-K10-Q dated September 19, 2014November 2, 2017 (File No. 001-35764))

83



10.18Delaware City West Ladder Rack Terminaling Services Agreement, dated as of October 1, 2014 among PBF Holding Company LLC and Delaware City Terminaling Company LLC (Incorporated by reference to Exhibit 10.3 filed with PBF Energy Inc.’s Current Report on Form 8-K dated October 2, 2014 (File No. 001-35764))001-36446).
   
10.19Contribution Agreement, dated as of December 2, 2014 by and between PBF Energy Company LLC and PBF Logistics LP (Incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s Current Report on Form 8-K dated December 5, 2014 (File No. 001-35764))
10.20 Storage and Terminaling Services Agreement dated as of December 12, 2014 among PBF Holding Company LLC and Toledo Terminaling Company LLC (Incorporated(incorporated by reference to Exhibit 10.3 to the Current Report on Form 8-K filed on December 16, 2014 (File No. 001-36446)).


Employment Agreement dated as of September 4, 2014 between PBF Investments LLC and Thomas O’Connor (incorporated by reference to Exhibit 10.9 filed with PBF Energy Inc.’s Annual Report on Form 10-K dated February 29, 2016 (File No. 001-35764)).
   
10.21*Employment Agreement dated as of April 1, 2014 between PBF Investments LLC and Timothy Paul Davis (incorporated by reference to Exhibit 10.4 filed with PBF Energy Inc.’s Quarterly Report on Form 10-Q dated May 7, 2014 (File No. 001-35764)).
Employment Agreement dated as of April 1, 2014 between PBF Investments LLC and Erik Young (incorporated by reference to Exhibit 10.2 filed with PBF Energy Inc.’s Quarterly Report on Form 10-Q dated May 7, 2014 (File No. 001-35764)).
 Amended and Restated Employment Agreement dated as of December 17, 2012, between PBF Investments LLC and Thomas J. Nimbley (Incorporated(incorporated by reference to Exhibit 10.8 filed with PBF Energy Inc.’s Current Report on Form 8-K dated December 18, 2012 (File No. 001-35764)).
   
10.22* Second Amended and Restated Employment Agreement, dated as of December 17, 2012, between PBF Investments LLC and Matthew C. Lucey (Incorporated(incorporated by reference to Exhibit 10.9 filed with PBF Energy Inc.’s Current Report on Form 8-K dated December 18, 2012 (File No. 001-35764)).
   
10.23**Employment Agreement dated as of April 1, 2014 between PBF Investments LLC and Erik Young. (Incorporated by reference to Exhibit 10.2 filed with PBF Energy Inc.'s March 31, 2014 Form 10-Q (File No. 001-35764))
10.24**PBF Energy Inc. 2012 Equity Incentive Plan (Incorporated by reference to Exhibit 10.6 filed with PBF Energy Inc.’s Current Report on Form 8-K dated December 18, 2012 (File No. 001-35764))
10.25**Form of Restricted Stock Award Agreement for Directors under the PBF Energy Inc. 2012 Equity Incentive Plan. (Incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.'s September 30, 2014 Form 10-Q (File No. 001-35764))
10.26**Form of Non-Qualified Stock Option Agreement under the PBF Energy Inc. 2012 Equity Incentive Plan (Incorporated by reference to Exhibit 10.28 filed with PBF Energy Inc.’s Amendment No. 6 to Registration Statement on Form S-1 (Registration No. 333-177933))
12.1*Computation of Ratios of Earnings to Fixed Charge of PBF Holding Company LLC
 Subsidiaries of PBF Holding Company LLC
  
 Power of Attorney (included on signature page)
   
 Certification by Chief Executive Officer of PBF Holding Company LLC pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
   
 Certification by Chief Financial Officer of PBF Holding Company LLC pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
   
 Certification by Chief Executive Officer of PBF Holding Company LLC pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
  
 Certification by Chief Financial Officer of PBF Holding Company LLC pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
   
101.INS XBRL Instance Document.
   
101.SCH XBRL Taxonomy Extension Schema Document.
   
101.CAL XBRL Taxonomy Extension Calculation Linkbase Document.
   
101.DEF XBRL Taxonomy Extension Definition Linkbase Document.
   
101.LAB XBRL Taxonomy Extension Label Linkbase Document.
   
101.PRE XBRL Taxonomy Extension Presentation Linkbase Document.

84




 ——————————
*Filed herewith.
  
**Indicates management compensatory plan or arrangement.
  
Confidential treatment has been granted by the SEC as to certain portions, which portions have been omitted and filed separately with the SEC.
  
(1)This exhibit should not be deemed to be “filed” for purposes of Section 18 of the Exchange Act.



85


PBF HOLDING COMPANY LLC
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
 


F- 1




REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To PBF Energy Inc., the Managing Member of
PBF Holding Company LLC

Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of PBF Holding Company LLC and subsidiaries (the “Company”"Company") as of December 31, 20152018 and 2014, and2017, the related consolidated statements of operations, comprehensive income, changes in equity, and cash flows, for each of the three years in the period ended December 31, 2015. 2018, and the related notes (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2018 and 2017, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2018, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company’sCompany's management. Our responsibility is to express an opinion on thesethe Company's financial statements based on our audits.

We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States).PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement.misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. OurAs part of our audits, included considerationwe are required to obtain an understanding of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company'sCompany’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence supportingregarding the amounts and disclosures in the financial statements, assessingstatements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statement presentation.statements. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of PBF Holding Company LLC and subsidiaries as of December 31, 2015 and 2014, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2015, in conformity with accounting principles generally accepted in the United States of America.

/s/ Deloitte & Touche LLP

Parsippany, New Jersey
March 24, 20166, 2019


We have served as the Company's auditor since 2011.


F- 2



PBF HOLDING COMPANY LLC
CONSOLIDATED BALANCE SHEETS
(in thousands)
December 31,
2015
 December 31,
2014
December 31,
2018
 December 31,
2017
ASSETS      
Current assets:      
Cash and cash equivalents$914,749
 $218,403
$561,691
 $526,160
Accounts receivable454,759
 551,269
710,695
 951,129
Accounts receivable - affiliate3,438
 3,223
12,047
 8,352
Inventories1,174,272
 1,102,261
1,864,056
 2,213,797
Prepaid expense and other current assets33,701
 32,157
Prepaid and other current assets52,440
 49,523
Total current assets2,580,919
 1,907,313
3,200,929
 3,748,961
      
Property, plant and equipment, net2,211,090
 1,806,060
2,971,227
 2,805,390
Investment in equity method investee169,472
 171,903
Deferred charges and other assets, net290,713
 300,389
871,848
 779,924
Total assets$5,082,722
 $4,013,762
$7,213,476
 $7,506,178
      
LIABILITIES AND EQUITY      
Current liabilities:      
Accounts payable$314,843
 $335,182
$483,765
 $572,932
Accounts payable - affiliate23,949
 11,630
49,504
 40,817
Accrued expenses1,117,435
 1,129,970
1,579,038
 1,800,859
Current portion of long-term debt
 
Current debt2,378
 10,987
Deferred revenue4,043
 1,227
17,126
 7,495
Note payable
 5,621
Total current liabilities1,460,270
 1,478,009
2,131,811
 2,438,711
      
Delaware Economic Development Authority loan4,000
 8,000
Long-term debt1,236,720
 712,221
1,257,992
 1,626,249
Intercompany notes payable470,047
 122,264
Deferred tax liabilities20,577
 
40,365
 33,155
Other long-term liabilities69,824
 62,752
253,601
 223,961
Total liabilities3,261,438
 2,383,246
3,683,769
 4,322,076
      
Commitments and contingencies (Note 13)
 
Commitments and contingencies (Note 11)
 
      
Equity:      
Member's equity1,479,175
 1,144,100
PBF Holding Company LLC equity   
Member’s equity2,652,424
 2,359,791
Retained earnings349,654
 513,292
890,376
 840,431
Accumulated other comprehensive loss(24,770) (26,876)(23,945) (26,928)
Total PBF Holding Company LLC equity1,804,059
 1,630,516
3,518,855
 3,173,294
Noncontrolling interest17,225
 
10,852
 10,808
Total equity1,821,284
 1,630,516
3,529,707
 3,184,102
Total liabilities and equity$5,082,722
 $4,013,762
$7,213,476
 $7,506,178

See notes to consolidated financial statements.
F- 3



PBF HOLDING COMPANY LLC
CONSOLIDATED STATEMENTS OF OPERATIONS
(in thousands)
 
 Year Ended December 31, Year Ended December 31,
 2015 2014 2013 2018 2017 2016
Revenues $13,123,929
 $19,828,155
 $19,151,455
 $27,164,008
 $21,772,478
 $15,908,537
            
Cost and expenses:            
Cost of sales, excluding depreciation 11,611,599
 18,514,054
 17,803,314
Operating expenses, excluding depreciation 889,368
 880,701
 812,652
General and administrative expenses 166,904
 140,150
 95,794
Cost of products and other 24,744,619
 19,095,827
 13,765,088
Operating expenses (excluding depreciation and amortization expense as reflected below) 1,654,749
 1,626,440
 1,390,135
Depreciation and amortization expense 329,709
 254,271
 204,005
Cost of sales 26,729,077
 20,976,538
 15,359,228
General and administrative expenses (excluding depreciation and amortization expense as reflected below) 253,834
 197,938
 149,510
Depreciation and amortization expense 10,634
 12,964
 5,835
Equity income in investee (17,819) (14,565) (5,679)
(Gain) loss on sale of assets (1,004) (895) (183) (43,094) 1,458
 11,374
Depreciation and amortization expense 191,110
 178,996
 111,479
 12,857,977
 19,713,006
 18,823,056
Total cost and expenses 26,932,632
 21,174,333
 15,520,268
            
Income from operations 265,952
 115,149
 328,399
 231,376
 598,145
 388,269
            
Other income (expense)      
Change in fair value of catalyst lease 10,184
 3,969
 4,691
Other income (expense):      
Change in fair value of catalyst leases 5,587
 (2,247) 1,422
Debt extinguishment costs 
 (25,451) 
Interest expense, net (88,194) (98,001) (94,214) (127,129) (122,628) (129,536)
Other non-service components of net periodic benefit cost 1,109
 (1,402) (580)
Income before income taxes 187,942
 21,117
 238,876
 110,943
 446,417
 259,575
Income tax expense 648
 
 
Income tax expense (benefit) 7,999
 (10,783) 23,689
Net income 187,294
 21,117
 238,876
 102,944
 457,200
 235,886
Less income attributable to noncontrolling interests 274
 
 
Less: net income attributable to noncontrolling interests 44
 95
 269
Net income attributable to PBF Holding Company LLC $187,020
 $21,117
 $238,876
 $102,900
 $457,105
 $235,617

See notes to consolidated financial statements.
F- 4



PBF HOLDING COMPANY LLC
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(in thousands)



Year Ended December 31,Year Ended December 31,
2015 2014 20132018 2017 2016
Net income$187,294
 $21,117
 $238,876
$102,944
 $457,200
 $235,886
Other comprehensive income (loss):
 
  
 
  
Unrealized gain (loss) on available for sale securities124
 127
 (308)
Unrealized loss on available for sale securities(108) (16) (42)
Net gain (loss) on pension and other post-retirement
benefits
1,982
 (12,465) (5,289)3,091
 (950) (2,550)
Total other comprehensive income (loss)2,106
 (12,338) (5,597)2,983
 (966) (2,592)
Comprehensive income189,400
 8,779
 233,279
105,927
 456,234
 233,294
Less: comprehensive income attributable to noncontrolling interests274
 
 
44
 95
 269
Comprehensive income attributable to PBF Holding Company LLC$189,126
 $8,779
 $233,279
$105,883
 $456,139
 $233,025

See notes to consolidated financial statements.
F- 5




PBF HOLDING COMPANY LLC
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(in thousands)
 Member's EquityAccumulated Other Comprehensive Loss Retained
Earnings
 Noncontrolling Interest Total
Equity
 Member's EquityAccumulated Other Comprehensive Loss Retained
Earnings
 Noncontrolling Interest Total
Equity
  
Balance, January 1, 2013 $930,098
 $(8,941) $830,497
 $
 $1,751,654
Member distributions 
 
 (215,846) 
 (215,846)
Member contributions 1,757
 
 
 
 1,757
Stock based compensation 1,309
 
 
 
 1,309
Net income 
 
 238,876
 
 238,876
Other comprehensive loss 
 (5,597) 
 
 (5,597)
Balance, December 31, 2013 933,164
 (14,538) 853,527
 
 1,772,153
Balance, January 1, 2016 $1,479,175
 $(24,770) $349,654
 $17,225
 $1,821,284
Member distributions 
 
 (361,352) 
 (361,352) 
 
 (139,434) 
 (139,434)
Capital contributions 328,664
 
 
 
 328,664
 830,247
 
 
 
 830,247
Distribution of assets to PBF LLC (126,280) 
 
 
 (126,280) (172,743) 
 
 
 (172,743)
Stock based compensation 6,095
 
 
 
 6,095
 18,296
 
 
 
 18,296
Exercise of options and other 2,457
 
 
 
 2,457
 886
 
 
 
 886
Net income 
 
 21,117
 
 21,117
 
 
 235,617
 269
 235,886
Other comprehensive loss 
 (12,338) 
 
 (12,338) 
 (2,592) 
 
 (2,592)
Balance, December 31, 2014 1,144,100
 (26,876) 513,292
 
 1,630,516
Other 2
 1,400
 682
 (4,981) (2,897)
Balance, December 31, 2016 2,155,863
 (25,962) 446,519
 12,513
 2,588,933
Member distributions 
 
 (61,149) 
 (61,149)
Capital contributions 183,298
 
 
 
 183,298
Stock based compensation 21,503
 
 
 
 21,503
Net income 
 
 457,105
 95
 457,200
Other comprehensive loss 
 (966) 
 
 (966)
Other (873) 
 (2,044) (1,800) (4,717)
Balance, December 31, 2017 2,359,791
 (26,928) 840,431
 10,808
 3,184,102
Member distributions 
 
 (350,658) 
 (350,658) 
 
 (52,587) 
 (52,587)
Capital contributions 345,000
 
 
 
 345,000
 287,000
 
 
 
 287,000
Distribution of assets to PBF LLC (19,233) 
 
 
 (19,233) (13,733) 
 
 
 (13,733)
Stock based compensation 9,218
 
 
 
 9,218
 19,697
 
 
 
 19,697
Exercise of options and other 90
 
 
 
 90
Net income 
 
 187,020
 274
 187,294
 
 
 102,900
 44
 102,944
Other comprehensive income 
 2,106
 
 
 2,106
 
 2,983
 
 
 2,983
Noncontrolling interest acquired in Chalmette Acquisition 
 
 
 16,951
 16,951
Balance, December 31, 2015 $1,479,175
 $(24,770) $349,654
 $17,225
 $1,821,284
Other (331) 
 (368) 
 (699)
Balance, December 31, 2018 $2,652,424
 $(23,945) $890,376
 $10,852
 $3,529,707

See notes to consolidated financial statements.
F- 6




PBF HOLDING COMPANY LLC
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands)
 Year Ended December 31,
 2015 2014 2013
Cash flows from operating activities:     
Net income$187,294
 $21,117
 $238,876
Adjustments to reconcile net income to net cash provided by operations:     
Depreciation and amortization199,383
 186,412
 118,001
Stock-based compensation9,218
 6,095
 3,753
Change in fair value of catalyst lease obligation(10,184) (3,969) (4,691)
Non-cash change inventory repurchase obligations63,389
 (93,246) (20,492)
Non-cash lower of cost or market inventory adjustment427,226
 690,110
 
Pension and other post retirement benefits costs26,982
 22,600
 16,728
Gain on disposition of property, plant and equipment(1,004) (895) (183)
      
Changes in current assets and current liabilities:     
Accounts receivable97,636
 45,378
 (92,851)
Due to/from affiliates12,104
 8,407
 14,721
Inventories(271,892) (394,031) 45,991
Prepaid expense and other current assets(631) 23,686
 (42,455)
Accounts payable(25,015) (67,111) 42,236
Accrued expenses(37,737) 59,899
 214,817
Deferred revenue2,816
 (6,539) (202,777)
Other assets and liabilities(27,182) (2,225) (20,403)
Net cash provided by operations652,403
 495,688
 311,271
      
Cash flow from investing activities:     
Acquisition of Chalmette Refining, net of cash acquired(565,304) 
 
Expenditures for property, plant and equipment(352,365) (470,460) (318,394)
Expenditures for deferred turnaround costs(53,576) (137,688) (64,616)
Expenditures for other assets(8,236) (17,255) (32,692)
Proceeds from sale of assets168,270
 202,654
 102,428
Net cash used in investing activities(811,211) (422,749) (313,274)
      
Cash flows from financing activities:     
Proceeds from members' capital contributions345,000
 328,664
 1,757
Distributions to members(350,658) (361,352) (215,846)
Proceeds from intercompany notes payable347,783
 90,631
 31,835
Proceeds from revolver borrowings170,000
 395,000
 1,450,000
Repayments of revolver borrowings(170,000) (410,000) (1,435,000)
Proceeds from Rail Facility revolver borrowings102,075
 83,095
 
Repayments of Rail Facility revolver borrowings(71,938) (45,825) 
Proceeds from 2023 Senior Secured Notes500,000
 
 
Proceeds from catalyst lease
 
 14,337
Payment of contingent consideration related to acquisition of Toledo refinery
 
 (21,357)
Deferred financing costs and other(17,108) (11,719) (1,044)
Net cash provided by (used in) financing activities855,154
 68,494
 (175,318)
      
Net increase (decrease) in cash and cash equivalents696,346
 141,433
 (177,321)
Cash and equivalents, beginning of period218,403
 76,970
 254,291
Cash and equivalents, end of period$914,749
 $218,403
 $76,970
 Year Ended December 31,
 2018 2017 2016
Cash flows from operating activities:     
Net income$102,944
 $457,200
 $235,886
Adjustments to reconcile net income to net cash provided by operating activities:     
Depreciation and amortization346,687
 274,651
 218,933
Stock-based compensation20,212
 21,503
 18,296
Change in fair value of catalyst leases(5,587) 2,247
 (1,422)
Deferred income taxes7,233
 (12,526) 19,802
Non-cash change in inventory repurchase obligations(31,790) 13,779
 29,453
Non-cash lower of cost or market inventory adjustment351,278
 (295,532) (521,348)
Debt extinguishment costs
 25,451
 
Pension and other post-retirement benefit costs47,381
 42,242
 37,987
Income from equity method investee(17,819) (14,565) (5,679)
Distributions from equity method investee17,819
 20,244
 
(Gain) loss on sale of assets(43,094) 1,458
 11,374
      
Changes in operating assets and liabilities:     
Accounts receivable240,433
 (335,248) (161,122)
Due to/from affiliates(3,512) 3,233
 9,721
Inventories(1,537) (54,705) 236,602
Prepaid and other current assets(2,917) (9,191) (5,783)
Accounts payable(110,715) 34,527
 213,514
Accrued expenses(232,995) 353,115
 227,986
Deferred revenue9,631
 (4,845) 8,297
Other assets and liabilities1,319
 (51,974) (20,878)
Net cash provided by operating activities$694,971
 $471,064
 $551,619
      
Cash flows from investing activities:     
Expenditures for property, plant and equipment(277,258) (232,656) (282,430)
Expenditures for deferred turnaround costs(266,028) (379,114) (198,664)
Expenditures for other assets(17,055) (31,143) (42,506)
Acquisition of Torrance refinery and related logistics assets
 
 (971,932)
Chalmette Acquisition working capital settlement
 
 (2,659)
Proceeds from sale of assets48,290
 
 24,692
Equity method investment - return of capital2,431
 1,300
 
Net cash used in investing activities$(509,620) $(641,613) $(1,473,499)

See notes to consolidated financial statements.
F- 7




PBF HOLDING COMPANY LLC
CONSOLIDATED STATEMENTS OF CASH FLOWS (Continued)
(in thousands)

Cash flows from financing activities:     
Contributions from PBF LLC$287,000
 $97,000
 $450,300
Distributions to members(52,587) (61,149) (139,434)
Distributions to T&M and Collins shareholders
 (1,800) 
Payment received for affiliate note receivable
 11,600
 
Proceeds from affiliate notes payable
 
 43,396
Repayments of affiliate notes payable
 
 (53,524)
Proceeds from 2025 Senior Notes
 725,000
 
Cash paid to extinguish 2020 Senior Secured Notes
 (690,209) 
Proceeds from revolver borrowings
 490,000
 550,000
Repayments of revolver borrowings(350,000) (490,000) (200,000)
Repayments of Rail Facility revolver borrowings
 
 (67,491)
Proceeds from PBF Rail Term Loan
 
 35,000
Repayments of PBF Rail Term Loan(6,812) (6,633) 
Repayments of Note payable(5,621) (1,210) 
Catalyst lease settlements(9,108) 10,830
 15,589
Deferred financing costs and other(12,692) (13,425) 
Net cash (used in) provided by financing activities$(149,820) $70,004
 $633,836
      
Net increase (decrease) in cash and cash equivalents35,531
 (100,545) (288,044)
Cash and cash equivalents, beginning of period526,160
 626,705
 914,749
Cash and cash equivalents, end of period$561,691
 $526,160
 $626,705
Year Ended December 31,
2015 2014 2013
Supplemental cash flow disclosure     
Supplemental cash flow disclosures     
Non-cash activities:          
Accrued and unpaid capital expenditures$89,526
 $25,382
 $34,055
Distribution of assets to PBF Energy Company LLC13,733
 25,547
 172,743
Conversion of affiliate notes payable to capital contribution
 86,298
 379,947
Conversion of Delaware Economic Development Authority loan to grant4,000
 4,000
 8,000

 
 4,000
Accrued construction in progress and unpaid fixed assets7,974
 33,296
 33,747
Distribution of assets to PBF Energy Company LLC19,233
 126,280
 
Note payable issued for purchase of property, plant and equipment
 6,831
 
Cash paid during the year for:          
Interest (including capitalized interest of $3,529, $7,487 and $5,672 in 2015, 2014 and 2013, respectively)83,371
 96,346
 92,848
Interest (net of capitalized interest of $9,326, $5,937 and $8,333 in 2018, 2017 and 2016, respectively)$124,429
 $131,416
 $108,547
Income taxes596
 
 2,449


See notes to consolidated financial statements.
F- 8

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

 
1. DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION
Description of the Business
PBF Holding Company LLC (“PBF Holding” or the “Company”), a Delaware limited liability company, together with its consolidated subsidiaries, owns and operates oil refineries and related facilities in North America. PBF Holding is a wholly-owned subsidiary of PBF Energy Company LLC (“PBF LLC”). PBF Energy Inc. (“PBF Energy”) is the sole managing member of, and owner of an equity interest representing approximately 95.1%99.0% of the outstanding economic interest in PBF LLC as of December 31, 2015.2018. PBF Finance CorporationInvestments LLC (“PBF Finance”) is a wholly-owned subsidiary of PBF Holding. Delaware City Refining Company LLC (“DCR”Investments”), PBF Power Marketing LLC, PBF Energy Limited, Paulsboro Refining Company LLC (“Paulsboro Refining”), Paulsboro Natural Gas Pipeline Company LLC, Toledo Refining Company LLC (“Toledo Refining” or “TRC”), 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 MOEM PipelineTorrance Logistics Company LLC are PBF LLC'sLLC’s principal operating subsidiaries and are all wholly-owned subsidiaries of PBF Holding. In addition, PBF LLC, through Chalmette Refining, holds an 80% interest in and consolidates Collins Pipeline Company and T&M Terminal Company. Collectively, PBF Holding and its consolidated subsidiaries are referred to hereinafter as the “Company”.
On May 14, 2014, PBF Logistics LP (“PBFX”), a Delaware master limited partnership, completed its initial public offering (the “PBFX Offering”) of 15,812,500 common units. PBF Logistics GP LLC (“PBF GP”) serves as the general partner of PBFX. PBF GP is wholly-owned by PBF LLC. In connection with the PBFX Offering, PBF Holding distributedcontributed to PBF LLCPBFX the assets and liabilities of certain crude oil terminaling assets, which were immediately contributed by PBF LLC to PBFX. The assets were previously owned and operated by PBF Holding’s subsidiaries, DCR and Toledo Refining. The initial assets distributed consistedassets. In a series of the Delaware City Rail Unloading Terminal (“DCR Rail Terminal”), which was part of PBF Holding’s Delaware City, Delaware refinery, and the Toledo Truck Unloading Terminal (“Toledo Truck Terminal” and together with DCR Rail Terminal, the “Contributed Assets”), which was part of PBF Holding’s Toledo, Ohio refinery. The Contributed Assets did not generate third party or intra-entity revenue prioradditional transactions subsequent to the PBFX Offering. The exchange for the Contributed Assets is described in the Contribution Agreement (as defined herein) (refer to Note 12 “Related Party Transactions” of our Notes to Consolidated Financial Statements).
Effective September 30, 2014,Offering, PBF Holding distributed certain additional assets to PBF LLC, all of the equity interests of DCR's wholly-owned subsidiary, Delaware City Terminaling Company II LLC (“DCT II”), which in turn contributed those assets consist solely of the Delaware City heavy crude unloading rack (the “DCR West Rack”). PBF LLC then contributed to PBFX all of the equity interests of DCT II for total consideration of $150,000, consisting of $135,000 of cash and $15,000 of PBFX common units, or 589,536 common units (the “DCR West Rack Acquisition”(as described in “Note 10 - Related Party Transactions”).
Effective December 11, 2014, PBF Holding distributed to PBF LLC all of the issued and outstanding limited liability company interests of Toledo Terminaling Company LLC (“Toledo Terminaling”), whose assets consist of a tank farm and related facilities located at PBF Energy's Toledo refinery, including a propane storage and loading facility (the “Toledo Storage Facility”). PBF LLC then contributed to PBFX all of the issued and outstanding limited liability company interest of Toledo Terminaling for total consideration to PBF LLC of $150,000, consisting of $135,000 of cash and $15,000 of PBFX common units, or 620,935 common units (the “Toledo Storage Facility Acquisition”).
On May 14, 2015, PBF Holding distributed all of the equity interests of DPC and Delaware City Logistics Company LLC (“DCLC”) to PBF LLC immediately prior to the contribution by PBF LLC to PBFX. The contributed assets consisted of the Delaware City Products Pipeline and Truck Rack, for a total consideration payable to PBF LLC of $143,000, consisting of $112,500 of cash and $30,500 of PBFX common units, or 1,288,420 common units.
Substantially all of the Company’s operations are in the United States. TheAs of December 31, 2018, the Company’s four oil refineries are all engaged in the refining of crude oil and other feedstocks into petroleum products, and have been aggregated to form one reportable segment. To generate earnings and cash flows from operations, the Company is primarily dependent upon processing crude oil and selling refined petroleum products at margins sufficient to cover fixed

F- 9

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

and variable costs and other expenses. Crude oil and refined petroleum products are commodities; and factors that are largely out of the Company’s control can cause prices to vary over time. The resulting potential margin volatility can have a material effect on the Company’s financial position, earnings and cash flow.


F- 9

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation and Presentation
These consolidated financial statements include the accounts of PBF Holding and its consolidated subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation.
Cost Classifications
Cost of products and other consists of the cost of crude oil, other feedstocks, blendstocks and purchased refined products and the related in-bound freight and transportation costs.
Operating expenses (excluding depreciation and amortization) consists of direct costs of labor, maintenance and services, utilities, property taxes, environmental compliance costs and other direct operating costs incurred in connection with our refining operations. Such expenses exclude depreciation related to refining and logistics assets that are integral to the refinery production process, which is presented separately as Depreciation and amortization expense as a component of Cost of sales on the Company’s consolidated statements of operations.
Reclassification
Certain amounts previously reported in the Company'sCompany’s consolidated financial statements for prior periods have been reclassified to conform to the 20152018 presentation. These reclassifications include presentation of deferred financing costs and debt due tocertain details about the Company’s adoption of a recently adopted accounting pronouncement (as discussed below).ASU 2017-07, further explained below, under Recently Adopted Accounting Guidance.
Use of Estimates
The preparation of the financial statements in conformity with U.S.accounting principles generally accepted accounting principlesin 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 yearyears ended December 31, 20152018, 2017 and 2016 no single customer amounted to greater than or equal to 10% of the Company's revenue. Only one customer, ExxonMobil Oil Corporation (“ExxonMobil”), accounted for 10% or more of our total trade accounts receivables as of December 31, 2015. Following the Chalmette Acquisition on November 1, 2015, ExxonMobil and its affiliates represented approximately 18% of our total trade accounts receivable as of December 31, 2015.Company’s revenues.
For the year ended December 31, 2014, no single customer amounted to greater than or equal to 10% of the Company's revenues. No single customer accounted for 10% or more of our total trade accounts receivable as of December 31, 2014.
For the year ended2018 or December 31, 2013, Morgan Stanley Capital Group, Inc. (“MSCG”) and Sunoco, Inc. (R&M) (“Sunoco”) accounted for 29% and 10% of the Company’s revenues, respectively.2017.

F- 10

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

Revenue, Deferred Revenue and Accounts Receivable
ThePrior to January 1, 2018, the Company sells various refined products primarily through its refinery subsidiaries and recognizesrecognized revenue related tofrom customers when all of the sale of products when there isfollowing criteria were met: (i) persuasive evidence of an agreement,exchange arrangement existed, (ii) delivery had occurred or services had been rendered, (iii) the sales prices arebuyer’s price was fixed or determinable and (iv) collectability iswas reasonably assured and when products are shipped or deliveredassured. Amounts billed in accordance with their respective agreements. Revenue for services is recorded when the services have been provided. Certainadvance of the Company's refineries have products offtake agreements with third-partiesperiod in which the service was rendered or product delivered were recorded as deferred revenue. Effective January 1, 2018, the Company adopted ASC 606, as defined below under which these third parties purchase“Recently Adopted Accounting Guidance”. As a portion ofresult, the refineries' daily gasoline production. The refineries also sell their products through short-term contracts or on the spot market.
Prior to July 1, 2013, the Company’s Paulsboro and Delaware City refineries sold light finished products, certain intermediates and lube base oils to MSCG under products offtake agreements with each refinery (the “Offtake Agreements”). On a daily basis, MSCG purchased and paidCompany has changed its accounting policy for the refineries’ production of light finished products as they were produced, delivered to the refineries’ storage tanks, and legal title passed to MSCG. Revenue on these product sales was deferred until they shipped out of the storage facility by MSCG.
Under the Offtake Agreements, the Company’s Paulsboro and Delaware City refineries also entered into purchase and sale transactions of certain intermediates and lube base oils whereby MSCG purchased and paid for the refineries’ production of certain intermediates and lube products as they were produced and legal title passed to MSCG. The intermediate products were held in the refineries’ storage tanks until they were needed for further use in the refining process. The intermediates may also have been sold to third parties. The refineries had the right to repurchase lube products and did so to supply other third parties with that product. When the refineries needed intermediates or lube products, the products were drawn out of the storage tanks, title passed back to the refineries and MSCG was paid for those products. These transactions occurred at the daily market price for the related products. These transactions were considered to be made in contemplation of each other and, accordingly, did not result in the recognition of a salerevenue from contracts with customers. Revenues are recognized when title passed fromcontrol of the refineriespromised goods or services is transferred to MSCG. Inventory remained at costthe customers, in an amount that reflects the consideration the Company expects to be entitled to in exchange for those goods or services. Refer to “Note 15 - Revenues” for further discussion of the Company’s revenue recognition policy, including deferred revenues and the net cash receipts resulted in a liability that was recorded at market price for the volumes held in storage with any change in the market price being recorded in costs of sales. The liability represented the amount the Company expected to pay to repurchase the volumes held in storage.
While MSCG had legal title, it had the right to encumber and/or sell these products and any such sales by MSCG resulted in sales being recognized by the refineries when products were shipped outpractical expedients elected as part of the storage facility. As the exclusive vendor of intermediate productstransition to ASC 606.
On May 4, 2017 and September 8, 2017, PBF Holding and its subsidiaries, DCR and PRC, entered into amendments to the refineries, MSCG had the obligation to provide the intermediate products to the refineries as they were needed. Accordingly, sales by MSCG to others were limited and only made with the Company or its subsidiaries’ approval.
As of July 1, 2013, the Company terminated the Offtake Agreements for the Company’s Paulsboro and Delaware City refineries. The Company entered into two separate inventory intermediation agreements (“Inventory(as amended, the “Inventory Intermediation Agreements”) with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. (“J. Aron”) on June 26, 2013 which commenced upon the termination of the Offtake Agreements with MSCG.
On May 29, 2015, PBF Holding entered into amended and restated inventory intermediation agreements (the “A&R Intermediation Agreements”) with J. Aron, pursuant to which certain terms of the existing inventory intermediation agreements were amended, including, among other things, pricing and an extension of the terms. As a result of the amendments (i) the Inventory Intermediation Agreement by and among J. Aron, PBF Holding and PRC relating to the Paulsboro refinery extends 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 clausesDecember 31, 2019, which term may be further extended by mutual consent of both parties.the parties to December 31, 2020 and (ii) the Inventory Intermediation Agreement by and among J. Aron, PBF Holding and DCR relating to the Delaware City refinery extends the term to July 1, 2019, which term may be further extended by mutual consent of the parties to July 1, 2020.
Pursuant to each A&RInventory Intermediation Agreement, J. Aron will continuecontinues 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 refinerythe Refinery as the Products are discharged out of the Refineries'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&RInventory Intermediation Agreements and will retain these storage rights for the term of the agreements. PBF Holding will continuecontinues to market and sell the Products independently to third parties.

F- 11

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

Until December 31, 2015, the Company's Delaware City refinery sold and purchased feedstocks under a supply agreement with Statoil (the “Crude Supply Agreement”).  This Crude Supply Agreement expired on December 31, 2015. Statoil purchased the refineries' production of certain feedstocks or purchased feedstocks from third parties on the refineries' behalf. Legal title to the feedstocks were held by Statoil and the feedstocks were held in the refineries' storage tanks until they were needed for further use in the refining process. At that time, the products were drawn out of the storage tanks and purchased by the refinery. These purchases and sales were settled monthly at the daily market prices related to those products. These transactions were considered to be made in contemplation of each other and, accordingly, did not result in the recognition of a sale when title passed from the refineries to Statoil. Inventory remained at cost and the net cash receipts resulted in a liability which is discussed further in the Inventory note below. The Company terminated its supply agreement with Statoil for its Paulsboro refinery in March 2013, at which time the Company began to purchase from Statoil the feedstocks owned by them at that date that had been purchased on its behalf. Subsequent to the expiration of the Delaware City Crude Supply Agreement, the Company began to purchase all of its crude and feedstock needs independently from a variety of suppliers on the spot market or through term agreements.
Accounts receivable are carried at invoiced amounts. An allowance for doubtful accounts is established, if required, to report such amounts at their estimated net realizable value. In estimating probable losses, management reviews accounts that are past due and determines if there are any known disputes. There was no allowance for doubtful accounts at December 31, 20152018 and 2014.2017.
Excise taxes on sales of refined products that are collected from customers and remitted to various governmental agencies are reported on a net basis.
InventoryInventories
Inventories are carried at the lower of cost or market. The cost of crude oil, feedstocks, blendstocks and refined products are determined under the last-in first-out (“LIFO”) method using the dollar value LIFO method with increments valued based on average purchase prices during the year. The cost of supplies and other inventories is determined principally on the weighted average cost method.
The Company had the obligation to purchase and sell feedstocks under a supply agreement with Statoil for its Delaware City refinery. This Crude Supply Agreement expired on December 31, 2015. The Company's Paulsboro refinery also had a crude supply agreement with Statoil that was terminated in March 2013. Prior to the expiration or termination of these agreements, Statoil purchased the refineries' production of certain feedstocks or purchased feedstocks from third parties on the refineries' behalf. The Company took title to the crude oil as it was delivered to the processing units, in accordance with the Crude Supply Agreement; however, the Company was obligated to purchase all the crude oil held by Statoil on the Company’s behalf upon termination of the agreement at the then market price. The Paulsboro crude supply agreement also included an obligation to purchase a fixed volume of feedstocks from Statoil on the later of maturity or when the arrangement is terminated based on a forward market price of West Texas Intermediate crude oil. As a result of the purchase obligations, the Company recorded the inventory of crude oil and feedstocks in the refineries’ storage facilities. The Company determined the purchase obligations were contracts that contain derivatives that changed in value based on changes in commodity prices. Such changes in the fair value of these derivatives were included in cost of sales.
Prior to July 31, 2014, the Company’s Toledo refinery acquired substantially all of its crude oil from MSCG under a crude oil acquisition agreement (the “Toledo Crude Oil Acquisition Agreement”). Under the Toledo Crude Oil Acquisition Agreement, the Company took title to crude oil at various pipeline locations for delivery to the refinery or sale to third parties. The Company recorded the crude oil inventory when it received title. Payment for the crude oil was due to MSCG under the Toledo Crude Oil Acquisition Agreement three days after the crude oil was delivered to the Toledo refinery processing units or upon sale to a third party. The Company terminated the Toledo Crude Oil Acquisition Agreement effective July 31, 2014 and began to source its crude oil needs independently.

F- 1211

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

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, Netnet
Deferred charges and other assets include refinery turnaround costs, catalyst, precious metals catalyst,metal catalysts, linefill, deferred financing costs and intangible assets. Refinery turnaround costs, which are incurred in connection with planned major maintenance activities, are capitalized when incurred and amortized on a straight-line basis over the period of time estimated to lapse until the next turnaround occurs (generally 3 to 5 years).
Precious metals catalystmetal catalysts, linefill and linefillcertain other intangibles are considered indefinite-lived assets as they are not expected to deteriorate in their prescribed functions. Such assets are assessed for impairment in connection with the Company’s review of its long-lived assets 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 utilizeutilizes assumptions that it believes are reasonable, future events and changing market conditions may impact management’s assumptions, which could produce different results.

F- 12

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

Investments in Equity Method Investments
For equity investments that are not required to be consolidated under the variable or voting interest model, the Company evaluates the level of influence it is able to exercise over an entity’s operations to determine whether to use the equity method of accounting. The Company’s judgment regarding the level of control over an equity method investment includes considering key factors such as its ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Amounts recognized for equity method investments are included in equity method investments in the consolidated balance sheet and adjusted for the Company’s share of the net earnings and losses of the investee and cash distributions, which are included in the consolidated statements of operations and the consolidated statements of cash flows. Amounts recognized for earnings in excess of distributions of the Company’s equity method investments are included in the operating section of the consolidated statements of cash flows. The Company evaluates its equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. A loss is recorded in earnings in the current period to write down the carrying value of the investment to fair value if a decline in the value of an equity method investment is determined to be other than temporary.
Asset Retirement Obligations
The Company records an asset retirement obligation at fair value for the estimated cost to retire a tangible long-lived asset at the time the Company incurs that liability, which is generally when the asset is purchased, constructed,

F- 13

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

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

F- 13

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

estimated fair value is amortized as stock-based compensation expense on a straight-line method over the vesting period and included in generalGeneral and administration expense.expense with forfeitures recognized in the period they occur.
Beginning in 2018, PBF Energy granted performance share awards and performance unit awards to certain officers of the Company. Both types of awards have a three-year performance cycle and the payout for each, which ranges from 0% to 200%, is based on the relative ranking of the total shareholder return (“TSR”) of PBF Energy’s common stock as compared to the TSR of a selected group of industry peer companies over an average of four measurement periods. The performance share and performance unit awards are each measured at fair value based on Monte Carlo simulation models. The performance share awards will be settled in PBF Energy Class A common stock and are accounted for as equity awards and the performance unit awards will be settled in cash and are accounted for as liability awards.
Income Taxes
As PBF Holding is a limited liability company treated as a “flow-through” entity for income tax purposes, there is no benefit or provisionexpense 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 thatand the Company’s wholly-owned Canadian subsidiary, PBF Energy Limited (“PBF Ltd”). These subsidiaries are treated as C-corporations for tax purposes.
The Federal and state tax returns for all years since 20122015 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 otherOther 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

F- 14

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

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.

F- 14

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

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 partythird-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 consolidated 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.

F- 15

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

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 Adopted Accounting Guidance
In May 2014, the Financial Accounting Standard Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09 (Topic 606) “Revenue from Contracts with Customers.” (“ASC 606”). ASC 606 supersedes the revenue recognition requirements in Accounting Standards Codification 605 “Revenue Recognition” (“ASC 605”), and requires entities to recognize revenue when control of the promised goods or services is transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled to in exchange for those goods or services. The Company adopted ASC 606 as of January 1, 2018 using the modified retrospective transition method. See “Note 15 - Revenues” for further details.

F- 15

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

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 periodic benefit cost in the income statement and on the components eligible for capitalization in assets. Under the new guidance, employers 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 non-service components of the net periodic benefit cost separately from the line item(s) that includes the service cost and outside of any subtotal of income from operations, if one is presented. 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 Company adopted ASU 2017-07 effective January 1, 2018 and applied the new guidance retrospectively in the Consolidated Statements of Operations. Income and expense amounts related to non-service components of net periodic benefit cost, historically recorded within Operating expenses and General and administrative expenses, have been recorded within Other income (expense). For the years ended December 31, 2018, 2017 and 2016 the Company recorded income of $1,109, expense of $1,402 and expense of $580, respectively, related to the non-service components of net periodic benefit cost.
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 Company adopted the amendments in this ASU effective January 1, 2018. The Company’s adoption of this guidance did not materially impact its consolidated financial statements.
Recently Issued Accounting Pronouncements
In February 2015, the FASB issued ASU No. 2015-02, “Consolidations (Topic 810): Amendments to the Consolidation Analysis” (“ASU 2015-02”), which amends current consolidation guidance including changes to both the variable and voting interest models used by companies to evaluate whether an entity should be consolidated. The requirements from ASU 2015-02 are effective for interim and annual periods beginning after December 15, 2015, and early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.
In April 2015, the FASB issued ASU No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs” (“ASU 2015-03”), which requires debt issuance costs related to a recognized debt liability to be presented on the balance sheet as a direct deduction from the debt liability rather than as an asset. The standard is effective for interim and annual periods beginning after December 15, 2015 and early adoption is permitted. The Company early adopted the new standard in its consolidated financial statements and related disclosures, which resulted in a reclassification of $32,217 and $30,128 of deferred financing costs from other assets to long-term debt as of December 31, 2015 and December 31, 2014, respectively.
In August 2015, the FASB issued ASU No. 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date” (“ASU 2015-14”), which defers the effective date of ASU 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”) for all entities by one year. The guidance in ASU 2014-09 will replace most existing revenue recognition guidance in GAAP when it becomes effective. Under ASU 2015-14, this guidance becomes effective for interim and annual periods beginning after December 15, 2017 and permits the use of either the retrospective or cumulative effect transition method. Under ASU 2015-14, early adoption is permitted only as of annual reporting periods beginning after December 15, 2016, including interim reporting periods within that reporting period. The Company continues to evaluate the impact of this new standard on its consolidated financial statements and related disclosures.
In September 2015, the FASB issued ASU No. 2015-16, “Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments” (“ASU 2015-16”), which requires (i) that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined, (ii) that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date, (iii)that an entity present separately on the face of the income statement or disclose in the notes the portion of the amount recorded in current period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. Under ASU 2015-16, this guidance becomes effective for annual periods beginning after December 15, 2016 and interim periods within annual periods beginning after December 15, 2017 with prospective application with early adoption permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures and expects to early adopt this guidance for periods beginning after December 31, 2015.
In November 2015, the FASB issued ASU 2015-17 (Topic 740), “Balance Sheet Classification of Deferred Taxes” (“ASU 2015-17”) which is intended to simplify the presentation of deferred taxes in a classified balance sheet. This guidance states that deferred tax assets and deferred tax liabilities should be presented as noncurrent in a classified statement of financial position. Under ASU 2015-17, this guidance becomes effective for annual periods beginning after December 15, 2016 and interim periods within those annual periods with early adoption permitted as of the beginning of an annual or interim period after issuance of the ASU. The Company is currently

F- 16

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

evaluating the impact of this new standard on its consolidated financial statements and related disclosures and expects to early adopt this guidance for periods beginning after December 31, 2015.
In January 2016, the FASB issued ASU No. 2016-01, “Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” (“ASU 2016-01”), which amends how entities measure equity investments that do not result in consolidation and are not accounted for under the equity method and how they present changes in the fair value of financial liabilities measured under the fair value option that are attributable to their own credit. ASU 2016-01 also changes certain disclosure requirements and other aspects of current GAAP but does not change the guidance for classifying and measuring investments in debt securities and loans. Under ASU 2016-01, this guidance becomes effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted in certain circumstances. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.
In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842)” (“ASU 2016-02”), to increase the transparency and comparability about leases among entities. Additional ASUs have been issued subsequent to ASU 2016-02 to provide supplementary clarification and implementation guidance for leases related to, among other things, the application of certain practical expedients, the rate implicit in the lease, lessee reassessment of lease classification, lessor reassessment of lease term and purchase options, variable payments that depend on an index or rate and certain transition adjustments (collectively, the Company refers to ASU 2016-02 and these additional ASUs as the “Updated Lease Guidance”). The new guidanceUpdated Lease 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 isThe Company has adopted the Updated Lease Guidance effective for interim and annual periods beginning after December 15, 2018, and requiresJanuary 1, 2019, using a modified retrospective approach whereby a cumulative effect adjustment will be recognized upon adoption and the Updated Lease Guidance will be applied prospectively.

F- 16

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

The Company has completed its evaluation of the provisions of the Updated Lease Guidance, including the adoption of certain practical expedients allowed. The significant practical expedients adopted include the following:
The Company elected the practical expedient to adoption.apply the transition approach as of the beginning of the period of adoption and not restate comparative periods;
The Company elected to utilize the “package of three” expedients, as defined in the Updated Lease Guidance, whereby it did not reassess whether contracts existing prior to the effective date contain leases, nor did it reassess lease classification determinations nor whether initial direct costs qualify for capitalization;
The Company elected the practical expedient to not capitalize any leases with initial terms of less than twelve months on its consolidated balance sheet;
The Company elected the practical expedient to not separate lease and non-lease components; and
The Company elected the practical expedient to continue to account for land easements (also known as “rights of way”) that were not previously accounted for as leases consistent with prior accounting until such contracts are modified or replaced, at which time they would be assessed for lease classification under the Updated Lease Guidance.

The Company has successfully completed the implementation of a lease software system and refined business processes and controls to address the new standard. The Company is currently developing its lease disclosures and enhancing its accounting systems to enable the preparation of such disclosures beginning with its quarterly reporting on Form 10-Q for the period ending March 31, 2019. As of the date of implementation on January 1, 2019, the impact of the adoption of the Updated Lease Guidance is estimated to result in the recognition of a right of use asset and lease payable obligation on the Company’s consolidated balance sheet of approximately $825,000 to $925,000, of which approximately $600,000 to $650,000 is attributable to leases with affiliates. Subsequent to adoption, the Company does not anticipate the impact on its results and cash flows to be material.
In August 2017, the FASB issued ASU No. 2017-12, “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” (“ASU 2017-12”). The amendments in ASU 2017-12 more closely align the results of cash flow and fair value hedge accounting with risk management activities in the consolidated financial statements. The amendments expand the ability to hedge nonfinancial and financial risk components, reduce complexity in fair value hedges of interest rate risk, eliminate the requirement to separately measure and report hedge ineffectiveness, and eases certain hedge effectiveness assessment requirements. The guidance in ASU 2017-12 should be applied using a modified retrospective approach. The guidance in ASU 2017-12 also provides transition relief to make it easier for entities to apply certain amendments to existing hedges (including fair value hedges) where the hedge documentation needs to be modified. The presentation and disclosure requirements of ASU 2017-12 should be applied prospectively. The Company adopted the amendments in this ASU effective January 1, 2019, which did not have a material impact on its consolidated financial statements and related disclosures.
In June 2018, the FASB issued ASU No. 2018-07, “Compensation - Stock Compensation (Topic 718): Targeted Improvements to Non-employee Share-Based Payment Accounting” (“ASU 2018-07”). ASU 2018-07 expands the scope of Topic 718, Compensation-Stock Compensation, to include share-based payment transactions for acquiring goods and services from nonemployees. As a result, nonemployee share-based transactions will be measured by estimating the fair value of the equity instruments at the grant date, taking into consideration the probability of satisfying performance conditions. In addition, ASU 2018-07 also clarifies that any share-based payment awards issued to customers should be evaluated under ASC 606, Revenue from Contracts with Customers. The Company adopted the amendments in this ASU effective January 1, 2019, which did not have a material impact on its consolidated financial statements and related disclosures.

F- 17

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

In August 2018, the FASB issued ASU No. 2018-14, “Compensation - Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20)”, to improve the effectiveness of disclosures in the notes to financial statements by facilitating clear communication of the information required by GAAP that is most important to users of each entity’s financial statements. The amendments in this ASU modify the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. Additionally, the amendments in this ASU remove disclosures that no longer are considered cost beneficial, clarify the specific requirements of disclosures, and add disclosure requirements identified as relevant. The amendments in this ASU are effective for fiscal years ending after December 15, 2020, for public business entities and for fiscal years ending after December 15, 2021, for all other entities. Early adoption is permitted.permitted for all entities. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.
In March 2016, the FASB issued ASU No. 2016-06, “Derivatives and Hedging (Topic 815) Contingent Put and Call Options in Debt Instruments No. 2016-06 March 2016 a consensus of the FASB Emerging Issues Task Force” (“ASU 2016-06”), to increase consistency in practice in applying guidance on determining if an embedded derivative is clearly and closely related to the economic characteristics of the host contract, specifically for assessing whether call (put) options that can accelerate the repayment of principal on a debt instrument meet the clearly and closely related criterion. The guidance in ASU 2016-06 applies to all entities that are issuers of or investors in debt instruments (or hybrid financial instruments that are determined to have a debt host) with embedded call (put) options. ASU 2016-06 is effective for interim and annual periods beginning after December 15, 2016, and requires a modified retrospective approach to adoption. Early adoption is permitted. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.

3. ACQUISITIONS
ChalmetteTorrance Acquisition
On NovemberJuly 1, 2015,2016, the Company acquired from ExxonMobil Oil Corporation and its subsidiary, Mobil Pacific Pipe Line Company, and PDV Chalmette, L.L.C., 100% of the ownership interests of Chalmette Refining, which owns the ChalmetteTorrance refinery and related logistics assets (collectively, the “Chalmette“Torrance Acquisition”). The Chalmette refinery, located outsideWhile the Company’s consolidated financial statements for both the years ended December 31, 2018 and 2017 include the results of New Orleans, Louisiana, is a dual-train coking refinery and is capableoperations of processing both light and heavy crude oil. Subsequent toTorrance Refining, the closing of the Chalmette Acquisition, Chalmette Refining is a wholly-owned subsidiary of PBF Holding. Chalmette Refining is strategically positioned on the Gulf Coast with strong logistics connectivity that offers flexible raw material sourcing and product distribution opportunities, including the potential to export products and provides geographic diversification into PADD 3.

Chalmette Refining owns 100% of the MOEM Pipeline, providing access to the Empire Terminal, as well as the CAM Connection Pipeline, providing access to the Louisiana Offshore Oil Port facility through a third party pipeline. Chalmette Refining also owns 80% of each of the Collins Pipeline Company and T&M Terminal Company, both located in Collins, Mississippi, which provide a clean products outletfinal working capital settlement for the refinery to the Plantation and Colonial Pipelines. Also includedTorrance Acquisition was finalized in the second quarter of 2017. Additionally, certain acquisition are a marine terminal capablerelated costs for the Torrance Acquisition were recorded in the first and second quarter 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.

F- 17

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)


2017.
The aggregate purchase price for the ChalmetteTorrance Acquisition was $322,000$521,350 in cash after post-closing purchase price adjustments, plus estimated inventory andfinal working capital of $243,304, which is subject to final valuation upon agreement of both parties.$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 equity offerings, and borrowings under the Company’s existing revolving credit line.

Revolving Credit Facility.
The Company accounted for the Chalmette Acquisition as a business combination under US GAAP whereby we recognize assets acquired and liabilities assumed in an acquisition at their estimated fair values as of the date of acquisition. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired is recorded as goodwill. The final purchase price and its allocation are dependent on final reconciliations of working capital and other items subject to agreement by both parties.

The following table summarizes the preliminary amounts recognized for assets acquired and liabilities assumed as of the acquisition date.The total purchase consideration and the estimated fair values of the assets and liabilities at the acquisition date were as follows:
 Purchase Price
Net cash$565,083
Preliminary estimate of payable to Seller for working capital adjustments19,263
Cash acquired(19,042)
Total estimated consideration$565,304
 Purchase Price
Gross purchase price$537,500
Working capital450,582
Post close purchase price adjustments(16,150)
Total consideration$971,932

F- 18

 Fair Value Allocation
Accounts receivable$1,126
Inventories268,751
Prepaid expenses and other current assets913
Property, plant and equipment356,961
Deferred charges and other assets8,312
Accounts payable(4,870)
Accrued expenses(28,347)
Deferred tax liability(20,577)
Noncontrolling interest(16,965)
Estimated fair value of net assets acquired$565,304
PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

In addition, in connection withThe following table summarizes the amounts recognized for assets acquired and liabilities assumed as of the acquisition date:
 Fair Value Allocation
Inventories$404,542
Prepaid and other current assets982
Property, plant and equipment704,633
Deferred charges and other assets, net68,053
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 consolidated financial statements for the years ended December 31, 2018 and 2017 include the results of Chalmette Refining,operations of the Company acquired Collins Pipeline Company and T&M Terminal Company, which are both C-corporationsTorrance refinery for tax purposes. As a result, the Company recognized a deferred tax liability of $20,577 attributable to the book and tax basis difference in the C-corporation assets.full year. The Company’s consolidated financial statements for the year ended December 31, 20152016 include the results of operations of the ChalmetteTorrance refinery since NovemberJuly 1, 20152016 during which period the ChalmetteTorrance refinery contributed revenues of $643,267$1,977,204 and net income of $53,539.$86,394. On an unaudited pro forma basis, the revenues and net income of the Company assuming the acquisitionTorrance Acquisition had occurred on January 1, 2014,2015, 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, 2014,2015, nor is the financial information indicative of the results of future operations. The unaudited pro forma financial information includes the depreciation and amortization expense related to the acquisitionTorrance Acquisition and interest expense associated with the Chalmette acquisitionrelated financing.

F- 18

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

 Years ended December 31,
(Unaudited)2015 2014
Revenues$16,811,922
 $26,685,661
Net income attributable to PBF Holdings LLC397,108
 47,030

The amount of revenues and net income above have been calculated after conforming Chalmette Refining's accounting policies to those of the Company and certain one-time adjustments.

 Year ended December 31,
(Unaudited)2016
Pro forma revenues$16,987,548
Pro forma net income attributable to PBF Holding Company LLC31,565
Acquisition Expenses

The Company incurred acquisition related costs consisting primarily of consulting and legal expenses related to the Chalmette Acquisition and othercompleted, pending and non-consummated acquisitions of $5,833$488 and $13,622 in the years ended December 31, 2017 and 2016, respectively. There were no such costs for the year ended December 31, 2015 .2018. Acquisition related expenses were not material for the years ended December 31, 2014 and 2013. These costs are included in the consolidated income statementstatements of operations in “GeneralGeneral and Administrative expenses”.

4. INVENTORIES
Inventories consisted of the following:
December 31, 2015
 Titled Inventory Inventory Supply and Offtake Arrangements Total
Crude oil and feedstocks$1,137,605
 $
 $1,137,605
Refined products and blendstocks687,389
 411,357
 1,098,746
Warehouse stock and other55,257
 
 55,257
 $1,880,251
 $411,357
 $2,291,608
Lower of cost or market adjustment(966,564) (150,772) (1,117,336)
Total inventories$913,687
 $260,585
 $1,174,272
December 31, 2014
 Titled Inventory Inventory Supply and Offtake Arrangements Total
Crude oil and feedstocks$918,756
 $61,122
 $979,878
Refined products and blendstocks520,308
 255,459
 775,767
Warehouse stock and other36,726
 
 36,726
 $1,475,790
 $316,581
 $1,792,371
Lower of cost or market adjustment(609,774) (80,336) (690,110)
Total inventories$866,016
 $236,245
 $1,102,261
administrative expenses.

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.

F- 19

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)


Due4. INVENTORIES
Inventories consisted of the following:
December 31, 2018
 Titled Inventory Inventory Intermediation Arrangements Total
Crude oil and feedstocks$1,044,824
 $
 $1,044,824
Refined products and blendstocks1,026,921
 334,708
 1,361,629
Warehouse stock and other109,337
 
 109,337
 $2,181,082
 $334,708
 $2,515,790
Lower of cost or market adjustment(557,187) (94,547) (651,734)
Total inventories$1,623,895
 $240,161
 $1,864,056
December 31, 2017
 Titled Inventory Inventory Intermediation Arrangements Total
Crude oil and feedstocks$1,073,093
 $
 $1,073,093
Refined products and blendstocks1,030,817
 311,477
 1,342,294
Warehouse stock and other98,866
 
 98,866
 $2,202,776
 $311,477
 $2,514,253
Lower of cost or market adjustment(232,652) (67,804) (300,456)
Total inventories$1,970,124
 $243,673
 $2,213,797

Inventory under inventory intermediation arrangements included certain light finished products sold to counterparties and stored in the lower crude oilPaulsboro and refined product pricing environment atDelaware City refineries’ storage facilities in connection with the end of 2014 and into 2015, the Company recorded adjustments to value its inventories to the lower of cost or market. Inventory Intermediation Agreements with J. Aron.
During the year ended December 31, 2015,2018, the Company recorded an adjustment to value its inventories to the lower of cost or market which decreased both operating income and net incomefrom operations by $427,226$351,278 reflecting the net change in the lower of cost or market (“LCM”) inventory reserve from $690,110$300,456 at December 31, 20142017 to $1,117,336$651,734 at December 31, 2015. In2018. During the year ended December 31, 2014,2017, the Company first recorded an adjustment to value its inventories to the lower of cost or market which decreased both operatingincreased income from operations by $295,532 reflecting the net change in the LCM inventory reserve from $595,988 at December 31, 2016 to $300,456 at December 31, 2017.
An actual valuation of inventories valued under the LIFO method is made at the end of each year based on inventory levels and net income by $690,110.costs at that time. We recorded a charge related to a LIFO layer decrement of $21,881 and $4,940 during the years ended December 31, 2018 and December 31, 2017, respectively.


F- 20

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

5. PROPERTY, PLANT AND EQUIPMENT, NET
Property, plant and equipment, net consisted of the following:
 
 December 31,
2015
 December 31,
2014
 December 31, 2018 December 31, 2017
Land $91,256
 $59,575
 $248,979
 $253,105
Process units, pipelines and equipment 2,209,712
 1,843,157
 2,934,463
 2,799,360
Buildings and leasehold improvements 34,265
 28,397
 47,941
 50,001
Computers, furniture and fixtures 72,642
 68,431
 121,189
 105,921
Construction in progress 150,388
 69,413
 320,125
 167,460
 2,558,263
 2,068,973
 3,672,697
 3,375,847
Less—Accumulated depreciation (347,173) (262,913)
 $2,211,090
 $1,806,060
Less - Accumulated depreciation (701,470) (570,457)
Total property, plant and equipment, net $2,971,227
 $2,805,390
Depreciation expense for the years ended December 31, 2015, 20142018, 2017 and 20132016 was $88,474, $113,533$133,152, $123,257 and $79,413,$104,293, respectively. The Company capitalized $3,529$9,326 and $7,487$5,937 in interest during 20152018 and 2014,2017, respectively, in connection with construction in progress.
For the year ended December 31, 2014,Torrance Land Sale
In August 2018, the Company determined that it would abandonclosed on a capital project at the Delaware City refinery. The project was related to the constructionthird-party sale of a new hydrocracker (the “Hydrocracker Project”).parcel of real property acquired as part of the Torrance Refinery, but not part of the refinery itself. The carrying value forsale resulted in a gain of $43,761 included within (Gain) loss on sale of assets within the Hydrocracker Project was $28,508. The total pre-tax impairment chargeConsolidated Statements 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.Operations.


F- 21

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

6. DEFERRED CHARGES AND OTHER ASSETS, NET
Deferred charges and other assets, net consisted of the following:  
December 31,
2015
 December 31, 2014December 31, 2018 December 31, 2017
Deferred turnaround costs, net$177,236
 $204,987
$673,107
 $560,403
Catalyst77,725
 77,322
Catalyst, net124,290
 131,019
Environmental credits37,811
 42,452
Linefill13,504
 10,230
19,485
 19,485
Restricted cash1,500
 1,521
Pension plan assets9,694
 9,593
Intangible assets, net219
 357
511
 537
Other20,529
 5,972
6,950
 16,435
$290,713
 $300,389
Total deferred charges and other assets, net$871,848
 $779,924


F- 20

PBF HOLDING COMPANY LLCCatalyst, net includes $73,079 and $73,967 of indefinitely-lived precious metal catalysts as of December 31, 2018 and December 31, 2017, respectively.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

The Company recorded amortization expense related to deferred turnaround costs, catalyst and intangible assets of $102,636, $65,452$207,191, $143,978 and $32,066$105,547 for the years ended December 31, 2015, 20142018, 2017 and 20132016, respectively. The restricted cash consists primarily of cash held as collateral securing the Rail Facility.
Intangible assets, net was comprisedprimarily consists of permits and emission creditscredits. Our net balance as follows:of December 31, 2018 and December 31, 2017 is shown below.
  December 31,
2015
 December 31, 2014
Gross amount $3,597
 $3,599
Accumulated amortization (3,378) (3,242)
Net amount $219
 $357
  December 31, 2018 December 31, 2017
Intangible assets - gross $3,996
 $3,996
Accumulated amortization (3,485) (3,459)
Intangible assets - net $511
 $537



F- 22

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

7. ACCRUED EXPENSES
Accrued expenses consisted of the following:

December 31,
2015
 December 31, 2014December 31, 2018 December 31, 2017
Inventory-related accruals$548,800
 $588,297
$846,270
 $1,151,810
Inventory supply and intermediation arrangements252,380
 253,549
Inventory intermediation arrangements249,442
 244,287
Excise and sales tax payable149,358
 118,515
Accrued salaries and benefits89,308
 58,589
Accrued capital expenditures59,938
 17,342
Accrued transportation costs91,546
 59,959
53,579
 64,400
Accrued salaries and benefits61,011
 55,993
Excise and sales tax payable34,129
 40,444
Accrued construction in progress7,400
 31,452
Accrued utilities49,851
 42,189
Renewable energy credit and emissions obligations27,052
 26,231
Accrued refinery maintenance and support costs19,046
 35,674
Accrued interest6,796
 9,466
Environmental liabilities6,502
 7,968
Customer deposits20,395
 24,659
5,594
 16,133
Accrued interest22,313
 22,946
Accrued utilities25,192
 22,337
Renewable energy credit obligations19,472
 286
Other34,797
 30,048
16,302
 8,255
$1,117,435
 $1,129,970
Total accrued expenses$1,579,038
 $1,800,859

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&RInventory Intermediation Agreements with J. Aron. As of December 31, 2015,2018 and December 31, 2017, a liability is recognized for the Inventory supply and intermediation arrangementsIntermediation Agreements and is recorded at market price for the J. Aron owned inventory held in the Company'sCompany’s storage tanks under the Inventory Intermediation Agreements, with any change in the market price being recorded in costCost of sales.
The Company had the obligation to purchaseproducts and sell feedstocks under a supply agreement with Statoil for its Delaware City refinery. This Crude Supply Agreement expired on December 31, 2015. Prior to its expiration, Statoil purchased the refinery's production of certain feedstocks or purchased feedstocks from third parties on the refineries' behalf. Legal title to the feedstocks was held by Statoil and the feedstocks were held in the refinery's storage tanks until they were needed for further use in the refining process. At that time, the products were drawn out of the storage tanks and purchased by the refinery. These purchases and sales were settled monthly at the daily market prices related to those products. These transactions were considered to be made in contemplation of each other and, accordingly, did not result in the recognition of a sale when title passed from the refinery to Statoil. Inventory remained at cost and the net cash receipts resulted in a liability.other.

F- 21

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

The Company is subject to obligations to purchase Renewable Identification Numbers (“RINs”) required to comply with the Renewable Fuels Standard. The Company'sCompany’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 ourits RINs obligation, RINs must be purchased on the open market to avoid penalties and fines. The Company records its RINs obligation on a net basis in Accrued expenses when its RINs liability is greater than the amount of RINs earned and purchased in a given period and in Prepaid expenses and other current assets when the amount of RINs earned and purchased is greater than the RINs liability.
Accrued distributions represent unpaid distributions to PBF LLC related to tax distributions and non-tax distributions made by PBF LLC to its members.

8. DELAWARE ECONOMIC DEVELOPMENT AUTHORITY LOAN
In June 2010, in connection with the Delaware City acquisition, the Delaware Economic Development Authority (the “Authority”) granted the Company a $20,000 loan to assist with operating costs and the cost of restarting the refinery. The loan is represented by a zero interest rate note and the entire unpaid principal amount is payable in full on March 1, 2017, unless the loan is converted to a grant. The Company recorded the loan as a long-term liability pending approval from the Authority that it has met the requirements to convert the remaining loan balance to a grant.

The loan converts to a grant in tranches of up to $4,000 annually over a five-year period, starting at the one-year anniversary of the “certified restart date” as defined in the agreement and certified by the Authority. In order for the loan to be converted to a grant,addition, the Company is requiredsubject to utilize at least 600 man hoursobligations to comply with federal and state legislative and regulatory measures, including regulations in the state of labor in connectionCalifornia pursuant to Assembly Bill 32 (“AB32”), to address environmental compliance and greenhouse gas and other emissions. These requirements include incremental costs to operate and maintain our facilities as well as to implement and manage new emission controls and programs. Renewable energy credit and emissions obligations fluctuate with the reconstructionvolume of applicable product sales and restartingtiming of the Delaware City refinery, expend at least $125,000 in qualified capital expenditures, commence refinery operations, and maintain certain employment levels, all as defined in the agreement. In February 2013, October 2013, August 2014 and December 2015, the Company received confirmation from the Authority that the Company had satisfied the conditions necessary for the first four $4,000 tranches of the loan to be converted to a grant. As a result of the grant conversion, property, plant and equipment, net was reduced by $4,000 in each of the years ended December 31, 2015 and December 31, 2014, respectively, as the proceeds from the loan were used for capital projects.credit purchases.


F- 2223

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

9.Early Return of Railcars
On September 30, 2018, the Company agreed to voluntarily return a portion of railcars under an operating lease in order to rationalize certain components of its railcar fleet based on prevailing market conditions in the crude oil by rail market. Under the terms of the lease amendment, the Company will pay agreed amounts in lieu of satisfaction of return conditions (the “Early Termination Penalty”) and will pay a reduced rental fee over the remaining term of the lease. Certain of these railcars are idle and the remaining railcars were taken out of service during the fourth quarter of 2018 and subsequently fully returned to the lessor. As a result, the Company recognized an expense of $52,313 for year ended December 31, 2018 included within Cost of sales consisting of (i) a $40,313 charge for the Early Termination Penalty and (ii) a $12,000 charge related to the remaining lease payments associated with the portion of railcars within the amended lease, that were idled and out of service as of December 31, 2018. As of December 31, 2018, $7,106 of these payments are anticipated to be paid within the next twelve months and are included within the inventory-related accruals category above.
8. CREDIT FACILITY AND LONG-TERM DEBT
Long-term debt outstanding consisted of the following:
  December 31, 2018 December 31, 2017
Revolving Credit Facility $
 $350,000
2025 Senior Notes 725,000
 725,000
2023 Senior Notes 500,000
 500,000
PBF Rail Term Loan 21,554
 28,366
Catalyst leases 44,353
 59,048
  1,290,907
 1,662,414
Less - Current debt (2,378) (10,987)
Unamortized deferred financing costs (30,537) (25,178)
Long-term debt $1,257,992
 $1,626,249

F- 24

PBF Holding HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)


Revolving LoanCredit Facility
OnPrior to entering into a new revolving credit facility in May of 2018 as discussed further below, PBF Holding’s previous asset-based credit agreement dated as of August 15, 2014 PBF Holding amended and restated the terms of its asset based revolving credit agreement (“(the “August 2014 Revolving Loan”Credit Agreement”) to,, among other things, increase the commitments from $1,610,000 to $2,500,000,had a maximum commitment of $2,635,000, a maturity date of August 2019 and extend the maturity to August 2019. In addition, the amended and restated agreement reduced the interest rate on advances and the commitment fee paid on the unused portion of the facility. The amended and restated agreement also increased the sublimit for letters of credit from $1,000,000 to $1,500,000 and reduced the combined LC Participation Fee and Fronting Fee paid on each issued and outstanding letter of credit. As defined in the agreement, the LC Participation Fee ranges from 1.25% to 2.0% depending on the Company's debt rating and the Fronting Fee is equal to 0.25%.
Anan accordion feature allowsthat allowed for increases in the aggregate commitment of up to $2,750,000. In November 2015The sublimit for letters of credit was $1,500,000. The LC Participation Fee ranged from 1.25% to 2.0% depending on the Company’s senior secured debt rating and December 2015, PBF Holding increased the maximum availability under the Revolving LoanFronting Fee was equal to $2,600,000 and $2,635,000, respectively.0.25%. At the option of PBF Holding, advances under the Revolving Loan will bearborrowings bore 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.August 2014 Revolving Credit Agreement. The Applicable Margin rangesranged from 0.50% to 1.25% for Alternative Base Rate Loans and from 1.50% to 2.25% for Adjusted LIBOR Rate Loans, and from 0.50% to 1.25% for Alternative Base Rate Loans,in each case depending on the Company'sCompany’s senior secured debt rating. Interest is paid in arrears, either quarterly in
On May 2, 2018, PBF Holding and certain of its wholly-owned subsidiaries, as borrowers or subsidiary guarantors, replaced the caseAugust 2014 Revolving Credit Agreement with a new asset-based revolving credit agreement (the “Revolving Credit Facility"). The Revolving Credit Facility has a maximum commitment of Alternate Base Rate Loans or at the$3,400,000, a maturity date of each Adjusted LIBOR Rate Loan.
Advances under the Revolving Loan, plus all issuedMay 2023 and outstanding lettersredefines certain components of credit may not exceed the lesser of $2,635,000 or the Borrowing Base, as defined in the agreement.agreement governing the Revolving Credit Facility (the “Revolving Credit Agreement”), to make more funding available for working capital needs and other general corporate purposes. Borrowings under the Revolving Credit Facility bear interest at the Alternative Base Rate plus the Applicable Margin or at the Adjusted LIBOR Rate plus the Applicable Margin (all as defined in the Revolving Credit Agreement). The Revolving Loan can be prepaid, without penalty,Applicable Margin ranges from 0.25% to 1.00% for Alternative Base Rate Loans and from 1.25% to 2.00% for Adjusted LIBOR Rate Loans, in each case depending on the Company’s corporate credit rating. In addition, an accordion feature allows for commitments of up to $3,500,000. The LC Participation Fee ranges from 1.00% to 1.75% depending on the Company’s corporate credit rating and the Fronting Fee is capped at any time.0.25%.
The Revolving LoanCredit Agreement contains customary covenants and restrictions on the activities of PBF Holding and its subsidiaries, including, but not limited to, limitations on incurring additional indebtedness, liens, negative pledges, guarantees, investments, loans, asset sales, mergers and acquisitions, prepayment of other debt, distributions, dividends and the repurchase of capital stock, transactions with affiliates and the ability of PBF Holding to change the nature of its business or its fiscal year; all as defined in the Revolving Credit Agreement.
In addition, the Revolving Credit Agreement has a financial covenant which requires that if at any time Excess Availability, as defined in the agreement,Revolving Credit Agreement, is less than the greater of (i) 10% of the lesser of the then existing Borrowing Base and the then aggregate Revolving Commitments of the Lenders (the “Financial Covenant Testing Amount”), and (ii) $100,000, 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 agreementRevolving Credit Agreement and determined as of the last day of the most recently completed quarter, to be less than 1.11.0 to 1.0.
PBF Holding'sHolding’s obligations under the Revolving LoanCredit Facility are (a) are guaranteed by each of its domestic operating subsidiaries that are not Excluded Subsidiaries (as defined in the agreement)Revolving Credit Agreement) and (b) are secured by a lien on (x)(i) PBF LLC’s equity interestsinterest in PBF Holding and (y)(ii) certain assets of PBF Holding and the subsidiary guarantors, including all deposit accounts (other than zero balance accounts, cash collateral accounts, trust accounts and/or payroll accounts, all of which are excluded from the definition of collateral);, all accounts receivable;receivable, all hydrocarbon inventory (other than the intermediate and finished products owned by J. Aron pursuant to the Inventory Intermediation Agreements) and to the extent evidencing, governing, securing or otherwise related to the foregoing, all general intangibles, chattel paper, instruments, documents, letter of credit rights and supporting obligations; and all products and proceeds of the foregoing.
There were no outstanding borrowings under the Revolving Loan as of December 31, 2015 and December 31, 2014, and standby letters of credit were $351,511 and $400,262, respectively.
PBF Rail Revolving Credit Facility
Effective March 25, 2014, PBF Rail Logistics Company LLC (“PBF Rail”), an indirect wholly-owned subsidiary of PBF Holding, entered into a $250,000 secured revolving credit agreement (the “Rail Facility”) with a consortium of banks, including Credit Agricole Corporate & Investment Bank (“CA-CIB”) as Administrative Agent. The primary purpose of the Rail Facility is to fund the acquisition by PBF Rail of coiled and insulated crude tank cars and non-coiled and non-insulated general purpose crude tank cars (the “Eligible Railcars”) before December 2015.

F- 2325

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

The amount available to be advanced under the Rail Facility equals 70% of the lesser of the aggregate Appraised Value of the Eligible Railcars, or the aggregate Purchase Price of such Eligible Railcars, as these terms are defined in the Rail Facility. On the first anniversary of the closing, the advance rate adjusts automatically to 65%. At any time prior to maturity PBF Rail may repay and re-borrow any advances without premium or penalty.
At PBF Rail's election, advances bear interest at a rate per annum equal to one month LIBOR plus the Facility Margin for Eurodollar Loans, or the Corporate Base Rate plus the Facility Margin for Base Rate Loans (the Corporate Base Rate is equal to the higher of the prime rate as determined by CA-CIB, the Federal Funds Rate plus 50 basis points, or one month LIBOR plus 100 basis points), all as defined in the Rail Facility. In addition, there is a commitment fee on the unused portion. Interest and fees are payable monthly.
The lenders received a perfected, first priority security interest in all of PBF Rail's assets, including but not limited to (i) the Eligible Railcars, (ii) all railcar marks and other intangibles, (iii) the rights of PBF Rail under the Transportation Services Agreement (“TSA”) entered into between PBF Rail and PBF Holding, (iv) the accounts of PBF Rail, and (v) proceeds from the sale or other disposition of the Eligible Railcars, including insurance proceeds. In addition, the lenders received a pledge of the membership interest of PBF Rail held by PBF Transportation Company LLC, a wholly-owned subsidiary of PBF Holding. The obligations of PBF Holding under the TSA are guaranteed by each of Delaware City Refining, Paulsboro Refining, and Toledo Refining.
On April 29, 2015, PBF Rail entered into the First Amendment to the Rail Facility. The amendments to the Rail Facility include the extension of the maturity to April 29, 2017, the reduction of the total commitment from $250,000 to $150,000, and the reduction of the commitment fee on the unused portion of the Rail Facility. On the first anniversary of the closing of the amendment, the advance rate adjusts automatically to 65%.
There was $67,491 and $37,270no outstanding balance under the Revolving Credit Facility as of December 31, 2018. At December 31, 2017, there was $350,000 outstanding under the Rail Facility atAugust 2014 Revolving Credit Agreement. Issued letters of credit were $400,695 and $586,274, as of December 31, 20152018 and December 31, 2014,2017, respectively.
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 thecertain 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 August 2014 Revolving Loan.Credit Agreement.
On November 24, 2015, PBF Holding and PBF Holding’s wholly-owned subsidiary, PBF Finance Corporation completed an offering of $500,000 in aggregate principal amount of 7.00% Senior Secured Notes due 2023 (the “2023 Senior Secured Notes”, and together with the 2020 Senior Secured Notes, the “Senior Secured Notes”). The net proceeds from this offering were approximately $490,000 after deducting the initial purchasers’ discount and offering expenses. The Company intends to useIssuers used the proceeds for general corporate purposes, including to fundfunding a portion of the purchase price for the pending acquisition of the Torrance refinery and related logistics assets.
The 2023 Senior Secured Notes include a registration payment arrangement whereby the Company has agreed to file with the SEC and use reasonable efforts to cause to become effective within 365 days of the closing date of the 2023 Senior Secured Notes offering, a registration statement relating to an offer to exchange the 2023 Senior Secured Notes for an issue of registered notes with terms substantially identical to the notes. The Company fully intends to file a registration statement for the exchange of the 2023 Senior Secured Notes within the 365 day period following the closing of the 2023 Senior Secured Notes. In addition, there are no restrictions or hindrances that the Company is aware of that would prohibit it from filing such registration statement and maintaining its effectiveness as stipulated in the registration rights agreement. As such, the Company asserts that it is not probable that it will have to transfer any consideration as a result of the registration rights agreement and thus no loss contingency was recorded.

F- 24

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

The Senior Secured Notes arewere 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)Credit Facility). Payment of the Senior Secured Notes is jointly and severally guaranteed by substantially all of PBF Holding’s subsidiaries. PBF Holding has optional redemption rights to repurchase all or a portion of the Senior Secured Notes at varying prices no less than 100% of the principal amounts of the notes plus accrued and unpaid interest. The holders of the Senior Secured Notes have repurchase options exercisable only upon a change in control, certain asset sale transactions, or in event of a default as defined in the indenture agreement.
In addition, the Senior Secured Notes contain covenant restrictions limitingcustomary 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; (1) incur additional indebtedness or issue certain typespreferred stock; (2) make equity distributions; (3) pay dividends on or repurchase capital stock or make other restricted payments; (4) enter into transactions with affiliates; (5) create liens; (6) engage in mergers and consolidations or otherwise sell all or substantially all of additional debt, equity issuances,its assets; (7) designate subsidiaries as unrestricted subsidiaries; (8) make certain investments; and payments.(9) 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.
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 $711,576 from the offering after deducting the initial purchasers’ discount and offering expenses, all of which was used to fund the cash tender offer (the “Tender Offer”) for any and all of its outstanding 2020 Senior Secured Notes, to pay the related redemption price and accrued and unpaid interest for any 2020 Senior Secured Notes which remained outstanding after the completion of the Tender Offer, and for general corporate purposes. The 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 consolidated statements of operations.

F- 26

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

The 2025 Senior Notes are guaranteed by substantially all of PBF Holding’s subsidiaries. The 2025 Senior Notes and guarantees are senior unsecured obligations which rank equal in right of payment with all of the Issuers’ and the Guarantors’ existing and future senior indebtedness, including the Revolving Credit Facility and 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 Credit Facility) to the extent of the value of the collateral securing such indebtedness. The 2025 Senior Notes and the guarantees are structurally subordinated to any existing or future indebtedness and other obligations of the Issuers’ non-guarantor subsidiaries.
PBF Holding has optional redemption rights to repurchase all or a portion of the 2025 Senior Notes at varying prices which are no less than 100% of the principal amount plus accrued and unpaid interest. The holders of the 2025 Senior Notes have repurchase options exercisable only upon a change in control, certain asset sale transactions, or in event of a default as defined in the Indenture. In addition, the 2025 Senior Notes contain customary terms, events of default and covenants for an issuer of non-investment grade debt securities that limit certain types of additional debt, equity issuances, and payments. Many of these covenants will cease to apply or will be modified if the 2025 Senior Notes are rated investment grade.
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.
The 2025 Senior Notes and the 2023 Senior Notes are collectively referred to as the “Senior Notes”.
PBF Rail Term Loan
On December 22, 2016, PBF Rail Logistics Company LLC (“PBF Rail”) entered into a $35,000 term loan (the “PBF Rail Term Loan”) with a bank previously party to the Rail Facility. The PBF Rail Term Loan amortizes monthly over its five year term and bears interest at a rate equal to one month LIBOR plus the margin as defined in the agreement governing the PBF Rail Term Loan (the “Rail Credit Agreement”). As security for the PBF Rail Term Loan, PBF Rail pledged, among other things: (i) certain Eligible Railcars; (ii) the Debt Service Reserve Account (as defined in the Rail Credit Agreement); and (iii) PBF Holding’s membership interest in PBF Rail. Additionally, the Rail Credit Agreement 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 securing the loan are sold, scrapped or otherwise removed from the collateral pool.
The outstanding balances under the PBF Rail Term Loan were $21,554 and $28,366 as of December 31, 2018 and December 31, 2017, respectively.
Precious Metal Catalyst Leases
SubsidiariesCertain subsidiaries of the Company have entered into agreements at eachwhereby such subsidiary sold a portion of its refineries whereby the Company sold certain of its catalyst precious metalsmetal catalysts to a major commercial banksbank and then leased them back.back the precious metal catalysts. The catalyst is required to be repurchased byvolume of the precious metal catalysts and the lease rate are fixed over the term of each lease. At maturity, the Company must repurchase the precious metal catalysts in question at its then fair market valuevalue. The Company believes that there is a substantial market for precious metal catalysts and that it will be able to release such catalysts at lease termination.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.catalysts. The fair value of these repurchase obligations as reflected in the fair value of long-term debt outstanding table below is measured using Level 2 inputs.

F- 27

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

Details on the catalyst leases at each of ourthe Company’s refineries as of December 31, 20152018 are included in the following table:
 Annual lease fee Annual interest rate Expiration date Annual lease fee Annual interest rate Expiration date 
Paulsboro catalyst lease $180
 1.95% December 2016 * $140
 2.20% December 2019
(2) 
Delaware City catalyst lease $322
 1.96% October 2016 * $210
 1.95% October 2019
(2) 
Delaware City catalyst lease - Palladium $30
 2.05% October 2019
(2) 
Delaware City bridge lease $26
 2.10% May 2019
(1) 
Toledo catalyst lease $326
 1.99% June 2017 $178
 1.75% June 2020 
Toledo bridge lease $22
 2.10% April 2019
(1) 
Chalmette catalyst lease $185
 3.85% November 2018 $97
 2.10% October 2021 
Chalmette catalyst lease $171
 2.20% November 2019
(2) 
Chalmette bridge lease $4
 2.15% April 2019
(1) 
Torrance catalyst lease $143
 1.78% July 2019
(2) 
*__________________
(1) During 2018 Delaware City Refining, Toledo Refining and Chalmette Refining entered into three new platinum bridge leases which will expire in 2019. These leases are payable at maturity and are not anticipated to be renewed. The Paulsborototal outstanding balance related to these bridge leases as of December 31, 2018 was $2,378 and Delawareis included in Current debt in the Company’s consolidated balance sheet.

(2) These catalyst leases are included in long-termLong-term debt as of December 31, 20152018 as the Company has the ability and intent to finance these debtsthis debt through availability under other credit facilities if the catalyst leases are not renewed at maturity.
Long-term debt outstanding consisted of the following:
  December 31, 2015 December 31, 2014
2020 Senior Secured Notes $669,644
 $668,520
2023 Senior Secured Notes 500,000
 
Revolving Loan 
 
Rail Facility 67,491
 37,270
Catalyst leases 31,802
 36,559
Unamortized deferred financing costs (32,217) (30,128)
  1,236,720
 712,221
Less—Current maturities 
 
Long-term debt $1,236,720
 $712,221
Note Payable


F- 25In connection with the purchase of a waste water treatment facility servicing the Toledo refinery completed on September 28, 2017, the Company issued a short-term promissory note payable in the amount of $6,831 due June 30, 2018. Payments of $403 on the note were made monthly with a balloon payment of $3,200 paid at maturity. The note payable was fully repaid as of December 31, 2018.

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

Debt Maturities
Debt maturing in the next five years and thereafter is as follows:
Year Ending December 31,  
2016$17,252
201777,164
20184,877
2019
$31,368
2020669,644
8,633
202125,906
2022
2023500,000
Thereafter500,000
725,000
$1,268,937
$1,290,907
 


F- 28

10. INTERCOMPANY
PBF HOLDING COMPANY LLC
NOTES PAYABLETO CONSOLIDATED FINANCIAL STATEMENTS
During 2013, PBF Holding entered into notes payable with PBF Energy and PBF LLC. As of December 31, 2015 and 2014, PBF Holding had outstanding notes payable with PBF Energy and PBF LLC for an aggregate principal amount of $470,047 and $122,264, respectively. The notes have an interest rate of 2.5% and a five-year term but may be prepaid in whole or in part at any time, at the option of PBF Holding, without penalty or premium.(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)


11.9. OTHER LONG-TERM LIABILITIES
Other long-term liabilities consisted of the following:
 
 December 31,
2015
 December 31, 2014 December 31, 2018 December 31, 2017
Environmental liabilities $135,145
 $138,545
Defined benefit pension plan liabilities $42,509
 $40,142
 74,972
 63,579
Post retiree medical plan 17,729
 14,740
Environmental liabilities 8,189
 7,870
Early railcar return liability 23,315
 
Post-retirement medical plan liabilities 19,345
 21,527
Other 1,397
 
 824
 310
 $69,824
 $62,752
Total other long-term liabilities $253,601
 $223,961


F- 29

12.
PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

10. 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
On May 8, 2014, PBFX, PBF GP, PBF Energy, PBF LLC, PBF Holding, DCR, Delaware City Terminaling Company LLC (“Delaware City Terminaling”) and TRC entered into the Contribution and Conveyance Agreement (the “Contribution Agreement I”). On May 14, 2014, concurrent withImmediately prior to the closing of certain contribution agreements, which PBF LLC entered into with PBFX (as defined in the PBFX Offering,table below, and collectively referred to as the following transactions occurred“Contribution Agreements”), PBF Holding contributed certain assets to PBF LLC. PBF LLC in turn contributed those assets to PBFX pursuant to the Contribution Agreement I: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:

DCR distributed all
Contribution AgreementEffective DateAssets ContributedTotal Consideration
Contribution Agreement I5/8/2014DCR Rail Terminal and the Toledo Truck Terminal74,053 PBFX common units and 15,886,553 PBFX subordinated units
Contribution Agreement II9/16/2014DCR West Rack$135,000 in cash and $15,000 through the issuance of 589,536 PBFX common units
Contribution Agreement III12/2/2014Toledo Storage Facility$135,000 in cash and $15,000 through the issuance of 620,935 PBFX common units
Contribution Agreement IV5/5/2015DCR Products Pipeline and Truck Rack$112,500 in cash and $30,500 through the issuance of 1,288,420 PBFX common units
Contribution Agreement V (a)8/31/2016Torrance Valley Pipeline$175,000 in cash
Contribution Agreement VI2/15/2017Paulsboro Natural Gas Pipeline$11,600 affiliate promissory note (b)
Contribution Agreements VII-X7/16/2018Development Assets (c)$31,586 through the issuance of 1,494,134 PBFX common units
(a) Pursuant to Contribution Agreement V entered into on August 31, 2016, PBF Holding contributed 50% of the issued and outstanding limited liability company interests in Delaware City Terminaling and TRC distributed the Toledo Truck Terminal, in each case,of Torrance Valley Pipeline Company LLC (“TVPC”) to PBF HoldingLLC, which in turn were acquired by PBFX. 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 their historical cost.two of the stations.

F- 2630

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

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, contributed, at their historical cost, (i) allis 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 consolidated balance sheet for the 50% of TVPC that it owns. The carrying value of the interestsCompany’s equity method investment in Delaware City TerminalingTVPC was $169,472 and (ii)$171,903 at December 31, 2018 and 2017, respectively. The equity investment in TVPC, through TVP Holding Company LLC “TVP Holding”, is included in the Toledo Truck Terminal to PBFX in exchange for (a) 74,053 common unitsNon-Guarantor financial position and 15,886,553 subordinated units representing an aggregate 50.2% limited partner interest in PBFX, (b) allresults of PBFX’s incentive distribution rights, (c) the right to receive a distribution of $30,000 from PBFX as reimbursement for certain preformation capital expenditures attributable to the contributed assets, and (d) the right to receive a distribution of $298,664; and in connection with the foregoing, PBFX redeemed PBF Holding’s initial partner interests in PBFX for $1.
PBF Holding distributeddisclosed in “Note 20- Consolidating Financial Statements of PBF Holding” as TVP Holding is not a guarantor of the Senior Notes.
(b) As a result of the completion of the Paulsboro Natural Gas Pipeline in the fourth quarter of 2017, PBF Holding received full payment for the affiliate promissory note due from PBFX.
(c) On July 16, 2018, PBFX entered into four contribution agreements with PBF LLC pursuant to which the Company contributed to PBF LLC (i)certain of its interest in PBF GP, (ii) the common units, subordinated units and incentive distribution rights, (iii) the right to receive a distribution of $30,000 as reimbursement for certain preformation capital expenditures, and (iv) the right to receive a distribution of $298,664.
On September 30, 2014, PBF Holding, PBF LLC and PBFX closed the transaction contemplated by thesubsidiaries (the “Development Assets Contribution Agreement dated September 16, 2014 (the “Contribution Agreement II”Agreements”). Pursuant to the terms ofDevelopment Asset Contribution Agreements, the Contribution Agreement II, PBF Holding distributed to PBF LLC all of the equity interests of DCT II, which assets consisted solely of the DCR West Rack, immediately prior to the transfer of such equity interests by PBF LLC to PBFX. The DCR West Rack was previously owned and operated by PBF Holding’s subsidiary, DCT II, and is located at the Company's Delaware City refinery. PBFX paid to PBF LLC total consideration of $150,000, consisting of $135,000 of cash and $15,000 of PBFX common units in exchange for the DCR West Rack.
On December 11, 2014, PBF Holding, PBF LLC and PBFX closed the transaction contemplated by the Contribution Agreement dated December 2, 2014 (the “Contribution Agreement III”). Pursuant to the terms of the Contribution Agreement III, PBF Holding distributed to PBF LLCCompany contributed all of the issued and outstanding limited liability company interests ofof: Toledo Terminaling, which assets consisted of the Toledo Storage Facility. PBF LLC then contributed to PBFX all of the equity interests of Toledo Terminaling for total consideration of $150,000, consisting of $135,000 of cash and $15,000 of PBFX common units, or 620,935 common units.
On May 14, 2015 PBF Holding, PBF LLC and PBFX closed the transactions contemplated by the Contribution Agreement dated May 5, 2015 (the “Contribution Agreement IV”). Pursuant to the terms of the Contribution Agreement IV, PBF Holding distributed all of the equity interests of Delaware Pipeline Company LLC (“DPC”) and Delaware CityRail Logistics Company LLC (“DCLC”TRLC”), whose assets consist of a loading and unloading rail facility located at the Toledo refinery (the “Toledo Rail Products Facility”); Chalmette Logistics Company LLC (“CLC”), whose assets consist of a truck loading rack facility (the “Chalmette Truck Rack”) and a rail yard facility (the “Chalmette Rosin Yard”), both of which are located at the Chalmette refinery; Paulsboro Terminaling Company LLC (“PTC”), whose assets consist of a lube oil terminal facility located at the Paulsboro refinery (the “Paulsboro Lube Oil Terminal”); and DCR Storage and Loading Company LLC (“DSLC”), whose assets consist of an ethanol storage facility located at the Delaware City refinery (the “Delaware Ethanol Storage Facility” and collectively with the Toledo Rail Products Facility, the Chalmette Truck Rack, the Chalmette Rosin Yard, and the Paulsboro Lube Oil Terminal, the “Development Assets”) to PBF LLC immediately prior toLLC. PBFX Operating Company LP (“PBFX Op Co”), PBFX’s wholly-owned subsidiary, in turn acquired the contibution of suchlimited liability company interests byin the Development Assets from PBF LLC to PBFX. The assets consisted of a products pipeline, truck rack and related facilities located at our Delaware City refinery (collectively the “Delaware City Products Pipeline and Truck Rack”), for total consideration of $143,000 consisting of $112,500 of cash and $30,500 of PBFX common units, or 1,288,420 common units.
Commercial Agreements
Inin connection with the contribution agreements described above, PBF Holding entered intoDevelopment Assets Contribution Agreements effective as of July 31, 2018.
Commercial Agreements with PBFX
PBFX currently derives a substantial majority of its revenue from long-term, fee-based commercial agreements with PBFX.PBF Holding relating to assets associated with the Contribution Agreements described above, the majority of which include a minimum volume commitment (“MVC”) and are supported by contractual fee escalations for inflation adjustments and certain increases in operating costs. Under these agreements, PBFX provides various pipeline, rail and truck terminaling and storage services to PBF Holding and PBF Holding has committed to provide PBFX with minimum fees based on minimum monthly throughput volumes. The feesPBF Holding believes the terms and conditions under each of these agreements, are indexed for inflation and any increase in operating costs for providing such services toas well as the Company. Prior to the PBFX Offering, the DCR Rail Terminal, Toledo Truck Terminal, the DCR West RackOmnibus Agreement (as defined below) and the Toledo Storage Facility and other assets contributed to PBFX subsequent to the PBFX Offering were owned, operated and maintained by PBF Holding. Therefore, PBF Holding did not previously pay a fee for the utilization of the facilities. Below is a summary of the agreements and corresponding fees for the use of each of the assets.
Delaware City Rail Terminaling Services Agreement
On May 14, 2014, concurrent with the closing of the PBFX Offering, PBF Holding entered into a rail terminaling services agreement (as defined below) each with PBFX, are generally no less favorable to obtain terminaling services at the DCR Rail Terminal (the “DCR Terminaling Agreement”). Under the DCR Terminaling Agreement, PBF Holding is obligatedeither party than those that could have been negotiated with unaffiliated parties with respect to throughput aggregate volumes of crude oil of at least 85,000 bpd (75,000 bpd through September 30, 2014) for each quarter thereafter (in each case, calculated on a quarterly average basis) for a terminaling service fee of $2.00 per barrel, which will decreasesimilar services.

F- 2731

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

to $0.50 per barrel to the extent volumes exceed the minimum throughput commitment. PBF Holding also pays PBFX for providing related ancillary services at the terminal that are specifiedThese commercial agreements (as defined in the agreement. The terminaling service fee is subject to (i) increase or decrease on January 1 of each year, beginning on January 1, 2015, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) increase by the increase in any operating costs that increase greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the DCR Terminaling Agreement. Effective January 1, 2015, the service fee was increased to $2.032 per barrel up to the minimum throughput commitment and $0.508 per barrel for volumes that exceed the minimum throughput commitment. The agreement will terminate on the first December 31st following the seventh anniversary of the closing of the PBFX Offering and may be extended, at PBF Holding's option, for up to two additional five-year terms.
For the year ended December 31, 2015 and 2014, PBF Holding paid PBFX $63,043 and $36,640, respectively, for fees related to the DCR Terminaling Agreement.
Toledo Truck Unloading & Terminaling Agreement
On May 14, 2014, concurrent with the closing of the PBFX Offering, PBF Holding entered into a truck unloading and terminaling services agreementtable below) with PBFX to obtain terminaling services at the Toledo Truck Terminal (as amended the “Toledo Terminaling Agreement”). Under the Toledo Terminaling Agreement, PBF Holding was obligated to throughput aggregate volumes of crude oil of at least 4,000 bpd (calculated on a quarterly average basis) for a terminaling service fee of $1.00 per barrel. The Toledo Terminaling Agreement was amended and restated effective as of June 1, 2014, to among other things, increase the minimum throughput volume commitment from 4,000 bpd to 5,500 bpd beginning August 1, 2014. PBF Holding also pays PBFX for providing related ancillary services at the terminal which are specified in the Toledo Terminaling Agreement. The terminaling service fee is subject to (i) increase or decrease on January 1 of each year, beginning on January 1, 2015, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) increase by the increase in any operating costs that increase greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the Toledo Terminaling Agreement. Effective January 1, 2015, the terminaling fee was increased to $1.016. The agreement will terminate on the first December 31st following the seventh anniversary of the closing of the PBFX Offering and may be extended, at PBF Holding's option, for up to two additional five-year terms.include:
For the year ended December 31, 2015 and 2014, PBF Holding paid PBFX $5,578 and $2,131, respectively, for fees related to the Toledo Terminaling Agreement.
Delaware City West Ladder Rack
Service AgreementsInitiation DateInitial TermRenewals (a)MVCForce Majeure
Transportation and Terminaling
Amended and Restated Rail Agreements (b)5/8/20147 years,
8 months
2 x 5125,000 bpdPBFX or PBF Holding can declare
Toledo Truck Unloading & Terminaling Services Agreement (g)5/8/20147 years,
8 months
2 x 55,500 bpd
Toledo Storage Facility Storage and Terminaling Services Agreement- Terminaling Facility (g)12/12/201410 years2 x 54,400 bpd
Delaware Pipeline Services Agreement5/15/201510 years,
8 months
2 x 550,000 bpd
Delaware Pipeline Services Agreement- Magellan Connection11/1/20162 years,
5 months
N/A14,500 bpd
Delaware City Truck Loading Services Agreement- Gasoline5/15/201510 years,
8 months
2 x 530,000 bpd
Delaware City Truck Loading Services Agreement- LPGs5/15/201510 years,
8 months
2 x 55,000 bpd
East Coast Terminals Terminaling Services Agreements (c)5/1/2016Various (d)Evergreen15,000 bpd (e)
East Coast Terminals Tank Lease Agreements5/1/2016Various (d)Evergreen350,000 barrels (f)
Torrance Valley Pipeline Transportation Services Agreement- North Pipeline (g)8/31/201610 years2 x 550,000 bpd
Torrance Valley Pipeline Transportation Services Agreement- South Pipeline (g)8/31/201610 years2 x 570,000 bpd
Torrance Valley Pipeline Transportation Services Agreement- Midway Storage Tank (g)8/31/201610 years2 x 555,000 barrels (f)
Torrance Valley Pipeline Transportation Services Agreement- Emidio Storage Tank (g)8/31/201610 years2 x 5900,000 barrels per month
Torrance Valley Pipeline Transportation Services Agreement- Belridge Storage Tank (g)8/31/201610 years2 x 5770,000 barrels per month
Paulsboro Natural Gas Pipeline Services Agreement (g) (h)8/4/201715 yearsEvergreen60,000 dekatherms per day
Knoxville Terminals Agreement- Terminaling Services4/16/20185 yearsEvergreenVarious (i)
Knoxville Terminals Agreement- Tank Lease (g)4/16/20185 yearsEvergreen115,334 barrels (f)
Toledo Rail Loading Agreement (g)7/31/20187 years, 5 months2 x 5Various (j)
Chalmette Terminal Throughput Agreement7/31/20181 yearEvergreenN/A
Chalmette Rail Unloading Agreement7/31/20187 years, 5 months2 x 57,600 bpd
DSL Ethanol Throughput Agreement (g)7/31/20187 years, 5 months2 x 55,000 bpd
Storage
Toledo Storage Facility Storage and Terminaling Services Agreement- Storage Facility (g)12/12/201410 years2 x 53,849,271 barrels (f)PBFX or PBF Holding can declare
Chalmette Storage Agreement (g)See note (k)10 years2 x 5625,000 barrels (f)
On October 1, 2014, PBF Holding and DCT II entered into a seven-year terminaling services agreement (the “West Ladder Rack Terminaling Agreement”) under which PBFX, through DCT II, provides rail terminaling services to PBF Holding. DCT II, immediately following the closing of the Contribution Agreement II, was merged with and into Delaware City Terminaling, a wholly-owned subsidiary of PBFX, with all property, rights, liabilities and obligations of DCT II vesting in Delaware City Terminaling as the surviving company. The agreement may be extended by PBF Holding for two additional five-year periods. Under the West Ladder Rack Terminaling Agreement, PBF Holding is obligated to throughput aggregate volumes of crude oil of at least 40,000 bpd for a terminaling service fee equal to $2.20 per barrel for all volumes of crude oil throughput up to the minimum throughput commitment, and $1.50 per barrel for all volumes of crude oil throughput in excess of the minimum throughput commitment, in any contract quarter. PBF Holding also pays PBFX for providing related ancillary services at the terminal which are specified in the West Ladder Rack Terminaling Agreement. The terminaling service fee is subject to (i) increase or decrease on January 1 of each year, beginning on January 1, 2016, by the amount of any change in the Producer Price Index, provided that the fee may not be adjusted below the initial amount and (ii) increase by the increase in any operating costs that increase greater than the Producer Price Index reasonably incurred by PBFX in connection with providing the services and ancillary services under the West Ladder Rack Terminaling Agreement.____________________
(a)PBF Holding has the option to extend the agreements for up to two additional five-year terms, as applicable.

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PBF HOLDING COMPANY LLC
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(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

(b)The Amended and Restated Rail Agreements, as amended and effective as of January 1, 2018, include the Amended and Restated Delaware City Rail Terminaling Services Agreement and the Amended and Restated Delaware West Ladder Rack Terminaling Services Agreement each between Delaware City Terminaling Company LLC and PBF Holding with the service fees thereunder being adjusted, including the addition of an ancillary fee paid by PBF Holding on an actual cost basis. In determining payments due under the Amended and Restated Rail Agreements, excess volumes throughput under the agreements shall apply against required payments in respect to the minimum throughput commitments on a quarterly basis and, to the extent not previously applied, on an annual basis against the MVCs. On February 13, 2019 PBF Holding amended and restated the existing Amended and Restated Delaware City Rail Terminaling Services Agreement and entered into a new terminaling services agreement. Refer to “Note 19 - Subsequent Events” of the Notes to Consolidated Financial Statements for further discussion.
(c)Subsequent to the Toledo Products Terminal Acquisition, the Toledo Products Terminal was added to the East Coast Terminals Terminaling Services Agreements.
(d)The East Coast Terminals related party agreements include varying initial term lengths, ranging from one to five years.
(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’s Paulsboro refinery with a 15,000 bpd MVC.
(f)Reflects the overall capacity as stipulated by the storage agreement. The storage MVC is subject to the effective operating capacity of each tank, which can be impacted by routine tank maintenance and other factors.
(g)These commercial agreements with PBFX are considered leases.
(h)In August 2017, PBFX’s Paulsboro Natural Gas Pipeline commenced service. Concurrent with the commencement of operations, a new services agreement was entered into between PBF Holding and PNGPC.
(i)The minimum throughput revenue commitment for the Knoxville Terminals Agreement- Terminaling Services is $894 for year one, $1,788 for year two and $2,683 for year three and thereafter.
(j)Under the Toledo Rail Loading Agreement, PBF Holding has minimum throughput commitments for (i) 30 railcars per day of products and (ii) 11.5 railcars per day of premium products. The Toledo Rail Loading Agreement also specifies a maximum throughput rate of 50 railcars per day.
(k)The Chalmette Storage Services Agreement was entered into on February 15, 2017 and commenced on November 1, 2017.
For the year ended December 31, 2015 and 2014, PBF Holding paid PBFX $32,120 and $9,639, respectively, related
Omnibus Agreement
In addition to the West Ladder Rack Terminaling Agreement.
Toledo Storage Facility Storage and Terminaling Services Agreement
On December 12, 2014, PBF Holding and Toledo Terminaling entered into a ten-year storage and terminaling services agreement (the “Toledo Storage Facility Storage and Terminaling Agreement”) under which PBFX, through Toledo Terminaling, will provide storage and terminaling services to PBF Holding. The Toledo Storage Facility Storage and Terminaling Agreement can be extended by PBF Holding for two additional five-year periods. Under the Toledo Storage Facility Storage and Terminaling Agreement, PBFX will provide PBF Holding with storage and throughput services in return for storage and throughput fees.
The storage services require PBFX to accept, redeliver and store all products tendered by PBF Holding in the tanks and load products at the storage facility on behalf of PBF Holding up to the effective operating capacity of each tank, the loading capacity of the products rack and the overall capacity of the Toledo Storage Facility Assets. PBF Holding will pay a fee of $0.50 per barrel of shell capacity dedicated to PBF Holding under the Toledo Storage Facility Storage and Terminaling Agreement.The minimum throughput commitment for the propane storage and loading facility will be 4,400 barrels per day (“bpd”) for a fee equal to $2.52 per barrel of product loaded up to the minimum throughput commitment and in excess of the minimum throughput commitment. If PBF Holding does not throughput the aggregate amounts equal to the minimum throughput commitmentcommercial agreements described above, PBF Holding will be required to pay a shortfall payment equal to the shortfall volume multiplied by the fee of $2.52 per barrel.
PBFX is required to maintain the Toledo Storage Facility Assets in a condition and with a capacity sufficient to store and handle a volume of PBF Holding's products at least equal to the current operating capacity for the storage facility as a whole subject to interruptions for routine repairs and maintenance and force majeure events. Failure to meet such obligations may result in a reduction of fees payable under the Toledo Storage Facility Storage and Terminaling Agreement.
For the year ended December 31, 2015 and 2014, PBF Holding paid PBFX $25,495 and $1,420, respectively, related to the Toledo Tank Farm Storage and Terminaling Agreement.
Delaware City Pipeline Services Agreement
On May 15, 2015, PBF Holding entered into a pipeline services agreement with PBFX (the “Delaware City Pipeline Services Agreement”). Under the Delaware City Pipeline Services Agreement, PBFX provides PBF Holding with pipeline throughput services in return for throughput fees. The Delaware City Pipeline Services Agreement has an initial term of approximately ten years, after which PBF Holding has the option to extend the agreement for two additional five year periods, under which PBFX provides pipeline services to PBF Holding on the Delaware Products Pipeline. The minimum throughput commitment for the pipeline facility is 50,000 bpd for a fee equal to $0.5266 per barrel of product throughputted up to the minimum throughput commitment and in excess of the minimum throughput commitment. If PBF Holding does not throughput the aggregate amounts equal to the minimum throughput commitment described above, PBF Holding will be required to pay a shortfall payment equal to the shortfall volume multiplied by the fee. Effective July 2015, the pipeline service fee was raised to $0.5507 per barrel, due to an increase in the Federal Energy Regulatory Commission (“FERC”) tariff.
For the year ended December 31, 2015, PBF Holding paid PBFX fees of $6,328, related to the Delaware City Pipeline Services Agreement. For the year ended December 31, 2014, PBF Holding paid PBFX no fees related to the Delaware City Pipeline Services Agreement.
Delaware City Truck Loading Agreement
On May 15, 2015, PBF Holding entered into a terminaling services agreement with PBFX (the “Delaware City Truck Loading Agreement”). Under the Delaware City Truck Loading Agreement, PBFX provides PBF Holding

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

with terminaling services in return for fees. The Delaware City Truck Loading Agreement has an initial term of approximately ten years, after which PBF Holding has the option to extend the agreement for two additional five year periods, under which PBFX provides loading services to PBF Holding at the Delaware City Terminal. The minimum throughput commitment for the truck rack is at least 30,000 bpd for refined clean products with a fee equal to $0.462 per barrel and at least 5,000 bpd for LPGs with a fee equal to $2.52 per barrel of product loaded up to the minimum throughput commitment and for volumes in excess of the minimum throughput commitment.
For the year ended December 31, 2015, PBF Holding paid PBFX fees of $6,155, related to the Delaware City Truck Loading Agreement. For the year ended December 31, 2014, PBF Holding paid PBFX no fees related to the Delaware City Truck Loading Agreement.
Third Amended and Restated Omnibus Agreement
On May 14, 2014, PBF Holding entered into an Omnibus Agreement (the “Original Omnibus Agreement”) by and amongomnibus agreement with PBFX, PBF GP and PBF LLC, which has been amended and restated in connection with certain of the Contribution Agreements with PBFX, PBF GP and PBF HoldingLLC for the provision of executive management services and support for accounting and finance, legal, human resources, information technology, environmental, health and safety, and other administrative functions.
The Original Omnibus Agreement addresses the following matters:
PBFX’s obligation to pay PBF Holding, an administrative fee, in the amount of $2,300 per year, for the provision by PBF LLC of centralized corporate services (which fee is in addition to certain expenses of PBF GP and its affiliates that are reimbursed under the First Amended and Restated Agreement of Limited Partnership of PBFX (the “PBFX Partnership Agreement”));
PBFX’s obligation to reimburse PBF Holding for the salaries and benefits costs of employees who devote more than 50% of their time to PBFX;
PBFX’s agreement to reimburse PBF Holding for all other direct or allocated costs and expenses incurred by PBF LLC on PBFX’s behalf;
functions, as well as (i) PBF LLC’s agreement not to compete with PBFX under certain circumstances, subject to certain exceptions;
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;
exceptions, and (iii) a license to use the PBF Logistics trademark and name; and
PBF Holding’s agreement to reimburse PBFX for certain expenditures up to $20,000 per event (net of any insurance recoveries) related to the contributed assets for a period of five years after the closing of the PBFX Offering, and PBFX's agreement to bear the costs associated with the expansion of the DCR Rail Terminal crude unloading capability. The liability arising from this agreement is classified as “Accounts Payable - Affiliate” on the PBF Holding consolidated balance sheet.name.
On September 30, 2014, the Original Omnibus Agreement was amended and restatedJuly 31, 2018, in connection with the Development Assets Contribution Agreement II (the “Amended and Restated Omnibus Agreement”). The annual fee payable underAgreements, the Amended and Restated Omnibus Agreement increased from $2,300 to $2,525 as a result of the inclusion of the DCR West Rack. On December 12, 2014, PBF Holding, PBFX, PBF GP, and PBF LLCCompany entered into a Secondthe Fifth Amended and Restated Omnibus Agreement (the “Second A&R Omnibus“Omnibus Agreement”) to amend and restate the Amended and Restated Omnibus Agreement dated as of September 30, 2014, by and among the same parties. The Second A&R Omnibus Agreement clarified the reimbursements to be made bywith PBFX, to BF LLCupdate the provision of these executive management services and fromsupport for the Development Assets, which PBF LLCHolding expects to PBFX. The Second A&R Omnibus Agreement incorporatedresult in an increase of the Toledo Storage Facility Assets into its provisions and increased theestimated annual administrative fee to be paid by PBFX to PBF Energy from $2,525 to $2,700. Pursuant to the Omnibus Agreement, as amended, the annual fee of $2,700 per year was reduced to $2,225 per year effective as of January 1, 2015.$7,000.

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

On May 15, 2015, the Second A&R Omnibus Agreement was amended and restated to include the Delaware City Products Pipeline and Truck Rack (the “Third A&R Omnibus Agreement”). Pursuant to Third A&R Omnibus Agreement, the annual administrative fee was increased to $2,350 per year from $2,225 per year.
For the years ended December 31, 2015 and 2014, PBF Holding received from PBFX $5,216 and $2,174, respectively, for fees related to the Omnibus Agreement (as amended).
Third Amended and Restated Operation and Management Services and Secondment Agreement
Additionally, PBF Holding and certain of its subsidiaries entered into an operation and management services and secondment agreement (the “Services Agreement”) with PBFX, pursuant to which PBF Holding and its subsidiaries will provide PBFX with the personnel necessary for PBFX to perform its obligations under itsthe commercial agreements. PBFX will reimbursereimburses PBF Holding for the use of such employees and the provision of certain infrastructure-related services to the extent applicable to its operations, including storm water discharge and waste water treatment, steam, potable water, access to certain roads and grounds, sanitary sewer access, electrical power, emergency response, filter press, fuel gas, API solids treatment, fire water and compressed air. In addition,
On July 31, 2018, in connection with the Development Assets Contribution Agreements, the Company entered into the Sixth Amended and Restated Operation and Management Services and Secondment Agreement with PBFX will pay(the “Services Agreement”), resulting in an increase of the annual fee of $490 to PBF Holding for the provision of such services pursuant to the Services Agreement.$8,587. The Services Agreement will terminate upon the termination of the Omnibus Agreement, provided that PBFX may terminate any service on 30 days’30-days’ notice.
On September 30, 2014,Summary of Transactions with PBFX
A summary of transactions with PBFX is as follows:
  Year Ended December 31,
  2018 2017 2016
Reimbursements under affiliate agreements:      
Services Agreement $7,477
 $6,626
 $5,121
Omnibus Agreement 7,468
 6,899
 4,805
Total expenses under affiliate agreements 259,426
 240,654
 175,448
Total reimbursements under the Omnibus Agreement are included in General and administrative expenses and reimbursements under the Services Agreement was amended and restatedexpenses under affiliate agreements are included in connection with the Contribution Agreement II (the “AmendedCost of products and Restated Services Agreement”). The annual fee payable under the Amended and Restated Services Agreement increased from $490 to $797 (indexed for inflation) as a result of the inclusion of the DCR West Rack. On December 12, 2014, PBF Holding, Delaware City Refining Company LLC, Delaware City Terminaling Company LLC, Toledo Terminaling, Toledo Refining Company LLC, PBFX and PBF GP entered into the Second Amended and Restated Operation and Management Services and Secondment Agreement (the “Second A&R Services Agreement”) to incorporate the Toledo Storage Facility Assets into its provisions and increases the fee to be paid by PBFX to PBF Holding from $797 to $4,400.
On May 15, 2015, the Second A&R Services Agreement was amended and restated in connection with the Delaware City Pipeline and Truck Rack Acquisition (the “Third A&R Services Agreement”) resulting in an increaseother in the annual fee payable from $4,400 to $4,486.
For the year ended December 31, 2015 and 2014, PBF Holding received from PBFX $4,455 and $579, respectively, for fees related to the Services Agreement (as amended).
Fuel Strategies International, Inc. Agreement
The Company engaged Fuel Strategies International, Inc, the principalCompany’s statements of which is the brother of the Executive Chairman of the Board of Directors of PBF Energy, to provide consulting services relating to petroleum coke and commercial operations. For the year ended December 31, 2015 there were no charges under this agreement. For the years ended December 31, 2014 and 2013, the Company incurred charges of $588 and $646, respectively, under this agreement.
Agreement with the Executive Chairman of the Board of Directors
The Company has an agreement with the Executive Chairman of the Board of Directors of PBF Energy, for the use of an airplane that is owned by a company owned by the Executive Chairman of PBF Energy. The Company pays a charter rate that is the lowest rate this aircraft is chartered to third-parties. For the years ended December 31, 2015, 2014 and 2013, the Company incurred charges of $957, $1,214, and $1,274, respectively, related to the use of this airplane.

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

Financial Sponsors
As of December 31, 2013 each of Blackstone and First Reserve, PBF Energy’s financial sponsors had received the full return of itstheir 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 Reservethe investment funds associated with the initial investors in PBF LLC 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 Reservesuch investment funds (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 Reservethe investment funds associated with the initial investors in PBF LLC 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. There were no distributions to PBF LLC Series B unitholders for the years ending December 31, 2018 and 2017. The total amount distributed to the PBF LLC Series B Unit holdersunitholders for the years endedyear ending December 31, 2015 , 2014 and 20132016 was $19,592, $130,523, and $6,427 respectively. There were no amounts distributed to PBF LLC Series B Unit holders prior to 2013.$6,152.

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

13.11. COMMITMENTS AND CONTINGENCIES
Lease and Other Commitments
The Company leases office space, office equipment, refinery facilities and equipment and railcars under non-cancelable operating leases, with terms ranging from one to twenty years, subject to certain renewal options as applicable. Total rent expense was $126,060, $98,473,$129,599, $125,433, and $70,581$129,768 (excluding expenses for leases with affiliates of $131,819, $97,771 and $46,511) for the years ended December 31, 2015, 20142018, 2017 and 2013,2016, respectively. The Company is party to agreements which provide for the treatment of wastewater and the supply of hydrogen and steam for certain of its refineries. The Company made purchases of $36,139, $40,444$68,613, $64,050 and $38,383$53,364 under these supply agreements for the years ended December 31, 2015, 20142018, 2017 and 2013,2016, respectively.
The fixed and determinable amounts of the obligations under these agreements, inclusive of operating leases and minimum volume commitments with affiliates and total minimum future annual rentals to third parties, exclusive of related costs, are approximately:
Year Ending December 31,  
2016$138,890
2017131,057
2018122,286
201995,397
$342,210
202094,666
321,177
2021284,963
2022179,735
2023169,901
Thereafter237,435
542,513
$819,731
 
Total obligations$1,840,499
Employment Agreements
PBF Investments (“PBFI”) is party tohas 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

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

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 $10,367$10,961 recorded as of December 31, 2015 ($10,4762018 ($10,282 as of December 31, 2014)2017) represents the present value of expected future costs discounted at a rate of 8%8.0%. At December 31, 20152018 the undiscounted liability is $15,646totaled $17,807 and the Company expects to make aggregate payments for this liability of $5,998$5,932 over the next five years. The current portion of the environmental liability is recorded in accruedAccrued expenses and the non-current portion is recorded in otherOther long-term liabilities. As of December 31, 20152018 and 2014,2017, this liability is self-guaranteed by the Company.

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

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$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) 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 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. At the time the Company acquired the Chalmette refinery it was subject to a Consolidated Compliance Order and Notice of Potential Penalty (the “Order”) issued by the Louisiana Department of Environmental Quality (“LDEQ”) covering deviations from 2009 and 2010. Chalmette Refining and LDEQ subsequently entered into a dispute resolution agreement to negotiate the resolution of deviations on or before December 31, 2014. On May 18, 2018 the Order was settled by LDEQ and the Chalmette refinery for an administrative penalty of $741, of which $100 has been paid in cash and the remainder has been spent on beneficial environmental projects.
The Delaware City refinery appealed a Notice of Penalty Assessment and Secretary’s Order issued in March 2017, including a $150 fine, alleging violation of a 2013 Secretary’s Order authorizing crude oil shipment by barge. 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 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, the Delaware City refinery appealed the Notice of Penalty Assessment and Secretary’s Order. On March 5, 2018, Notice of Penalty Assessment was settled by DNREC, the Delaware Attorney General and Delaware City refinery for $100. The Delaware City refinery made no admissions with respect to the alleged violations and agreed to request a Coastal Zone Act status decision prior to making crude oil shipments to destinations other than Paulsboro. The Delaware City refinery has paid the penalty. The Coastal Zone Act status decision request was submitted to DNREC and the outstanding appeal was withdrawn as required under the settlement agreement.
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 (the “Coastal Zone Board”) held a public hearing and dismissed the appeal, determining that the appellants did not have standing. The appellants filed an appeal of the Coastal Zone Board’s decision with the Delaware Superior Court (the “Superior Court”) on March 30, 2017. On January 19, 2018, the Superior Court rendered an Opinion regarding the decision of the Coastal Zone Board to dismiss the appeal of the Ethanol Permit for the ethanol project. The Judge determined that the record created by the Coastal Zone Board was insufficient for the Superior Court to make a decision, and therefore remanded the case back to the Coastal Zone Board to address the deficiency in the record. Specifically, the Superior Court directed the Coastal Zone Board to address any evidence concerning whether the appellants’ claimed injuries would be affected by the increased quantity of ethanol shipments. On remand the Coastal Zone Board met on January 28, 2019 and reversed its previous decision on standing, ruling that the appellants have standing to appeal the issuance of the Ethanol Permit. DCR is currently evaluating its appeal options.

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

At the time the Company acquired the Toledo refinery, EPA had initiated an investigation into the compliance of the refinery with EPA standards governing flaring pursuant to Section 114 of the Clean Air Act. On February 1, 2013, EPA issued an Amended Notice of Violation, and on September 20, 2013, EPA issued a Notice of Violation and Finding of Violation to Toledo refinery, alleging certain violations of the Clean Air Act at its Plant 4 and Plant 9 flares since the acquisition of the refinery on March 1, 2011. Toledo refinery and EPA subsequently entered into tolling agreements pending settlement discussions. Although the resolution has not been finalized, the civil administrative penalty is anticipated to be approximately $645 including supplemental environmental projects. To the extent the administrative penalty exceeds such amount, it is not expected to be material to the Company.
In connection with the acquisition of the Torrance refinery and related logistics assets, the Company assumed certain pre-existing environmental liabilities totaling $130,817 as of December 31, 2018 ($136,487 as of December 31, 2017), related to certain environmental remediation obligations to address existing soil and groundwater contamination and monitoring activities and other clean-up activities, which reflects the current estimated cost of the remediation obligations. The Company expects to make aggregate payments for this liability of $46,189 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 and the logistics assets, including specified incidents and/or notices of violations (“NOVs”) issued by regulatory agencies in various years before the Company’s ownership, including the Southern California Air Quality Management District (“SCAQMD”) and the Division of Occupational Safety and Health of the State of California (“Cal/OSHA”).
In connection with the acquisition of the Torrance refinery and related logistics assets, the Company agreed to take responsibility for NOV No. P63405 that ExxonMobil had received from the SCAQMD for Title V deviations that are alleged to have occurred in 2015. On August 14, 2018, the Company received a letter from SCAQMD offering to settle this NOV for $515. The Company is currently in communication with SCAQMD to resolve this NOV.
Subsequent to the acquisition, further NOVs were issued by the SCAQMD, Cal/OSHA, the City of Torrance, the City of Torrance Fire Department, and the Los Angeles County Sanitation District related to alleged operational violations, emission discharges and/or flaring incidents at the refinery and the logistics assets both before and after the Company’s acquisition. EPA in November 2016 conducted a Risk Management Plan (“RMP”) inspection following the acquisition related to Torrance operations and issued preliminary findings in March 2017 concerning RMP potential operational violations. The Company is currently in communication with EPA to resolve the RMP preliminary findings. EPA and the California Department of Toxic Substances Control (“DTSC”) in December 2016 conducted a Resource Conservation and Recovery Act (“RCRA”) inspection following the acquisition related to Torrance operations and also issued in March 2017 preliminary findings concerning RCRA potential operational violations. In April 2017, EPA referred the RCRA preliminary findings to DTSC for final resolution. On March 1, 2018, the Company received a notice of intent to sue from Environmental Integrity Project, on behalf of Environment California, under RCRA with respect to the alleged violations from EPA’s and DTSC’s December 2016 inspection. On March 2, 2018, DTSC issued an order to correct alleged RCRA violations relating to the accumulation of oil bearing materials in roll off bins during 2016 and 2017. On June 14, 2018, the Torrance refinery and DTSC reached settlement regarding the oil bearing materials in the form of a stipulation and order, wherein the Torrance refinery agreed that it would recycle or properly dispose of the oil bearing materials by the end of 2018 and pay an administrative penalty of $150. The Torrance refinery has complied with these requirements. Following this settlement, in June 2018, DTSC referred the remaining alleged RCRA violations from EPA’s and DTSC’s December 2016 inspection to the California Attorney General for final resolution. The Torrance refinery and the California Attorney General are in discussions to resolve these remaining alleged RCRA violations. Other than the $150 DTSC administrative penalty, no other settlement or penalty demands have been received to date with respect to any of the other NOVs, preliminary findings, or order that are in excess of $100. As the ultimate outcomes are uncertain, the Company cannot currently estimate the final amount or timing of their resolution but any such amount

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

is not expected to have a material impact on the Company’s financial position, results of operations or cash flows, individually or in the aggregate.
Applicable Federal and State Regulatory Requirements
The Company’s operations and many of the products it manufactures are subject to certain specific requirements of the Clean Air Act (the “CAA”) and related state and local regulations. The CAA contains provisions that require capital expenditures for the installation of certain air pollution control devices at the Company’s refineries. Subsequent rule making authorized by the CAA or similar laws or new agency interpretations of existing rules, may necessitate additional expenditures in future years.
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, sixall of the Northeastern states and Washington DC have adopted sulfur controls on heating oil. As of July 1, 2018 most of the Northeastern states require heating oil with 15 PPM or less sulfur. By July 1, 2016, two more states are expected to adopt this requirement and by July 1, 2018 most of the remaining Northeastern statessulfur (except for Pennsylvania and New Hampshire) will require heating oil with 15Maryland where less than 500 PPM or less sulfur.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'sCompany’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.CAA. 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 refineries are complying with these new requirements as planned, either directly or using flexibility provided by sulfur credits generated or purchased in advance as an economic optimization. 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 wasCompany is required to releasecomply with the final annual standards for the Reformulated FuelsRenewable Fuel Standard (“RFS”) implemented by EPA, which sets annual quotas for 2014 no later than Nov 29, 2013 and for 2015 no later than Nov 29, 2014. Thethe quantity of renewable fuels (such as ethanol) that must be blended into motor fuels consumed in the United States. In July 2018, EPA did not meet these requirements but did releaseissued proposed amendments to the RFS program regulations that would establish annual percentage standards for 2014. The EPA did not finalize this proposal in 2014. However, in May 2015, the EPA re-proposed annual standards for RFS 2 for 2014, and proposed new standards for 2015 and 2016 andcellulosic biofuel, biomass-based diesel, volumes for 2017. The final standards were issued on November 30, 2015. The standards

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

issued by the EPA include volume requirements in the annual standards which, while below the volumes originally set by Congress, increasedadvanced biofuel, and renewable fuel usefuels that would apply to all gasoline and diesel produced in the U.S. above historical levels and provide for steady growth over time. The EPA also increasedor imported in the required volume ofyear 2019. In addition, the separate proposal includes a proposed biomass-based diesel in 2015, 2016,applicable volume for 2020. It is likely that RIN production will continue to be lower than needed forcing obligated parties, such as the Company, to purchase cellulosic waiver credits or purchase excess RINs from suppliers on the open market.
In addition, on November 26, 2018 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 2017 while maintainingdelayed coke drum vent controls to be installed by January 30, 2019. In addition, a program for ambient fence line monitoring for benzene was implemented prior to the opportunity for growth in other advanced biofuels.deadline of January 30, 2018. The Company is currently evaluatingin the final standards and they mayprocess of implementing the requirements of this regulation. The regulation does not have a material impact on the Company's costCompany’s financial position, results of compliance with RFS 2.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)(“BTA”) as soon as possible, but state agencies have the discretion to establish implementation time lines. The Company continues to evaluate the impact of this regulation, and at this time does not anticipate it having a material impact on the Company’s financial position, results of operations or cash flows.

In addition,
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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

As a result of the Torrance Acquisition, the Company is subject to greenhouse gas emission control regulations in the state of California pursuant to AB32. AB32 imposes a statewide cap on December 1, 2015greenhouse gas emissions, including emissions from transportation fuels, with the EPA finalized revisionsaim 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, which was extended for 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 relievingten years 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, 2018.2030 in July 2017. The Company is currently evaluatingresponsible for the final standardsAB32 obligations related to evaluate the impactTorrance refinery beginning on July 1, 2016 and must purchase emission credits to comply with these obligations. Additionally, in September 2016, the state of this regulation,California enacted Senate Bill 32 (“SB32”) 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 at this timeas such does not anticipate itexpect this obligation to materially impact the Company’s financial position, results of operations, or cash flows. To the degree there are unfavorable changes to AB32 or SB32 regulations or the Company is unable to recover such compliance costs from customers, these regulations could have a material adverse effect on our financial position, results of operations and cash flows.
The Company is subject to obligations to purchase RINs. On February 15, 2017, the Company received a notification that EPA records indicated that PBF Holding used potentially invalid RINs that were in fact verified under EPA’s RIN Quality Assurance Program (“QAP”) by an independent auditor as QAP A RINs. Under the regulations, use of potentially invalid QAP A RINs provided the user with an affirmative defense from civil penalties provided certain conditions are met. The Company has asserted the affirmative defense and if accepted by EPA will not be required to replace these RINs and will not be subject to civil penalties under the program. It is reasonably possible that EPA will not accept the Company’s defense and may assess penalties in these matters but any such amount is not expected to have a material impact on the Company'sCompany’s financial position, results of operations or cash flows.

As of January 1, 2011, the Company is required to comply with EPA’s Control of Hazardous Air Pollutants From Mobile Sources, or MSAT2, regulations on gasoline that impose reductions in the benzene content of its produced gasoline. The Company purchases benzene credits to meet these requirements. The Company’s planned capital projects will reduce the amount of benzene credits that it needs to purchase. In addition, the renewable fuel standards mandate the blending of prescribed percentages of renewable fuels (e.g., ethanol and biofuels) into the Company’s produced gasoline and diesel. These new requirements, other requirements of the CAA and other presently existing or future environmental regulations may cause the Company to make substantial capital expenditures as well as the purchase of credits at significant cost, to enable its refineries to produce products that meet applicable requirements.
The Delaware City Rail Terminalfederal Comprehensive Environmental Response, Compensation and DCR West RackLiability Act of 1980 (“CERCLA”), also known as “Superfund,” imposes liability, without regard to fault or the legality of the original conduct, on certain classes of persons who are collocated withconsidered to be responsible for the Delaware City refinery,release of a “hazardous substance” into the environment. These persons include the current or former owner or operator of the disposal site or sites where the release occurred and are located in Delaware's coastal zone where certain activities are regulated undercompanies that disposed of or arranged for the Delaware Coastal Zone act. On June 14, 2013, two administrative appeals were filed bydisposal of the Sierra Clubhazardous substances. Under CERCLA, such persons may be subject to joint and Delaware Audubon (collectively, the “Appellants”) regarding an air permit Delaware City Refining obtained to allow loading of crude oil onto barges. The appeals allege that both the loading of crude oil onto bargesseveral liability for investigation and the operationcosts of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. As discussed more fully above, certain of the Delaware City Rail Terminal violate Delaware’s Coastal Zone Act. The first appeal is Number 2013-1 before the State Coastal Zone Industrial Control Board (the “CZ Board”),Company’s sites are subject to these laws and the second appealCompany may be held liable for investigation and remediation costs or claims for natural resource damages. It is beforenot uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the Environmental Appeals Board (the “EAB”)environment. Analogous state laws impose similar responsibilities and appeals Secretary’s Order No. 2013-A-0020. The CZ Board heldliabilities on responsible parties. In the Company’s current normal operations, it has generated waste, some of which falls within the statutory definition of a hearing on the first appeal on July 16, 2013,“hazardous substance” and ruled in favorsome of Delaware City Refining and the Statewhich may have been disposed of Delaware and dismissed Appellants’ appeal for lack of standing. The Appellants appealedat sites that decision to the Delaware Superior Court, New Castle County, Case No. N13A-09-001 ALR, and Delaware City Refining and the State of Delaware filed cross-appeals. A hearing on the second appeal before the EAB, case no. 2013-06, was held on January 13, 2014, and the EAB ruled in favor of Delaware City Refining and the State and dismissed the appeal for lack of jurisdiction. The Appellants also filed a Notice of Appeal with the Superior Court appealing the EAB’s decision. On March 31, 2015 the Superior Court affirmed the decisions by both the CZ Board and the EAB stating they both lacked jurisdiction to rule on the Appellants' appeal. The Appellants appealed to the Delaware Supreme Court, and, on November 5, 2015, the Delaware Supreme Court affirmed the Superior Court decision.

may require cleanup under Superfund.
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.

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

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

F- 34

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

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 generally obtains funding to pay its tax distributions by causing PBF Holding to distribute cash to PBF LLC and from distributions it receives from PBFX.

Tax Receivable Agreement
PBF Energy (the Company'sCompany’s indirect parent) entered into a tax receivable agreement with the PBF LLC Series A and PBF LLC Series B Unit holdersunitholders (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'sEnergy Class A common stock and had PBF Energy not entered into the Tax Receivable Agreement. The term of the Tax Receivable Agreement will continue until all such tax benefits have been utilized or expired unless: (i) PBF Energy exercises its right to terminate the Tax Receivable Agreement, (ii) PBF Energy breaches any of its material obligations under the Tax Receivable Agreement or (iii) certain changes of control occur, in which case all obligations under the Tax Receivable Agreement will generally be accelerated and due as calculated under certain assumptions.

The payment obligations under the Tax Receivable Agreement are obligations of PBF Energy and not of PBF LLC or PBF Holding. In general, PBF Energy expects to obtain funding for these annual payments from PBF LLC, primarily through tax distributions, which PBF LLC makes on a pro-rata basis to its owners. Such owners include PBF Energy, which holds a 95.1%99.0% and 89.9%96.7% interest in PBF LLC as of December 31, 20152018 and December 31, 2014,2017, respectively. PBF LLC generally obtains funding to pay its tax distributions by causing PBF Holding to distribute cash to PBF LLC and from distributions it receives from PBFX.

F- 40

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

As a result of the reduction of the corporate federal tax rate to 21% as part of the TCJA, PBF Energy’s liability associated with the Tax Receivable Agreement was reduced.

14.12. EQUITY STRUCTURE
PBF Holding has no common stock outstanding. As of December 31, 2015,2018, 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'sCompany’s indirect and direct parents, PBF Energy and PBF LLC, respectively.

F- 35

PBF HOLDING COMPANY LLCEnergy Capital Structure
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

PBF Energy Class A Common Stock
Holders of Class A common stock are entitled to receive dividends when and if declared by the Board of Directors of PBF Energy out of funds legally available therefore, subject to any statutory or contractual restrictions on the payment of dividends and to any restrictions on the payment of dividends imposed by the terms of any outstanding preferred stock. Upon PBF Energy'sEnergy’s dissolution or liquidation or the sale of all or substantially all of the assets, after payment in full of all amounts required to be paid to creditors and to the holders of preferred stock having liquidation preferences, if any, the holders of shares of Class A common stock will be entitled to receive pro rata remaining assets available for distribution. Holders of shares of Class A common stock do not have preemptive, subscription, redemption or conversion rights.
PBF Energy Class B Common Stock
Holders of shares of Class B common stock are entitled, without regard to the number of shares of Class B common stock held by such holder, to one vote for each PBF LLC Series A Unit beneficially owned by such holder. Accordingly, the the members of PBF LLC other than PBF Energy collectively have a number of votes in PBF Energy that is equal to the aggregate number of PBF LLC Series A Units that they hold.
Holders of shares of Class A common stock and Class B common stock vote together as a single class on all matters presented to stockholders for their vote or approval, except as otherwise required by applicable law.
Holders of Class B common stock do not have any right to receive dividends or to receive a distribution upon a liquidation or winding up of PBF Energy.
PBF Energy Preferred Stock
Authorized preferred stock may be issued in one or more series, with designations, powers and preferences as shall be designated by the Board of Directors.
PBF LLC Capital Structure
PBF LLC Series A Units
The allocation of profits and losses and distributions to PBF LLC Series A unit holdersunitholders 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 holdersunitholders do not have voting rights.

F- 41

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

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'sEnergy’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

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PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

Subsequent to the Chlamette Acquisition, PBF Holding recorded noncontrolling interest in two subsidiaries of Chalmette refinery. PBF Holding, through Chalmette Refining, owns an 80% ownership interest in both Collins Pipeline Company and T&M Terminal Company. The Company recorded earnings related to the noncontrolling interest in these subsidiaries of $274 for the year ended December 31, 2015.

15. STOCK-BASED COMPENSATION
Stock-based compensation expense included in general and administrative expenses consisted of the following:
  Years Ended December 31,
  2015 2014 2013
PBF LLC Series A Unit compensatory warrants and options $
 $522
 $779
PBF LLC Series B Units 
 
 530
PBF Energy options 7,528
 4,343
 2,051
PBF Energy restricted shares 1,690
 1,230
 393
  $9,218
 $6,095
 $3,753
PBF LLC Series A warrants and optionsB Units
The PBF LLC granted compensatory warrantsSeries B Units are intended to employeesbe “profit interests” within the meaning of Revenue Procedures 93-27 and 2001-43 of the CompanyInternal 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 connection withvalue only after the Company’s financial sponsors achieve certain levels of return on their purchase of Series A unitsinvestment in PBF LLC. The warrants grant the holder the right to purchase PBF LLC Series A Units. One-quarterAccordingly, 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 compensatory warrants were exercisable atUnits held by the date of grantCompany’s financial sponsors, and the remaining three-quarters become exercisable over equal annual installments on each of the first three anniversaries of the grant date subjectwill not reduce or otherwise impact any amounts payable 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 offeringPBF Energy (the holder of PBF Energy in December 2012.
In addition, options to purchaseLLC Series C Units), the holders of PBF Energy’s Class A common stock or any other holder of PBF LLC Series A units were grantedUnits. The maximum number of PBF LLC Series B Units authorized 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.be issued is 1,000,000.
PBF LLC Series C Units
The Company did not issuePBF LLC Series C Units rank on a parity with the PBF LLC Series A Units compensatory warrantsas to distribution rights, voting rights and rights upon liquidation, winding up or options in 2015, 2014 or 2013.

F- 37

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

The following table summarizes activity fordissolution. PBF LLC Series A compensatory warrants and options for the years ended December 31, 2015, 2014 and 2013:
  
Number of
PBF LLC
Series A
Compensatory
Warrants
and Options
 
Weighted
Average
Exercise Price
 
Weighted
Average
Remaining
Contractual
Life
(in years)
Stock Based Compensation, Outstanding at January 1, 2013 1,184,726
 $10.44
 8.23
Exercised (301,979) 10.11
 
Forfeited (41,668) 11.27
 
Outstanding at December 31, 2013 841,079
 $10.52
 7.40
Exercised (32,934) 10.00
 
Forfeited (6,666) 11.59
 
Outstanding at December 31, 2014 801,479
 $10.53
 6.41
Exercised (160,700) 10.28
 
Outstanding at December 31, 2015 640,779
 $10.59
 5.46
Exercisable and vested at December 31, 2015 640,779
 $10.59
 5.46
Exercisable and vested at December 31, 2014 753,985
 $10.41
 6.34
Exercisable and vested at December 31, 2013 545,247
 $10.24
 7.23
Expected to vest at December 31, 2015 640,779
 $10.59
 5.46
The total intrinsic value of stock options outstanding and exercisable at December 31, 2015, was $16,797, respectively. The total intrinsic value of stock options exercised during the years ended December 31, 2015, 2014, and 2013 was $3,452, $618, and $4,298, respectively.
There was no unrecognized compensation expense related toC Units are held solely by PBF LLC Series A warrants and options at December 31, 2015. Unrecognized compensation expense related to PBF LLC Series A warrants and options at December 31, 2014 was $140, which was recognized in 2015.Energy.
Prior to 2014, members of management of the Company had also purchased an aggregate of 2,740,718 non-compensatory Series A warrants in PBF LLC with an exercise price of $10.00 per unit, all of which were immediately exercisable. During the year ended December 31, 2015 and 2014, 24,000 and 11,700 non-compensatory warrants were exercised, respectively. At December 31, 2015 and 2014, there were 32,719 and 56,719 non-compensatory warrants outstanding, respectively.
PBF LLC Series B Units
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 interests 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 attributable to the noncontrolling interest in these subsidiaries of $44 and $95 for the years ended December 31, 2018 and December 31, 2017, respectively.

13. STOCK-BASED COMPENSATION
Stock-based compensation expense included in general and administrative expenses consisted of the following:
  Years Ended December 31,
  2018 2017 2016
PBF Energy options $11,545
 $9,369
 $11,020
PBF Energy restricted shares 7,460
 12,134
 7,276
PBF Energy performance awards 1,207
 
 
  $20,212
 $21,503

$18,296
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 Unit compensatory warrants or options in 2018, 2017 or 2016.

F- 42

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

The following table summarizes activity for PBF LLC Series A compensatory warrants and options for the years ended December 31, 2018, 2017 and 2016:
  
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, 2016 640,779
 $10.59
 5.46
Exercised (27,833) 10.00
 
Outstanding at December 31, 2016 612,946
 $10.62
 4.47
Exercised (126,634) 10.17
 
Outstanding at December 31, 2017 486,312
 $10.73
 3.52
Exercised (243,700) 10.62
 
Outstanding at December 31, 2018 242,612
 $10.85
 2.64
       
Exercisable and vested at December 31, 2018 242,612
 $10.85
 2.64
Exercisable and vested at December 31, 2017 486,312
 $10.73
 3.52
Exercisable and vested at December 31, 2016 612,946
 $10.62
 4.47
Expected to vest at December 31, 2018 242,612
 $10.85
 2.64

The total intrinsic value of stock options both outstanding and exercisable at December 31, 2018 and December 31, 2017 was $5,290 and $12,016, respectively. The total intrinsic value of stock options exercised during the years ended December 31, 2018, 2017, and 2016 was $7,487, $2,301, and $461, respectively.
There was no unrecognized compensation expense related to PBF LLC Series A warrants and options at December 31, 2018 and December 31, 2017.
Prior to 2014, members of management of the Company had also purchased non-compensatory Series A warrants in PBF LLC with an exercise price of $10.00 per unit, all of which were immediately exercisable. During the year ended December 31, 2018, 19,400 non-compensatory warrants were exercised. There were no non-compensatory warrants exercised during December 31, 2017. At December 31, 2018 and 2017, there were 13,319 and 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.

F- 38

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

The following table summarizes There was no activity for PBF LLCrelated to the Series B Unitsunits for the yearyears ended December 31, 2013:
  Number of
PBF LLC
Series B units
 Weighted
Average
Grant Date
Fair Value
Non-vested units at January 1, 2013 250,000
 $5.11
Allocated 
 
Vested (250,000) 5.11
Forfeited 
 
Non-vested units at December 31, 2013 
 $
2018, 2017 or 2016.
PBF Energy options and restricted stock
PBF Energy grants awards of its Class A common stock under the 2012 Equity Incentive Planits equity incentive plans which authorizesauthorize 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.plans.
A total of 1,899,500 and 1,135,000 options to purchase shares of
F- 43

PBF Energy Class A common stock were granted to certain employees and management of the Company in the years ended December 31, 2015 and 2014, respectively. A total of 247,720 and 30,348 restricted Class A common stock were granted to certain directors, employees and management of the Company as of December 31, 2015 and 2014, respectively. HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

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 following table summarizes activity for PBF Energy restricted stock for the years ended December 31, 2018, 2017 and 2016.
  Number of
PBF Energy
Restricted Class A
Common Stock
 
Weighted Average
Grant Date
Fair Value
Nonvested at January 1, 2016 294,880
 $30.87
Granted 360,820
 22.44
Vested (134,331) 31.43
Forfeited 
 
Nonvested at December 31, 2016 521,369
 $24.89
Granted 762,425
 25.86
Vested (172,978) 24.99
Forfeited (15,100) 24.18
Nonvested at December 31, 2017 1,095,716
 $25.56
Granted 58,830
 47.24
Vested (345,073) 26.13
Forfeited (15,519) 24.18
Nonvested at December 31, 2018 793,954
 $26.88

Unrecognized compensation expense related to PBF Energy Restricted Class A Common Stock at December 31, 2018 was $10,280, which will be recognized from 2019 through 2022.
The estimated fair value of PBF Energy options granted during the years ended December 31, 2015, 20142018, 2017 and 20132016 was determined using the Black-Scholes pricing model with the following weighted average assumptions:
 December 31, 2015 December 31, 2014 December 31, 2013 December 31, 2018 December 31, 2017 December 31, 2016
Expected life (in years) 6.25
 6.25
 6.25
 6.25
 6.25
 6.25
Expected volatility 38.4% 52.0% 52.1% 35.8% 39.5% 39.7%
Dividend yield 3.96% 4.82% 4.43% 3.49% 4.58% 4.73%
Risk-free rate of return 1.58% 1.80% 1.53% 2.82% 2.09% 1.42%
Exercise price $30.28
 $24.78
 $27.79
 $35.25
 $26.52
 $26.18


F- 3944

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

The following table summarizes activity for PBF Energy options for the years ended December 31, 2015, 20142018, 2017 and 2013.2016.
 Number of
PBF Energy
Class A
Common
Stock Options
 Weighted
Average
Exercise Price
 Weighted
Average
Remaining
Contractual
Life
(in years)
 Number of
PBF Energy
Class A
Common
Stock Options
 Weighted
Average
Exercise Price
 Weighted
Average
Remaining
Contractual
Life
(in years)
Stock-based awards, outstanding at January 1, 2013 682,500
 $26.00
 9.95
Stock-based awards, outstanding at January 1, 2016 4,256,375
 $27.89
 8.32
Granted 697,500
 27.79
 10.00
 1,792,000
 26.18
 10.00
Exercised 
 
 
 (11,250) 25.86
 
Forfeited (60,000) 25.36
 
 (66,500) 28.74
 
Outstanding at December 31, 2013 1,320,000
 $26.97
 9.33
Outstanding at December 31, 2016 5,970,625
 $27.37
 8.02
Granted 1,135,000
 24.78
 10.00
 1,638,075
 26.52
 10.00
Exercised 
 
 
 (462,500) 25.65
 
Forfeited (53,125) 25.44
 
 (263,425) 27.71
 
Outstanding at December 31, 2014 2,401,875
 $25.97
 8.67
Outstanding at December 31, 2017 6,882,775
 $27.27
 7.82
Granted 1,899,500
 30.28
 10.00
 2,500,742
 35.25
 10.00
Exercised (30,000) 25.79
 
 (884,878) 27.57
 
Forfeited (15,000) 26.38
 
 (141,981) 33.49
 
Outstanding at December 31, 2015 4,256,375
 $27.89
 8.32
Exercisable and vested at December 31, 2015 1,136,250
 $26.22
 7.61
Exercisable and vested at December 31, 2014 485,000
 $26.66
 8.21
Exercisable and vested at December 31, 2013 158,125
 $26.00
 8.95
Expected to vest at December 31, 2015 4,256,375
 $27.89
 8.23
Outstanding at December 31, 2018 8,356,658
 $29.60
 7.48
Exercisable and vested at December 31, 2018 3,531,066
 $27.39
 6.27
Exercisable and vested at December 31, 2017 2,958,875
 $27.58
 6.77
Exercisable and vested at December 31, 2016 2,271,375
 $27.23
 7.21
Expected to vest at December 31, 2018 8,356,658
 $29.60
 7.48
The total estimated fair value of PBF Energy options granted in 20152018 and 20142017 was $14,512$23,892 and $9,068$10,913 and the weighted average per unit fair value was $7.64$9.55 and $7.99.$6.66. The total intrinsic value of stock options outstanding and exercisable at December 31, 2015,2018, was $38,167$36,523 and $12,139,$19,355, respectively. The total intrinsic value of stock options outstanding and exercisable at December 31, 2017, was $56,656 and $23,665, respectively. The total intrinsic value of stock options exercised during the yearyears ended December 31, 20152018 and 2017 was $133.$12,445 and $2,365, respectively.
Unrecognized compensation expense related to PBF Energy options at December 31, 20152018 was $21,556,$33,162, which will be recognized from 20162019 through 2019.2022.
PBF Energy Performance Awards
Performance Share Awards
In October 2018, the PBF Energy granted 179,072 performance share awards, with a weighted average grant date fair value of $50.23, to certain officers of the Company which have a three-year performance period from January 1, 2018 through December 31, 2020 (“Performance Cycle”). The payout for the performance share units is based on the relative ranking of the TSR of PBF Energy’s common stock as compared to the TSR of a selected group of industry peer companies over an average of four measurement periods. The performance share units will vest on December 31, 2020, subject to forfeiture or acceleration under certain circumstances set forth in the award agreement.

F- 45

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

The performance share awards are issued under PBF Energy’s 2017 equity compensation plan and are settled in PBF Energy’s common stock at the end of the performance cycle. The number of shares distributed will range from zero to 200 percent of the number of performance share units granted based on the Company’s achievement of prescribed TSR rankings relative to its peers during the applicable performance measurement periods in the Performance Cycle plus additional shares of Common Stock may be awarded at vesting with respect to the computed value of dividend equivalents accrued during such performance measurement. The performance share awards are accounted for as equity awards, for which the fair value was determined on the grant date by application of a Monte Carlo simulation model. For the year ended December 31, 2018 there have been no forfeitures of performance share awards.
The performance share awards grant date fair value was calculated using a Monte Carlo valuation model with the following assumptions:
Risk-free interest rate2.89%
Dividend yield2.95%
Expected volatility39.04%

The risk-free interest rate for the remaining performance period as of the grant date is based on a linear interpolation of published yields of traded U.S. Treasury Interest-Only STRIP Bonds. The dividend yield assumption is based on the annualized most recent quarterly dividend divided by the stock price on the grant date. The assumption for the expected volatility of the Company’s stock price reflects the average of PBF Energy’s common stock historical and implied volatility.
As of December 31, 2018, unrecognized compensation cost related to performance share awards was $8,303, which is expected to be recognized over a weighted average period of two years.

Performance Unit awards
In October 2018, the Company granted 7,279,188 performance unit awards, with a fair value of $0.92 at December 31, 2018, to certain officers of the Company. The Performance Cycle and payout methodology for the performance unit awards is consistent with that of the performance share units. The performance units will vest on December 31, 2020, subject to forfeiture or acceleration under certain circumstances set forth in the award agreement.
The performance unit awards are dollar denominated with a target value of $1.00, with actual payout of up to $2.00 per unit (or 200 percent of target). The performance unit awards are settled in cash based on the payout amount determined at the end of the performance cycle. The Company accounts for the performance unit awards as liability awards which the Company recorded at fair market value on the date of grant. Subsequently, the performance unit awards will be marked-to-market at the end of each fiscal quarter by application of a Monte Carlo simulation model. For the year ended December 31, 2018 there have been no forfeitures of performance unit awards.
As of December 31, 2018, unrecognized compensation cost related to performance unit awards was $6,182, which is expected to be recognized over a weighted average period of two years.

16.14. EMPLOYEE BENEFIT PLANS
Defined Contribution Plan
The Company’s defined contribution plan covers all employees. Employees are eligible to participate as of the first day of the month following 30 days of service. Participants can make basic contributions up to 50 percent of their annual salary subject to Internal Revenue Service limits. The Company matches participants’ contributions at the rate of 200 percent of the first 3 percent of each participant’s total basic contribution based on the participant’s total annual salary. The Company’s contribution to the qualified defined contribution plans was $12,753, $11,364$26,310, $23,321 and $10,450$19,746 for the years ended December 31, 2015, 20142018, 2017 and 2013,2016, respectively.

F- 46

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

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

F- 40

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

Plan”). The funded status is measured as the difference between plan assets at fair value and the projected benefit obligation which is to be recognized in the consolidated balance sheet. The plan assets and benefit obligations are measured as of the consolidated balance sheet date.
The non-union Delaware City employees and all Paulsboro, Toledo, Chalmette and ChalmetteTorrance employees became eligible to participate in the Company’s defined benefit plans as of the respective acquisition dates. The union Delaware City employees became eligible to participate in the Company’s defined benefit plans upon commencement of normal operations. The Company did not assume any of the employees’ pension liability accrued prior to the respective acquisitions.
The Company formed the Post-Retirement Medical Plan on December 31, 2010 to provide health care coverage continuation from date of retirement to age 65 for qualifying employees associated with the Paulsboro acquisition. The Company credited the qualifying employees with their prior service under Valero which resulted in the recognition of a liability for the projected benefit obligation. The Post-Retirement Medical Plan was amended during 2013 to include all corporate employees, amended in 2014 to include Delaware City and Toledo employees, and amended in 2015 to include Chalmette employees and amended in 2016 to include Torrance employees.


F- 47

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

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, 20152018 and 20142017 were as follows:
 Pension Plans 
Post-Retirement
Medical Plan
 Pension Plans 
Post-Retirement
Medical Plan
 2015 2014 2015 2014 2018 2017 2018 2017
Change in benefit obligation:                
Benefit obligation at beginning of year $81,098
 $53,350
 $14,740
 $8,225
 $185,231
 $135,508
 $21,527
 $22,740
Service cost 24,298
 19,407
 967
 1,099
 47,344
 40,572
 1,148
 1,263
Interest cost 2,974
 2,404
 558
 520
 5,793
 4,336
 620
 688
Plan amendments 
 529
 1,533
 3,911
 
 462
 
 
Plan settlements 
 (4,881) 
 
Benefit payments (2,231) (2,634) (381) (215) (7,214) (4,034) (562) (693)
Actuarial loss (gain) (6,128) 8,042
 312
 1,200
Actuarial (gain) loss (12,811) 13,268
 (3,388) (2,471)
Projected benefit obligation at end of year $100,011
 $81,098
 $17,729
 $14,740
 $218,343
 $185,231
 $19,345
 $21,527
Change in plan assets:                
Fair value of plan assets at beginning of year $40,956
 $25,050
 $
 $
 $121,652
 $75,367
 $
 $
Actual return on plan assets (13) 1,822
 
 
 (6,148) 14,019
 
 
Benefits paid (2,231) (2,634) (381) (215) (7,214) (4,034) (562) (693)
Plan settlements 
 (4,881) 
 
Employer contributions 18,790
 16,718
 381
 215
 35,081
 41,181
 562
 693
Fair value of plan assets at end of year $57,502
 $40,956
 $
 $
 $143,371
 $121,652
 $
 $
Reconciliation of funded status:                
Fair value of plan assets at end of year $57,502
 $40,956
 $
 $
 $143,371
 $121,652
 $
 $
Less: benefit obligations at end of year 100,011
 81,098
 17,729
 14,740
Less benefit obligations at end of year 218,343
 185,231
 19,345
 21,527
Funded status at end of year $(42,509) $(40,142) $(17,729) $(14,740) $(74,972) $(63,579) $(19,345) $(21,527)
The accumulated benefit obligations for the Company’s Pension Plans exceed the fair value of the assets of those plans at December 31, 20152018 and 2014.2017. The accumulated benefit obligation for the defined benefit plans approximated $80,897$184,531 and $66,576$148,011 at December 31, 20152018 and 2014,2017, 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
2019 $11,155
 $1,342
2020 13,039
 1,605
2021 16,570
 1,726
2022 19,991
 1,761
2023 19,228
 1,746
Years 2024-2028 136,559
 9,121


F- 4148

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

  Pension Benefits 
Post-Retirement
Medical Plan
2016 $11,125
 $843
2017 8,271
 1,141
2018 9,403
 1,296
2019 10,694
 1,580
2020 13,429
 1,788
Years 2021-2025 88,044
 8,835

The Company’s funding policy for its defined benefit plans is to contribute amounts sufficient to meet legal funding requirements, plus any additional amounts that may be appropriate considering the funded status of the plans, tax consequences, the cash flow generated by the Company and other factors. The Company plans to contribute approximately $16,700$34,000 to the Company’s Pension Plans during 2016.2019.

The components of net periodic benefit cost were as follows for the years ended December 31, 2015, 20142018, 2017 and 2013:2016:
 Pension Benefits 
Post-Retirement
Medical Plan
 Pension Benefits 
Post-Retirement
Medical Plan
 2015 2014 2013 2015 2014 2013 2018 2017 2016 2018 2017 2016
Components of net period benefit cost:            
Components of net periodic benefit cost:            
Service cost $24,298
 $19,407
 $14,794
 $967
 $1,099
 $726
 $47,344
 $40,572
 $36,359
 $1,148
 $1,263
 $1,047
Interest cost 2,974
 2,404
 992
 558
 520
 334
 5,793
 4,336
 3,096
 620
 688
 528
Expected return on plan assets (3,422) (2,156) (550) 
 
 
 (8,540) (5,766) (4,681) 
 
 
Settlement loss recognized 
 993
 
 
 
 
Amortization of prior service cost 53
 39
 11
 326
 258
 
 85
 53
 53
 646
 646
 541
Amortization of actuarial loss (gain) 1,228
 1,033
 421
 
 (4) 
Amortization of actuarial loss 285
 452
 1,043
 
 
 
Net periodic benefit cost $25,131
 $20,727
 $15,668
 $1,851
 $1,873
 $1,060
 $44,967
 $40,640
 $35,870
 $2,414
 $2,597
 $2,116

Lump sum payments made by the Supplemental Plan to employees retiring in 2018 did not exceed the Plan’s total service and interest costs expected for 2018. Lump sum payments made by the Supplemental Plan to employees retiring in 2017 exceeded the Plan’s total service and interest costs expected for 2017. Settlement losses are required to be recorded when lump sum payments exceed total service and interest costs. As a result, the 2017 pension expense included a settlement expense related to our cumulative lump sum payments made during the year ended December 31, 2017.
The pre-tax amounts recognized in other comprehensive income (loss) for the years ended December 31, 2015, 20142018, 2017 and 20132016 were as follows:
 Pension Benefits 
Post-Retirement
Medical Plan
 Pension Benefits 
Post-Retirement
Medical Plan
 2015 2014 2013 2015 2014 2013 2018 2017 2016 2018 2017 2016
Prior service costs (credits) $
 $529
 $
 $1,533
 $3,911
 $(860)
Prior service costs $
 $462
 $
 $
 $
 $2,524
Net actuarial loss (gain) (2,220) 8,151
 8,235
 312
 1,201
 (1,654) 1,877
 5,015
 176
 (3,388) (2,471) 1,487
Amortization of losses and prior service cost (1,281) (1,072) (432) (326) (255) 
 (826) (1,410) (1,096) (646) (646) (541)
Total changes in other comprehensive loss (income) $(3,501) $7,608
 $7,803
 $1,519
 $4,857
 $(2,514)
Total changes in other comprehensive income (loss) $1,051
 $4,067
 $(920) $(4,034) $(3,117) $3,470

F- 49

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

The pre-tax amounts in accumulated other comprehensive lossincome (loss) as of December 31, 20152018 and 20142017 that have not yet been recognized as components of net periodic costs were as follows:
 

F- 42

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

 Pension Benefits 
Post-Retirement
Medical Plan
 Pension Benefits 
Post-Retirement
Medical Plan
 2015 2014 2015 2014 2018 2017 2018 2017
Prior service (costs) credits $(529) $(582) $(3,999) $(2,793)
Prior service costs $(799) $(885) $(4,691) $(5,337)
Net actuarial (loss) gain (19,841) (23,762) (391) (78) (24,136) (22,544) 3,981
 593
Total $(20,370) $(24,344) $(4,390) $(2,871) $(24,935) $(23,429) $(710) $(4,744)

The following pre-tax amounts included in accumulated other comprehensive lossincome (loss) as of December 31, 20152018 are expected to be recognized as components of net periodperiodic benefit cost during the year ended December 31, 2016:2019:
  Pension Benefits 
Post-Retirement
Medical Plan
Amortization of prior service costs (credits) $(53) $(436)
Amortization of net actuarial loss (gain) (775) 
Total $(828) $(436)

Effective December 31, 2015, we changed the method we use to estimate the service and interest components of net periodic benefit cost for the Qualified Plan, the Supplemental Plan and the Post-Retirement Medical Plan. Historically, we estimated these service and interest cost components utilizing a single weighted-average discount rate derived from the yield curve used to measure the benefit obligation for each of these plans at the beginning of the period. Additionally, we historically combined the disclosures of assumptions for the Qualified Plan and the Supplemental Plan in one category we called “Pension Benefits”. We have elected to utilize a full yield curve approach in the estimation of these components by applying the specific spot rates along the yield curve used in the determination of the benefit obligation to the relevant projected cash flows for each plan separately. We have made this change to provide a more precise measurement of service and interest costs by improving the correlation between projected benefit cash flows to the corresponding spot yield curve rates. This change does not affect the measurement of our total benefit obligations or our annual net periodic benefit cost as the change in the service and interest costs is completely offset in the actuarial (gain) loss reported. We have accounted for this change as a change in accounting estimate that is inseparable from a change in accounting principle and accordingly have accounted for it prospectively.
  Pension Benefits 
Post-Retirement
Medical Plan
Amortization of prior service costs $(86) $(646)
Amortization of net actuarial (loss) gain (180) 135
Total $(266) $(511)

The weighted average assumptions used to determine the benefit obligations as of December 31, 20152018 and 20142017 were as follows:
 Qualified Plan Supplemental Plan Post-Retirement Medical Plan Qualified Plan Supplemental Plan Post-Retirement Medical Plan
 2015 2014 2015 2014 2015 2014 2018 2017 2018 2017 2018 2017
Discount rate - Benefit obligations 4.17% 3.70% 4.22% 3.70% 3.76% 3.70%
Discount rate - benefit obligations 4.22% 3.58% 4.17% 3.55% 3.99% 3.33%
Rate of compensation increase 4.81% 4.96% 5.50% 4.96% % % 4.55% 4.53% 5.00% 5.00% 
 
The weighted average assumptions used to determine the net periodic benefit costs for the years ended December 31, 2015, 20142018, 2017 and 20132016 were as follows:
 
  Qualified Plan Supplemental Plan Post-Retirement Medical Plan
  2018 2017 2016 2018 2017 2016 2018 2017 2016
Discount rates:                  
Effective rate for service cost 3.62% 4.15% 4.15% 3.58% 4.17% 4.17% 3.59% 4.10% 4.10%
Effective rate for interest cost 3.21% 3.38% 3.38% 3.15% 3.20% 3.20% 2.97% 3.11% 3.11%
Effective rate for interest on service cost 3.32% 3.59% 3.59% 3.24% 3.63% 3.63% 3.46% 3.84% 3.84%
Expected long-term rate of return on plan assets 6.25% 6.50% 7.00% N/A N/A N/A N/A N/A N/A
Rate of compensation increase 4.53% 4.81% 4.81% 5.00% 5.50% 5.50% N/A N/A N/A

F- 4350

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

  Qualified Plan Supplemental Plan Post-Retirement Medical Plan
  2015 2014 2013 2015 2014 2013 2015 2014 2013
Discount rate:                  
Service Cost 4.25% 4.55% 3.45% 4.30% 4.55% 3.45% 4.32% 4.55% 3.45%
Effective rate for interest cost 3.31% 4.55% 3.45% 3.16% 4.55% 3.45% 3.09% 4.55% 3.45%
Effective rate for interest on service cost 3.51% 4.55% 3.45% 3.37% 4.55% 3.45% 4.04% 4.55% 3.45%
Expected long-term rate of return on plan assets 7.00% 6.70% 3.50% % % % % % %
Rate of compensation increase 4.81% 4.64% 4.00% 5.50% 4.64% 4.00% % % %
The assumed health care cost trend rates as of December 31, 20152018 and 20142017 were as follows:
 
Post-Retirement
Medical Plan
 
Post-Retirement
Medical Plan
 2015 2014 2018 2017
Health care cost trend rate assumed for next year 6.1% 6.7% 5.8% 6.0%
Rate to which the cost trend rate was assumed to decline (the ultimate trend rate) 4.5% 4.5% 4.5% 4.5%
Year that the rate reached the ultimate trend rate 2038
 2027
Year that the rate reaches the ultimate trend rate 2038
 2038

Assumed health care costscost trend rates have a significant effect on the amounts reported for retiree health care plans. A one percentage-point change in assumed health care costscost trend rates would have the following effects on the medical post-retirement benefits:
 
1%
Increase
 
1%
Decrease
 
1%
Increase
 
1%
Decrease
Effect on total of service and interest cost components $21
 $(20)
Effect on total service and interest cost components $11
 $(10)
Effect on accumulated post-retirement benefit obligation 413
 (388) 237
 (226)
The tablestable below presentpresents the fair values of the assets of the Company’s Qualified Plan as of December 31, 20152018 and 20142017 by level of fair value hierarchy. Assets categorized in Level 12 of the hierarchy consist of collective trusts and are measured at fair value using a market approach based on publishedthe closing net asset values of mutual funds.value (“NAV”) as determined by the fund manager and reported daily. As noted above, the Company’s post retirementpost-retirement medical plan is funded on a pay-as-you-go basis and has no assets.
 
Fair Value Measurements Using
Quoted Prices in Active Markets
(Level 1)
 
Fair Value Measurements Using
NAV as Practical Expedient
(Level 2)
 December 31, December 31,
 2015 2014 2018 2017
Equities:        
Domestic equities $17,660
 $12,682
 $34,800
 $36,582
Developed international equities 8,320
 5,600
 19,201
 17,236
Emerging market equities 4,017
 2,629
 10,263
 8,474
Global low volatility equities 4,930
 3,478
 11,437
 9,983
Fixed-income 22,495
 16,517
 59,680
 45,469
Real Estate 7,905
 
Cash and cash equivalents 80
 50
 85
 3,908
Total $57,502
 $40,956
 $143,371
 $121,652

F- 44

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

The Company’s investment strategy for its Qualified Plan is to achieve a reasonable return on assets that supports the plan’s interest credit rating, subject to a moderate level of portfolio risk that provides liquidity. Consistent with these financial objectives as of December 31, 2015,2018, the plan'splan’s target allocations for plan assets are 60%54% invested in equity securities, and 40% fixed income investments.investments and 6% in real estate. Equity securities include international stocks and a blend of U.S. growth and value stocks of various sizes of capitalization. Fixed income securities include bonds and notes issued by the U.S. government and its agencies, corporate bonds, and mortgage-backed securities. The aggregate asset allocation is reviewed on an annual basis.
The overall expected long-term rate of return on plan assets for the Qualified Plan is based on the Company’s view of long-term expectations and asset mix.

17.
F- 51

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

15. REVENUES
Adoption of ASC 606, “Revenue from Contracts with Customers”
Prior to January 1, 2018, the Company recognized revenue from customers when all of the following criteria were met: (i) persuasive evidence of an exchange arrangement existed, (ii) delivery had occurred or services had been rendered, (iii) the buyer’s price was fixed or determinable and (iv) collectability was reasonably assured. Amounts billed in advance of the period in which the service was rendered or product delivered were recorded as deferred revenue.
Effective January 1, 2018, the Company adopted ASC 606. As a result, the Company has changed its accounting policy for the recognition of revenue from contracts with customers as detailed below.
The Company adopted ASC 606 using the modified retrospective method, which has been applied for the year ended December 31, 2018. The Company has applied ASC 606 only to those contracts that were not complete as of January 1, 2018. As such, the financial information for prior periods has not been adjusted and continues to be reported under ASC 605. The Company did not record a cumulative effect adjustment upon initially applying ASC 606 as there was not a significant impact upon adoption; however, the details of significant qualitative and quantitative disclosure changes upon implementing ASC 606 are detailed below.
Revenue Recognition
Revenues are recognized when control of the promised goods or services is transferred to our customers, in an amount that reflects the consideration we expect to be entitled to in exchange for those goods or services.
The following table provides information relating to the Company’s revenues from external customers for each product or group of similar products for the periods:periods presented:
 Year Ended December 31, Year Ended December 31,
 2015 2014 2013 2018 2017 2016
Gasoline and distillates $11,553,716
 $17,050,096
 $16,973,239
 $23,032,567
 $18,316,079
 $14,017,350
Feedstocks and other 1,374,272
 1,218,468
 376,471
Asphalt and blackoils 1,592,936
 1,162,339
 699,966
Chemicals 452,304
 739,096
 746,396
 842,768
 770,491
 554,392
Asphalt and blackoils 536,496
 706,494
 690,305
Lubricants 266,371
 410,466
 468,315
 321,465
 305,101
 260,358
Feedstocks and other 315,042
 922,003
 273,200
 $13,123,929
 $19,828,155
 $19,151,455
Total Revenues $27,164,008
 $21,772,478
 $15,908,537
The majority of the Company’s revenues are generated from the sale of refined petroleum products. These revenues are largely based on the current spot (market) prices of the products sold, which represent consideration specifically allocable to the products being sold on a given day, and the Company recognizes those revenues upon delivery and transfer of title to the products to our customers. The time at which delivery and transfer of title occurs is the point when the Company’s control of the products is transferred to the Company’s customers and when its performance obligation to its customers is fulfilled. Delivery and transfer of title are specifically agreed to between the Company and customers within the contracts. The Company also has contracts which contain fixed pricing, tiered pricing, minimum volume features with makeup periods, or other factors that have not materially been affected by ASC 606.
Deferred Revenues
The Company records deferred revenues when cash payments are received or are due in advance of performance, including amounts which are refundable. Deferred revenue was $17,126 and $7,495 as of December 31, 2018 and December 31, 2017, respectively. Fluctuations in the deferred revenue balance are primarily driven by the timing and extent of cash payments received or due in advance of satisfying the Company’s performance obligations.

F- 52

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

The Company’s payment terms vary by type and location of customers and the products offered. The period between invoicing and when payment is due is not significant (i.e. generally within two months). For certain products or services and customer types, the Company requires payment before the products or services are delivered to the customer.
Significant Judgment and Practical Expedients
For performance obligations related to sales of products, the Company has determined that customers are able to direct the use of, and obtain substantially all of the benefits from, the products at the point in time that the products are delivered. The Company has determined that the transfer of control upon delivery to the customer’s requested destination accurately depicts the transfer of goods. Upon the delivery of the products and transfer of control, the Company generally has the present right to payment and the customers bear the risks and rewards of ownership of the products. The Company has elected the practical expedient to not disclose the value of unsatisfied performance obligations for (i) contracts with an original expected length of one year or less and (ii) contracts for which the Company recognizes revenue at the amount to which it has the right to invoice for services performed.

18.16. 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 provisionexpense for federal or state income tax in the PBF Holding financial statements apart from the income tax attributable to two subsidiaries acquired in connection with the acquisition of Chalmette Refining and PBF Ltd that are treated as C-Corporations for income tax purposes. These two
The reported income tax expense (benefit) in the PBF Holding consolidated statements of operations consists of the following:
 December 31, 2018 December 31, 2017 December 31, 2016
Current income tax expense$766
 $1,743
 $3,887
Deferred income tax expense (benefit)7,233
 (12,526) 19,802
Total income tax expense (benefit)$7,999
 $(10,783) $23,689
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.

F- 53

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

A summary of the components of PBF Holding’s deferred tax assets and deferred tax liabilities consists of the following:
 December 31, 2018 December 31, 2017
Deferred tax assets   
Other$1,107
 $348
Total deferred tax assets1,107
 348
Valuation allowances
 
Total deferred tax assets, net1,107
 348
    
Deferred tax liabilities   
Property, plant and equipment15,786
 15,796
Inventory25,686
 17,707
Total deferred tax liabilities41,472
 33,503
Net deferred tax liability$(40,365) $(33,155)

Tax Cuts and Jobs Act
On December 22, 2017, the U.S. government enacted comprehensive tax legislation commonly referred to as the TCJA. The TCJA makes broad and complex changes to the U.S. tax code, including, but not limited to, (1) reducing the U.S. federal corporate tax rate from 35 percent to 21 percent; (2) requiring companies to pay a one-time transition tax on certain unrepatriated earnings of foreign subsidiaries incurred $648 of(the “Transition Tax”); (3) generally eliminating U.S. federal income taxes foron dividends from foreign subsidiaries; (4) requiring a current inclusion in U.S. federal taxable income of certain earnings of controlled foreign corporations; (5) eliminating the period from their acquisitioncorporate alternative minimum tax (“AMT”) and changing how existing AMT credits can be realized; (6) creating the base erosion anti-abuse tax (“BEAT”), a new minimum tax; (7) creating a new limitation on November 1, 2015 throughdeductible interest expense; and (8) changing rules related to uses and limitations of net operating loss carryforwards created in tax years beginning after December 31, 2015.2017.
In connection with the enactment of the TCJA, PBF Energy recognized the measurement of the tax effects related to the TCJA noting that the recognized amounts pertaining to the PBF Holding subsidiaries noted above were not material.

F- 54

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

19.17. FAIR VALUE MEASUREMENTS
The tables below present information about the Company'sCompany’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, 20152018 and 20142017.
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 consolidated balance sheet.

 As of December 31, 2018
 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$2,784
 $
 $
 $2,784
 N/A
 $2,784
Commodity contracts1,230
 8,872
 
 10,102
 (2,895) 7,207
Derivatives included with inventory intermediation agreement obligations
 24,069
 
 24,069
 
 24,069
Liabilities:           
Commodity contracts2,685
 210
 
 2,895
 (2,895) 
Catalyst lease obligations
 44,353
 
 44,353
 
 44,353

 As of December 31, 2017
 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$4,730
 $
 $
 $4,730
 N/A
 $4,730
Commodity contracts10,031
 357
 
 10,388
 (10,388) 
Liabilities:          
Commodity contracts51,673
 33,035
 
 84,708
 (10,388) 74,320
Catalyst lease obligations
 59,048
 
 59,048
 
 59,048
Derivatives included with inventory intermediation agreement obligations
 7,721
 
 7,721
 
 7,721


F- 4555

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

 As of December 31, 2015
 Fair Value Hierarchy     
 Level 1 Level 2 Level 3Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet
Assets:          
Money market funds$631,280
 $
 $
$631,280
 N/A
 $631,280
Non-qualified pension plan assets9,325
 
 
9,325
 N/A
 9,325
Commodity contracts63,810
 31,256
 3,543
98,609
 (52,482) 46,127
Derivatives included with inventory supply arrangement obligations
 35,511
 
35,511
 
 35,511
Liabilities:          
Commodity contracts49,960
 2,522
 
52,482
 (52,482) 
Catalyst lease obligations
 31,802
 
31,802
 
 31,802

 As of December 31, 2014    
 Level 1 Level 2 Level 3Total Gross Fair Value Effect of Counter-party Netting Net Carrying Value on Balance Sheet
Assets:          
Money market funds$5,575
 $
 $
$5,575
 N/A $5,575
Non-qualified pension plan assets5,494
 
 
5,494
 N/A 5,494
Commodity contracts415,023
 12,093
 1,715
428,831
 (397,676) 31,155
Derivatives included with inventory intermediation arrangement
 94,834
 
94,834
 
 94,834
Derivatives included with inventory supply arrangement obligations
 4,251
 
4,251
 
 4,251
Liabilities:         
Commodity contracts390,144
 7,338
 194
397,676
 (397,676) 
Catalyst lease obligations
 36,559
 
36,559
 
 36,559


F- 46

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

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 cashCash and cash equivalents.
Non-qualified pension plan assets categorized in Level 1 of the hierarchy are measured at fair value using a market approach based on published net asset values of mutual funds and included within deferred charges and other assets, net.
The commodity contracts categorized in Level 1 of the fair value hierarchy are measured at fair value based on quoted prices in an active market. The commodity contracts categorized in Level 2 of the fair value hierarchy are measured at fair value using a market approach based upon future commodity prices for similar instruments quoted in active markets.
The commodity contracts categorized in Level 3 of the fair value hierarchy consist of commodity price swap contracts that relate to forecasted purchases of crude oil for which quoted forward market prices are not readily available due to market illiquidity. The forward priceprices used to value these swaps waswere derived using broker quotes, prices from other third partythird-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, 2018 and 2017, $9,694 and $9,593, 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,Year Ended December 31,
2015 20142018 2017
Balance at beginning of period$1,521
 $(23,365)$
 $(84)
Purchases
 

 
Settlements(15,222) (22,055)
 45
Unrealized loss included in earnings17,244
 46,941
Unrealized gain included in earnings
 39
Transfers into Level 3
 

 
Transfers out of Level 3
 

 
Balance at end of period$3,543
 $1,521
$
 $

There were no transfers between levels during the years ended December 31, 20152018 and 2014,2017, respectively.

F- 4756

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

Fair value of debt
The table below summarizes the fair value and carrying value of debt as of December 31, 20152018 and 2014.2017.

 December 31, 2015 December 31, 2014
 
Carrying
value
 
Fair
 value
 
Carrying
 value
 
Fair
value
Senior Secured Notes due 2020 (a)$669,644
 $706,246
 $668,520
 $675,580
Senior Secured Notes due 2023 (a)500,000
 492,452
 
 
Revolving Loan (b)
 
 
 
Rail Facility (b)67,491
 67,491
 37,270
 37,270
Catalyst leases (c)31,802
 31,802
 36,559
 36,559
 1,268,937
 1,297,991
 742,349
 749,409
Less - Current maturities
 
 
 
Less - Unamortized deferred financing costs$32,217
 n/a
 $30,128
 n/a
Long-term debt$1,236,720
 $1,297,991
 $712,221
 $749,409
 December 31, 2018 December 31, 2017
 
Carrying
value
 
Fair
 value
 
Carrying
 value
 
Fair
value
2025 Senior Notes (a)
$725,000
 $688,420
 $725,000
 $763,945
2023 Senior Notes (a) (d)
500,000
 479,387
 500,000
 522,101
Revolving Credit Facility (b)

 
 350,000
 350,000
PBF Rail Term Loan (b)
21,554
 21,554
 28,366
 28,366
Catalyst leases (c)
44,353
 44,353
 59,048
 59,048
 1,290,907
 1,233,714
 1,662,414
 1,723,460
Less - Current debt (c)
(2,378) (2,378) (10,987) (10,987)
Less - Unamortized deferred financing costs(30,537) n/a
 (25,178) n/a
Long-term debt$1,257,992
 $1,231,336
 $1,626,249
 $1,712,473

(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'sCompany’s liability is directly impacted by the change in fair value of the underlying catalyst. During 2017 Delaware City Refining entered into two platinum bridge leases which were settled during the second quarter of 2018. During 2018 Delaware City Refining, Toledo Refining and Chalmette Refining entered into three new platinum bridge leases which will expire in 2019. The bridge leases are payable at maturity and are not anticipated to be renewed. The total outstanding balance related to these bridge leases as of December 31, 2018 was $2,378 and is included in Current debt in the Company’s consolidated balance sheet.

(d) As discussed in “Note 8 - Credit Facility and Debt”, these notes became unsecured following the Collateral Fall-Away Event on May 30, 2017.

20.18. DERIVATIVES

The Company uses derivative instruments to mitigate certain exposures to commodity price risk. The Company’s crude supply agreements contained purchase obligations for certain volumes of crude oil and other feedstocks. In addition, the Company entered into the 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 oilintermediates and refined products. The level of activity for these derivatives is based on the level of operating inventories.

As of December 31, 2015,2018, there were no3,350,166 barrels of crude oilintermediates and feedstocks (662,579refined products (3,000,142 barrels at December 31, 2014)2017) outstanding under these derivative instruments designated as fair value hedges and no barrels (no barrels at December 31, 2014) outstanding under these derivative instruments not designated as hedges. As of December 31, 2015, there were 3,776,011 barrels of intermediates and refined products (3,106,325 barrels at December 31, 2014) outstanding under these derivative instruments designated as fair value hedges and no barrels (no barrels at December 31, 2014) outstanding under these derivative instruments not designated as hedges. These volumes represent the notional value of the contract.


F- 57

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

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

F- 48

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

well as crude oil, feedstock, and refined product sales or purchases. The objective in entering into economic hedges is consistent with the objectives discussed above for fair value hedges. As of December 31, 2015,2018, there were 39,577,0005,801,000 barrels of crude oil and 4,599,1361,609,000 barrels of refined products (47,339,00022,348,000 and 1,970,8711,989,000, respectively, as of December 31, 20142017), 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, 20152018 and December 31, 20142017 and the line items in the consolidated balance sheet in which the fair values are reflected.
Description

Balance Sheet Location
Fair Value
Asset/(Liability)

Balance Sheet Location
Fair Value
Asset/(Liability)
Derivatives designated as hedging instruments:    
December 31, 2015:  
Derivatives included with inventory supply arrangement obligationsAccrued expenses$
December 31, 2018:  
Derivatives included with the inventory intermediation agreement obligationsAccrued expenses$35,511
Accrued expenses$24,069
December 31, 2014:  
Derivatives included with inventory supply arrangement obligationsAccrued expenses$4,251
December 31, 2017:  
Derivatives included with the inventory intermediation agreement obligationsAccrued expenses$94,834
Accrued expenses$(7,721)
    
Derivatives not designated as hedging instruments:    
December 31, 2015:  
December 31, 2018:  
Commodity contractsAccounts receivable$46,127
Accounts receivable$7,207
December 31, 2014:  
December 31, 2017:  
Commodity contractsAccounts receivable$31,155
Accrued expenses$(74,320)


F- 58

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

The following tables providetable provides information about the gains or losses recognized in income on these derivative instruments and the line items in the consolidated financial statements of operations in which such gains and losses are reflected.

F- 49

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, PER SHARE, PER UNIT AND BARREL DATA)

Description
Location of Gain or (Loss) Recognized in
 Income on Derivatives
Gain or (Loss)
Recognized in
Income on Derivatives
Derivatives designated as hedging instruments:  
For the year ended December 31, 2015:  
Derivatives included with inventory supply arrangement obligationsCost of sales$(4,251)
Derivatives included with the inventory intermediation agreement obligationsCost of sales$(59,323)
For the year ended December 31, 2014:  
Derivatives included with inventory supply arrangement obligationsCost of sales$4,428
Derivatives included with the inventory intermediation agreement obligationsCost of sales$88,818
For the year ended December 31, 2013  
Derivatives included with inventory supply arrangement obligationsCost of sales$(5,773)
Derivatives included with the inventory intermediation agreement obligationsCost of sales$6,016
Derivatives not designated as hedging instruments:  
For the year ended December 31, 2015:  
Commodity contractsCost of sales$32,416
For the year ended December 31, 2014:  
Commodity contractsCost of sales$146,016
For the year ended December 31, 2013  
Commodity contractsCost of sales$(88,962)
   
Hedged items designated in fair value hedges:  
For the year ended December 31, 2015:  
Crude oil and feedstock inventoryCost of sales$4,251
Intermediate and refined product inventoryCost of sales$59,323
For the year ended December 31, 2014:  
Crude oil and feedstock inventoryCost of sales$(4,428)
Intermediate and refined product inventoryCost of sales$(88,818)
For the year ended December 31, 2013  
Crude oil and feedstock inventoryCost of sales$(1,491)
Intermediate and refined product inventoryCost of sales$(6,016)
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, 2018:  
Derivatives included with the inventory intermediation agreement obligationsCost of products and other$31,790
For the year ended December 31, 2017:  
Derivatives included with the inventory intermediation agreement obligationsCost of products and other$(13,779)
For the year ended December 31, 2016  
Derivatives included with the inventory intermediation agreement obligationsCost of products and other$(29,453)
   
Derivatives not designated as hedging instruments:  
For the year ended December 31, 2018:  
Commodity contractsCost of products and other$(123,770)
For the year ended December 31, 2017:  
Commodity contractsCost of products and other$(85,443)
For the year ended December 31, 2016  
Commodity contractsCost of products and other$(55,557)
   
Hedged items designated in fair value hedges:  
For the year ended December 31, 2018:  
Intermediate and refined product inventoryCost of products and other$(31,790)
For the year ended December 31, 2017:  
Intermediate and refined product inventoryCost of products and other$13,779
For the year ended December 31, 2016  
Intermediate and refined product inventoryCost of products and other$29,453

The Company had no ineffectiveness related to the fair value hedges as of December 31, 20152018, 2017 and 2014. Ineffectiveness related to the Company's fair value hedges resulted in a loss of $7,264 for the year ended December 31 2013, recorded in cost of sales. Gains and losses due to ineffectiveness, resulting from the difference in the forward and spot rates of the underlying crude inventory related to the derivatives included with inventory supply arrangement obligations, were excluded from the assessment of hedge effectiveness.2016.



F- 5059

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

21.19. SUBSEQUENT EVENTS
Dividend Declared
On February 11, 2016,14, 2019, PBF Energy, PBF Holding'sHolding’s indirect parent, announced a dividend of $0.30 per share on outstanding Class A common stock. The dividend was paidis payable on March 8, 201614, 2019 to Class A common stockholders of record atas of February 28, 2019.
Rail Agreement Amendments

On February 13, 2019, the close of business on February 22, 2016.Company amended the existing Amended and Restated Delaware City Rail Terminaling Services Agreement between Delaware City Terminaling Company LLC and PBF Holding madefor the inclusion of services through certain rail infrastructure at PBFX’s recently acquired East Coast Storage Assets (the “East Coast Rail Assets”). The Company also entered into a distributionnew Terminaling Services Agreement, between Delaware City Terminaling Company and PBF Holding, with a four year term starting in 2022, subsequent to the expiration of $30,829the Amended and Restated Delaware City Rail Terminaling Services Agreement, related to the DCR Rail Facilities and the East Coast Rail Assets, which will reduce the MVC to 95,000 bpd and includes additional services to be provided by PBFX as operator of facilities owned by PBF LLC, which in turn made pro-rata distributions to its members, including PBF Energy. PBF Energy then used this distribution to fund the dividend payments to shareholders of PBF Energy.Holding’s subsidiaries.




F- 5160

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

22.20. 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 Energy Western Region LLC, Torrance Refining Company LLC, Torrance Logistics Company LLC, PBF International Inc. 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 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, and T&M Terminal Company, 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 SecuredNotes. 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 Secured Notes were co-issued by PBF Finance. For purposes of the following footnote, PBF Finance is referred to as “Co-Issuer.” The Co-Issuer has no independent assets or operations.

The following supplemental combining and consolidating financial information reflects the Issuer’s separate accounts, the combined accounts of the Guarantor Subsidiaries 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 investmentsinvestment in its subsidiaries and the Guarantor Subsidiaries’subsidiaries’ investments in itstheir subsidiaries are accounted for under the equity method of accounting.

F- 5261

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

22.20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING

CONSOLIDATING BALANCE SHEETSHEETS
December 31, 2015December 31, 2018
Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments TotalIssuer 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
$526,038
 $9,079
 $26,574
 $
 $561,691
Accounts receivable430,809
 11,057
 12,893
 
 454,759
690,097
 7,255
 13,343
 
 710,695
Accounts receivable - affiliate917
 2,521
 
 
 3,438
1,771
 9,543
 733
 
 12,047
Inventories608,646
 363,151
 202,475
 
 1,174,272
1,685,322
 
 178,734
 
 1,864,056
Prepaid expense and other current assets24,243
 9,074
 384
 
 33,701
Prepaid and other current assets20,654
 30,003
 1,783
 
 52,440
Due from related parties20,236,649
 20,547,503
 3,262,382
 (44,046,534) 
33,793,126
 25,057,250
 9,534,212
 (68,384,588) 
Total current assets22,184,084
 20,939,542
 3,507,102
 (44,049,809) 2,580,919
36,717,008
 25,113,130
 9,755,379
 (68,384,588) 3,200,929
                  
Property, plant and equipment, net25,240
 1,960,066
 225,784
 
 2,211,090
17,323
 2,722,679
 231,225
 
 2,971,227
Investment in subsidiaries1,740,111
 143,349
 
 (1,883,460) 

 421,438
 
 (421,438) 
Investment in equity method investee
 
 169,472
 
 169,472
Deferred charges and other assets, net23,973
 265,240
 1,500
 
 290,713
16,117
 855,697
 34
 
 871,848
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
$36,750,448
 $29,112,944
 $10,156,110
 $(68,806,026) $7,213,476
                  
LIABILITIES AND EQUITY                  
Current liabilities:                  
Accounts payable$196,988
 $113,564
 $7,566
 $(3,275) $314,843
$278,206
 $189,671
 $15,888
 $
 $483,765
Accounts payable - affiliate23,949
 
 
 
 23,949
34,251
 14,764
 489
 
 49,504
Accrued expenses503,179
 495,842
 118,414
 
 1,117,435
1,364,005
 156,147
 58,886
 
 1,579,038
Current portion of long-term debt
 
 
 
 
Current debt
 2,378
 
 
 2,378
Deferred revenue4,043
 
 
 
 4,043
15,599
 1,522
 5
 
 17,126
Due to related parties19,787,807
 21,026,310
 3,232,417
 (44,046,534) 
28,340,713
 30,433,385
 9,610,490
 (68,384,588) 
Total current liabilities20,515,966
 21,635,716
 3,358,397
 (44,049,809) 1,460,270
30,032,774
 30,797,867
 9,685,758
 (68,384,588) 2,131,811
                  
Delaware Economic Development Authority loan
 4,000
 
 
 4,000
Long-term debt1,137,980
 31,717
 67,023
 
 1,236,720
1,194,721
 41,975
 21,296
 
 1,257,992
Intercompany notes payable470,047
 
 
 
 470,047
Deferred tax liability
 
 20,577
 
 20,577
Deferred tax liabilities
 
 40,365
 
 40,365
Other long-term liabilities28,131
 41,693
 
 
 69,824
54,921
 194,535
 4,145
 
 253,601
Due to related party - long term
 20,577
 
 (20,577) 
Investment in subsidiaries1,938,325
 
 
 (1,938,325) 
Total liabilities22,152,124
 21,733,703
 3,445,997
 (44,070,386) 3,261,438
33,220,741
 31,034,377
 9,751,564
 (70,322,913) 3,683,769
                  
Commitments and contingencies
 
 
 
 

 
 
 
 
                  
Equity:                  
Member's equity1,479,175
 1,062,717
 182,696
 (1,245,413) 1,479,175
PBF Holding Company LLC equity         
Member’s equity2,652,424
 1,737,232
 323,690
 (2,060,922) 2,652,424
Retained earnings349,654
 502,788
 126,270
 (629,058) 349,654
890,376
 (3,662,009) 80,856
 3,581,153
 890,376
Accumulated other comprehensive loss(24,770) (8,236) 
 8,236
 (24,770)(23,945) (7,508) 
 7,508
 (23,945)
Total PBF Holding Company LLC equity1,804,059
 1,557,269
 308,966
 (1,866,235) 1,804,059
3,518,855
 (1,932,285) 404,546
 1,527,739
 3,518,855
Noncontrolling interest17,225
 17,225
 
 (17,225) $17,225
10,852
 10,852
 
 (10,852) 10,852
Total equity1,821,284
 1,574,494
 308,966
 (1,883,460) 1,821,284
3,529,707
 (1,921,433) 404,546
 1,516,887
 3,529,707
Total liabilities and equity$23,973,408
 $23,308,197
 $3,754,963
 $(45,953,846) $5,082,722
$36,750,448
 $29,112,944
 $10,156,110
 $(68,806,026) $7,213,476

F- 5362

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

22.20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING BALANCE SHEETS
 December 31, 2017
 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total
ASSETS         
Current assets:         
Cash and cash equivalents$486,568
 $13,456
 $26,136
 $
 $526,160
Accounts receivable903,298
 7,605
 40,226
 
 951,129
Accounts receivable - affiliate2,321
 5,300
 731
 
 8,352
Inventories1,982,315
 
 231,482
 
 2,213,797
Prepaid and other current assets20,523
 27,100
 1,900
 
 49,523
Due from related parties28,632,914
 23,302,660
 6,820,693
 (58,756,267) 
Total current assets32,027,939
 23,356,121
 7,121,168
 (58,756,267) 3,748,961
          
Property, plant and equipment, net21,785
 2,547,229
 236,376
 
 2,805,390
Investment in subsidiaries
 413,136
 
 (413,136) 
Investment in equity method investee
 
 171,903
 
 171,903
Deferred charges and other assets, net30,141
 749,749
 34
 
 779,924
Total assets$32,079,865
 $27,066,235
 $7,529,481
 $(59,169,403) $7,506,178
          
LIABILITIES AND EQUITY         
Current liabilities:         
Accounts payable$413,829
 $137,149
 $21,954
 $
 $572,932
Accounts payable - affiliate39,952
 865
 
 
 40,817
Accrued expenses1,409,212
 122,722
 268,925
 
 1,800,859
Current debt
 10,987
 
 
 10,987
Deferred revenue6,005
 1,472
 18
 
 7,495
Note payable
 5,621
 
 
 5,621
Due to related parties24,813,299
 27,166,679
 6,776,289
 (58,756,267) 
Total current liabilities26,682,297
 27,445,495
 7,067,186
 (58,756,267) 2,438,711
          
Long-term debt1,550,206
 48,024
 28,019
 
 1,626,249
Deferred tax liabilities
 
 33,155
 
 33,155
Other long-term liabilities30,612
 189,204
 4,145
 
 223,961
Investment in subsidiaries632,648
 
 
 (632,648) 
Total liabilities28,895,763
 27,682,723
 7,132,505
 (59,388,915) 4,322,076
          
Commitments and contingencies
 
 
 
 
          
Equity:         
PBF Holding Company LLC equity         
Member’s equity2,359,791
 1,731,268
 343,940
 (2,075,208) 2,359,791
Retained earnings840,431
 (2,348,904) 53,036
 2,295,868
 840,431
Accumulated other comprehensive loss(26,928) (9,660) 
 9,660
 (26,928)
Total PBF Holding Company LLC equity3,173,294
 (627,296) 396,976
 230,320
 3,173,294
Noncontrolling interest10,808
 10,808
 
 (10,808) 10,808
Total equity3,184,102
 (616,488) 396,976
 219,512
 3,184,102
Total liabilities and equity$32,079,865
 $27,066,235
 $7,529,481
 $(59,169,403) $7,506,178

CONSOLIDATING BALANCE SHEET
 December 31, 2014
 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total
ASSETS         
Current assets:         
Cash and cash equivalents$185,381
 $704
 $34,334
 $(2,016) $218,403
Accounts receivable518,498
 26,238
 6,533
 
 551,269
Accounts receivable - affiliate529
 2,694
 
 
 3,223
Inventories510,947
 435,924
 155,390
 
 1,102,261
Prepaid expense and other current assets26,964
 5,193
 
 
 32,157
Due from related parties16,189,384
 18,805,509
 1,607,878
 (36,602,771) 
Total current assets17,431,703
 19,276,262
 1,804,135
 (36,604,787) 1,907,313
          
Property, plant and equipment, net68,218
 1,683,294
 54,548
 
 1,806,060
Investment in subsidiaries2,569,636
 
 
 (2,569,636) 
Deferred charges and other assets, net5,899
 292,990
 1,500
 
 300,389
Total assets$20,075,456
 $21,252,546
 $1,860,183
 $(39,174,423) $4,013,762
          
LIABILITIES AND EQUITY         
Current liabilities:         
Accounts payable$235,791
 $92,984
 $8,423
 $(2,016) $335,182
Accounts payable - affiliate11,600
 30
 
 
 11,630
Accrued expenses487,783
 450,856
 191,331
 
 1,129,970
Current portion of long-term debt
 
 
 
 
Deferred revenue1,227
 
 
 
 1,227
Due to related parties16,924,490
 18,151,095
 1,527,186
 (36,602,771) 
Total current liabilities17,660,891
 18,694,965
 1,726,940
 (36,604,787) 1,478,009
          
Delaware Economic Development Authority loan
 8,000
 
 
 8,000
Long-term debt639,579
 36,451
 36,191
 
 712,221
Intercompany notes payable122,264
 
 
 
 122,264
Other long-term liabilities22,206
 40,546
 
 
 62,752
Total liabilities18,444,940
 18,779,962
 1,763,131
 (36,604,787) 2,383,246
          
Commitments and contingencies
 
 
 
 
          
Equity:         
Member's equity1,144,100
 749,278
 44,346
 (793,624) 1,144,100
Retained earnings513,292
 1,731,694
 52,706
 (1,784,400) 513,292
Accumulated other comprehensive loss(26,876) (8,388) 
 8,388
 (26,876)
Total PBF Holding Company LLC equity1,630,516
 2,472,584
 97,052
 (2,569,636) 1,630,516
Noncontrolling interest
 
 
 
 
Total equity1,630,516
 2,472,584
 97,052
 (2,569,636) 1,630,516
Total liabilities and equity$20,075,456
 $21,252,546
 $1,860,183
 $(39,174,423) $4,013,762

F- 5463

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

22.20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING

CONSOLIDATING STATEMENTSTATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
Year Ended December 31, 2015Year Ended December 31, 2018
Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments TotalIssuer 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
$26,935,156
 $1,532,383
 $2,961,078
 $(4,264,609) $27,164,008
                  
Costs and expenses:         
Cost of sales, excluding depreciation11,514,115
 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 expenses143,580
 21,016
 2,308
 
 166,904
Gain on sale of asset(249) (105) (650) 
 (1,004)
Cost and expenses:         
Cost of products and other25,170,899
 940,247
 2,898,082
 (4,264,609) 24,744,619
Operating expenses (excluding depreciation and amortization expense as reflected below)54
 1,623,564
 31,131
 
 1,654,749
Depreciation and amortization expense9,687
 178,578
 2,845
 
 191,110

 322,015
 7,694
 
 329,709
11,663,450
 2,117,869
 1,556,599
 (2,479,941) 12,857,977
Cost of sales25,170,953
 2,885,826
 2,936,907
 (4,264,609) 26,729,077
General and administrative expenses (excluding depreciation and amortization expense as reflected below)222,976
 26,652
 4,206
 
 253,834
Depreciation and amortization expense10,634
 
 
 
 10,634
Equity income in investee
 
 (17,819) 
 (17,819)
(Gain) loss on sale of asset
 (43,118) 24
 
 (43,094)
Total cost and expenses25,404,563
 2,869,360
 2,923,318
 (4,264,609) 26,932,632
                  
Income (loss) from operations1,421,672
 (1,232,939) 77,219
 
 265,952
1,530,593
 (1,336,977) 37,760
 
 231,376
                  
Other income (expense):                  
Equity in earnings of subsidiaries(1,154,420) 
 
 1,154,420
 
(1,302,931) 28,696
 
 1,274,235
 
Change in fair value of catalyst lease
 10,184
 
 
 10,184
Change in fair value of catalyst leases
 5,587
 
 
 5,587
Interest expense, net(79,310) (5,876) (3,008) 
 (88,194)(124,339) (1,725) (1,065) 
 (127,129)
Other non-service components of net periodic benefit cost(379) 1,488
 
 
 1,109
Income (loss) before income taxes187,942
 (1,228,631) 74,211
 1,154,420
 187,942
102,944
 (1,302,931) 36,695
 1,274,235
 110,943
Income tax expense (benefit)
 
 648
 

648
Income tax expense
 
 7,999
 

7,999
Net income (loss)187,942
 (1,228,631) 73,563
 1,154,420
 187,294
102,944
 (1,302,931) 28,696
 1,274,235
 102,944
Less net income attributable to noncontrolling interests274
 274
 
 (274) 274
Less: net income attributable to noncontrolling interests44
 44
 
 (44) 44
Net income (loss) attributable to PBF Holding Company LLC$187,668
 $(1,228,905) $73,563
 $1,154,694
 $187,020
$102,900
 $(1,302,975) $28,696
 $1,274,279
 $102,900
                  
Comprehensive income (loss) attributable to PBF Holding Company LLC$189,774
 $(1,228,905) $73,563
 $1,154,694
 $189,126
$105,883
 $(1,302,975) $28,696
 $1,274,279
 $105,883


F- 5564

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

22.20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING

CONSOLIDATING STATEMENTSTATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
 Year Ended December 31, 2014
 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total
          
Revenues$19,847,045
 $1,402,253
 $1,007,407
 $(2,428,550) $19,828,155
          
Costs and expenses:         
Cost of sales, excluding depreciation18,467,533
 1,522,901
 952,170
 (2,428,550) 18,514,054
Operating expenses, excluding depreciation218
 880,339
 144
 
 880,701
General and administrative expenses123,692
 16,259
 199
 
 140,150
(Gain) loss on sale of asset(277) 
 (618) 
 (895)
Depreciation and amortization expense13,583
 164,525
 888
 
 178,996
 18,604,749
 2,584,024
 952,783
 (2,428,550) 19,713,006
          
Income (loss) from operations1,242,296
 (1,181,771) 54,624
 
 115,149
          
Other income (expense):         
Equity in earnings (loss) of subsidiaries(1,131,321) 
 
 1,131,321
 
Change in fair value of catalyst lease
 3,969
 
 
 3,969
Interest expense, net(89,858) (6,225) (1,918) 
 (98,001)
Income (loss) before income taxes21,117
 (1,184,027) 52,706
 1,131,321
 21,117
Income tax expense (benefit)
 
 
 
 
Net income (loss)21,117
 (1,184,027) 52,706
 1,131,321
 21,117
Less net income attributable to noncontrolling interests
 
 
 
 
Net income (loss) attributable to PBF Holding Company LLC$21,117
 $(1,184,027) $52,706
 $1,131,321
 $21,117
          
Comprehensive income (loss) attributable to PBF Holding Company LLC$8,779
 $(1,194,031) $52,706
 $1,141,325
 $8,779
 Year Ended December 31, 2017
 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total
          
Revenues$21,489,767
 $1,488,687
 $2,376,654
 $(3,582,630) $21,772,478
          
Cost and expenses:         
Cost of products and other19,354,399
 962,929
 2,361,129
 (3,582,630) 19,095,827
Operating expenses (excluding depreciation and amortization expense as reflected below)(42) 1,594,937
 31,545
 
 1,626,440
Depreciation and amortization expense
 246,662
 7,609
 
 254,271
     Cost of sales19,354,357
 2,804,528
 2,400,283
 (3,582,630) 20,976,538
General and administrative expenses (excluding depreciation and amortization expense as reflected below)170,211
 28,258
 (531) 
 197,938
Depreciation and amortization expense12,964
 
 
 
 12,964
Equity income in investee
 
 (14,565) 
 (14,565)
Loss on sale of asset
 1,458
 
 
 1,458
Total cost and expenses19,537,532
 2,834,244
 2,385,187
 (3,582,630) 21,174,333
          
Income (loss) from operations1,952,235
 (1,345,557) (8,533) 
 598,145
          
Other income (expense)         
Equity in earnings of subsidiaries(1,349,208) 1,273
 
 1,347,935
 
Change in fair value of catalyst leases
 (2,247) 
 
 (2,247)
Debt extinguishment costs(25,451) 
 
 
 (25,451)
Interest expense, net(120,150) (1,501) (977) 
 (122,628)
Other non-service components of net periodic benefit cost(226) (1,176) 
 
 (1,402)
Income (loss) before income taxes457,200
 (1,349,208) (9,510) 1,347,935
 446,417
Income tax benefit
 
 (10,783) 
 (10,783)
Net income (loss)457,200
 (1,349,208) 1,273
 1,347,935
 457,200
Less: net income attributable to noncontrolling interests95
 95
 
 (95) 95
Net income (loss) attributable to PBF Holding Company LLC$457,105
 $(1,349,303) $1,273
 $1,348,030
 $457,105
          
Comprehensive income (loss) attributable to PBF Holding Company LLC$456,139
 $(1,349,303) $1,273
 $1,348,030
 $456,139

F- 5665

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

22.20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING

CONSOLIDATING STATEMENTSTATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
 Year Ended December 31, 2013
 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total
          
Revenues$16,190,178
 $7,641,498
 $
 $(4,680,221) $19,151,455
          
Costs and expenses:         
Cost of sales, excluding depreciation16,486,851
 5,996,684
 
 (4,680,221) 17,803,314
Operating expenses, excluding depreciation(482) 813,134
 
 
 812,652
General and administrative expenses82,284
 13,510
 
 
 95,794
Gain on sale of assets(388) 205
 
 
 (183)
Depreciation and amortization expense12,856
 98,623
 
 
 111,479
 16,581,121
 6,922,156
 
 (4,680,221) 18,823,056
          
(Loss) income from operations(390,943) 719,342
 
 
 328,399
          
Other income (expense):         
Equity in earnings (loss) of subsidiaries722,673
 
 
 (722,673) 
Change in fair value of contingent consideration
 
 
 
 
Change in fair value of catalyst lease
 4,691
 
 
 4,691
Interest expense, net(92,854) (1,360) 
 
 (94,214)
Income (loss) before income taxes238,876
 722,673
 
 (722,673) 238,876
Income tax expense (benefit)
 
 
 
 
Net income (loss)238,876
 722,673
 
 (722,673) 238,876
Less net income attributable to noncontrolling interests
 
 
 
 
Net income (loss) attributable to PBF Holding Company LLC$238,876
 $722,673
 $
 $(722,673) $238,876
          
Comprehensive income (loss) attributable to PBF Holding Company LLC$233,279
 $724,930
 $
 $(724,930) $233,279
 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
          
Cost and expenses         
Cost of products and other13,813,293
 649,242
 1,527,910
 (2,225,357) 13,765,088
Operating expenses (excluding depreciation and amortization expense as reflected below)41
 1,356,125
 33,969
 
 1,390,135
Depreciation and amortization expense
 194,702
 9,303
 
 204,005
     Cost of sales13,813,334
 2,200,069
 1,571,182
 (2,225,357) 15,359,228
General and administrative expenses (excluding depreciation and amortization expense as reflected below)123,017
 27,602
 (1,109) 
 149,510
Depreciation and amortization expense5,835
 
 
 
 5,835
Equity income in investee
 
 (5,679) 
 (5,679)
Loss on sale of assets2,392
 150
 8,832
 
 11,374
Total cost and expenses13,944,578
 2,227,821
 1,573,226
 (2,225,357) 15,520,268
          
Income (loss) from operations1,863,978
 (1,427,174) (48,535) 
 388,269
          
Other income (expense):         
Equity in earnings of subsidiaries(1,502,243) (74,507) 
 1,576,750
 
Change in fair value of catalyst leases
 1,422
 
 
 1,422
Interest expense, net(125,715) (1,538) (2,283) 
 (129,536)
Other non-service components of net periodic benefit cost(133) (447) 
 
 (580)
Income (loss) before income taxes235,887
 (1,502,244) (50,818) 1,576,750
 259,575
Income tax expense
 
 23,689
 
 23,689
Net income (loss)235,887
 (1,502,244) (74,507) 1,576,750
 235,886
Less: net income attributable to noncontrolling interests269
 269
 
 (269) 269
Net income (loss) attributable to PBF Holding Company LLC$235,618
 $(1,502,513) $(74,507) $1,577,019
 $235,617
          
Comprehensive income (loss) attributable to PBF Holding Company LLC$233,026
 $(1,502,513) $(74,507) $1,577,019
 $233,025


F- 5766

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

22.20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING

CONSOLIDATING STATEMENTSTATEMENTS OF CASH FLOWFLOWS
Year Ended December 31, 2015Year Ended December 31, 2018
Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments TotalIssuer 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
$102,944
 $(1,302,931) $28,696
 $1,274,235
 $102,944
Adjustments to reconcile net income to net cash provided by operating activities:         
Adjustments to reconcile net income (loss) to net cash provided by operating activities:         
Depreciation and amortization17,063
 178,601
 3,719
 
 199,383
16,852
 322,051
 7,784
 
 346,687
Stock-based compensation
 9,218
 
 
 9,218
173
 20,039
 
 
 20,212
Change in fair value of catalyst lease obligation
 (10,184) 
 
 (10,184)
Change in fair value of catalyst leases
 (5,587) 
 
 (5,587)
Deferred income taxes
 
 7,233
 
 7,233
Non-cash change in inventory repurchase obligations
 63,389
 
 
 63,389
(31,790) 
 
 
 (31,790)
Non-cash lower of cost or market inventory adjustment279,785
 147,441
 
 
 427,226
351,278
 
 
 
 351,278
Pension and other post retirement benefit costs7,576
 19,406
 
 
 26,982
Gain on disposition of property, plant and equipment(249) (105) (650) 
 (1,004)
Equity in earnings of subsidiaries1,154,420
 
 
 (1,154,420) 
Changes in current assets and current liabilities:         
Pension and other post-retirement benefit costs7,771
 39,610
 
 
 47,381
Income from equity method investee
 
 (17,819) 
 (17,819)
Distributions from equity method investee
 
 17,819
 
 17,819
Gain on sale of assets
 (43,094) 
 
 (43,094)
Equity in earnings (loss) of subsidiaries1,302,931
 (28,696) 
 (1,274,235) 
Changes in operating assets and liabilities:         
Accounts receivable87,689
 16,124
 (6,177) 
 97,636
213,200
 350
 26,883
 
 240,433
Amounts due to/from related parties(1,018,176) 1,133,364
 (103,084) 
 12,104
Due to/from affiliates(1,608,556) 1,483,875
 121,169
 
 (3,512)
Inventories(108,751) (116,074) (47,067) 
 (271,892)(54,285) 
 52,748
 
 (1,537)
Other current assets2,721
 (2,999) (353) 
 (631)
Prepaid and other current assets(129) (2,905) 117
 
 (2,917)
Accounts payable(38,609) 15,710
 (857) (1,259) (25,015)(135,623) 30,974
 (6,066) 
 (110,715)
Accrued expenses27,925
 8,172
 (73,834) 
 (37,737)(43,147) 20,563
 (210,411) 
 (232,995)
Deferred revenue2,816
 
 
 
 2,816
9,594
 50
 (13) 
 9,631
Other assets and liabilities(423) (26,769) 10
 
 (27,182)32,685
 (10,217) (21,149) 
 1,319
Net cash provided by (used in) operating activities601,729
 206,663
 (154,730) (1,259) 652,403
Net cash provided by operating activities$163,898
 $524,082
 $6,991
 $
 $694,971
                  
Cash flows from investing activities:                  
Acquisition of Chalemtte refinery, net of cash received from sale of assets(601,311) 19,042
 16,965
 
 (565,304)
Expenditures for property, plant and equipment(193,898) (158,361) (106) 
 (352,365)(6,172) (268,914) (2,172) 
 (277,258)
Expenditures for refinery turnarounds costs
 (53,576) 
 
 (53,576)
Expenditures for deferred turnaround costs
 (266,028) 
 
 (266,028)
Expenditures for other assets
 (8,236) 
 
 (8,236)
 (17,055) 
 
 (17,055)
Investment in subsidiaries10,000
 
 
 (10,000) 
Capital contributions to subsidiaries(5,000) 
 
 5,000
 
Proceeds from sale of assets60,902
 
 107,368
 
 168,270

 48,290
 
 
 48,290
Equity method investment - return of capital
 
 2,431
 
 2,431
Due to/from affiliates(31) 
 
 31
 
Net cash (used in) provided by investing activities(729,307) (201,131) 124,227
 (5,000) (811,211)$(6,203) $(503,707)
$259

$31

$(509,620)

F- 5867

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

22.20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENTSTATEMENTS OF CASH FLOWFLOWS (Continued)
Cash flows from financing activities:         
Proceeds from member's capital contributions345,000
 
 5,000
 (5,000) 345,000
Distribution to parent
 
 (10,000) 10,000
 
Distributions to members(350,658) 
 
 
 (350,658)
Proceeds from intercompany notes payable347,783
 
 
 
 347,783
Proceeds from revolver borrowings170,000
 
 
 
 170,000
Repayments of revolver borrowings(170,000) 
 
 
 (170,000)
Proceeds from Rail Facility revolver borrowings
 
 102,075
 
 102,075
Repayments of Rail Facility revolver borrowings
 
 (71,938) 
 (71,938)
Proceeds form Senior Secured Notes500,000
 
 
 
 500,000
Deferred financing costs and other(17,108) 
 
 
 (17,108)
Net cash provided by financing activities825,017
 
 25,137
 5,000
 855,154
          
Net increase (decrease) in cash and cash equivalents697,439
 5,532
 (5,366) (1,259) 696,346
Cash and equivalents, beginning of period185,381
 704
 34,334
 (2,016) 218,403
Cash and equivalents, end of period$882,820
 $6,236
 $28,968
 $(3,275) $914,749
Cash flows from financing activities:         
Contributions from PBF LLC$287,000
 $
 $
 $
 $287,000
Distributions to members(42,533) (10,054) 
 
 (52,587)
Repayments of revolver borrowings(350,000) 
 
 
 (350,000)
Repayments of PBF Rail Term Loan
 
 (6,812) 
 (6,812)
Repayments of note payable
 (5,621) 
 
 (5,621)
Catalyst lease settlements
 (9,108) 
 
 (9,108)
Due to/from affiliates
 31
 
 (31) 
Deferred financing costs and other(12,692) 
 
 
 (12,692)
Net cash used in financing activities$(118,225) $(24,752) $(6,812) $(31) $(149,820)
          
Net increase (decrease) in cash and cash equivalents39,470
 (4,377) 438
 
 35,531
Cash and cash equivalents, beginning of period486,568
 13,456
 26,136
 
 526,160
Cash and cash equivalents, end of period$526,038
 $9,079
 $26,574
 $
 $561,691


F- 5968

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

22.20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING
CONSOLIDATING STATEMENTSTATEMENTS OF CASH FLOWFLOWS
 Year Ended December 31, 2014
 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total
Cash flows from operating activities:         
Net income (loss)$21,117
 $(1,184,027) $52,706
 $1,131,321
 $21,117
Adjustments to reconcile net income to net cash provided by operating activities:         
Depreciation and amortization20,334
 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 adjustment566,412
 123,698
 
 
 690,110
Gain on disposition of property, plant and equipment(277) 
 (618) 
 (895)
Pension and other post retirement benefit cost6,426
 16,174
 
 
 22,600
Equity in earnings of subsidiaries1,131,321
 
 
 (1,131,321) 
Changes in current assets and current liabilities:         
Accounts receivable69,887
 (17,976) (6,533) 
 45,378
Amounts due to/from related parties(1,227,851) 1,328,439
 (92,181) 
 8,407
Inventories(259,352) 20,711
 (155,390) 
 (394,031)
Other current assets22,287
 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 activities138,075
 360,364
 (735) (2,016) 495,688
          
Cash flows from investing activities:         
Expenditures for property, plant and equipment(152,814) (205,508) (112,138) 
 (470,460)
Expenditures for refinery turnarounds costs
 (137,688) 
 
 (137,688)
Expenditures for other assets
 (17,255) 
 
 (17,255)
Investment in subsidiaries(44,346) 
 
 44,346
 
Proceeds from sale of assets133,845
 
 68,809
 
 202,654
Net cash (used in) provided by investing activities(63,315) (360,451) (43,329) 44,346
 (422,749)
          
Cash flows from financing activities:         
Proceeds from member's capital contributions328,664
 
 44,346
 (44,346) 328,664
Distributions to members(361,352) 
 
 
 (361,352)
Proceeds from intercompany notes payable90,631
 
 
 
 90,631
Proceeds from revolver borrowings395,000
 
 
 
 395,000
Repayments of revolver borrowings(410,000) 
 
 
 (410,000)
Proceeds from Rail Facility revolver borrowings
 
 83,095
 
 83,095
Repayments of Rail Facility revolver borrowings
 
 (45,825) 
 (45,825)
Deferred financing costs and other(8,501) 
 (3,218) 
 (11,719)
Net cash provided by (used in) financing activities34,442
 
 78,398
 (44,346) 68,494
          
Net increase (decrease) in cash and cash equivalents109,202

(87)
34,334

(2,016)
141,433
Cash and equivalents, beginning of period76,179
 791
 
 
 76,970
Cash and equivalents, end of period$185,381
 $704
 $34,334
 $(2,016) $218,403
 Year Ended December 31, 2017
 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total
Cash flows from operating activities:         
Net income (loss)$457,200
 $(1,349,208) $1,273
 $1,347,935
 $457,200
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:         
Depreciation and amortization19,971
 246,984
 7,696
 
 274,651
Stock-based compensation
 21,503
 
 
 21,503
Change in fair value of catalyst leases
 2,247
 
 
 2,247
Deferred income taxes
 
 (12,526) 
 (12,526)
Non-cash change in inventory repurchase obligations13,779
 
 
 
 13,779
Non-cash lower of cost or market inventory adjustment(295,532) 
 
 
 (295,532)
Debt extinguishment costs25,451
 
 
 
 25,451
Distribution received from subsidiaries
 7,200
 
 (7,200) 
Pension and other post-retirement benefit costs6,607
 35,635
 
 
 42,242
Equity in earnings (loss) of subsidiaries1,349,208
 (1,273) 
 (1,347,935) 
Income from equity method investee
 
 (14,565) 
 (14,565)
Distributions from equity method investee
 
 20,244
 
 20,244
Loss on sale of assets
 1,458
 
 
 1,458
Changes in operating assets and liabilities:         
Accounts receivable(304,151) 394
 (31,491) 
 (335,248)
Due to/from affiliates(1,696,091) 1,709,868
 (10,544) 
 3,233
Inventories(6,725) 
 (47,980) 
 (54,705)
Prepaid expense and other current assets6,922
 (14,373) (1,740) 
 (9,191)
Accounts payable53,569
 (28,168) 7,663
 1,463
 34,527
Accrued expenses288,434
 (38,022) 102,703
 
 353,115
Deferred revenue(4,896) 34
 17
 
 (4,845)
Other assets and liabilities(11,740) (19,098) (21,136) 
 (51,974)
Net cash (used in) provided by operating activities$(97,994) $575,181
 $(386) $(5,737) $471,064
          
Cash flows from investing activities:         
Expenditures for property, plant and equipment(1,884) (230,261) (511) 
 (232,656)
Expenditures for deferred turnaround costs
 (379,114) 
 
 (379,114)
Expenditures for other assets
 (31,143) 
 
 (31,143)
Equity method investment - return of capital
 
 1,300
 
 1,300
Due to/from affiliates(856) 
 
 856
 
Net cash (used in) provided by investing activities$(2,740) $(640,518) $789
 $856
 $(641,613)




F- 6069

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT SHARE, UNIT, BARREL AND PER SHARE, PER UNIT AND BARREL DATA)

22.20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING
CONSOLIDATING STATEMENTSTATEMENTS OF CASH FLOWFLOWS (Continued)
 Year Ended December 31, 2013
 Issuer Guarantors Subsidiaries Non-Guarantors Subsidiaries Combining and Consolidated Adjustments Total
Cash flows from operating activities:         
Net income$238,876
 $722,673
 $
 $(722,673) $238,876
Adjustments to reconcile net income to net cash         
provided by operating activities:         
Depreciation and amortization19,296
 98,705
 
 
 118,001
Stock-based compensation
 3,753
 
 
 3,753
Change in fair value of catalyst lease obligation
 (4,691) 
 
 (4,691)
Non-cash change in inventory repurchase obligations
 (20,492) 
 
 (20,492)
Pension and other post retirement benefit costs4,575
 12,153
 
 
 16,728
Gain on disposition of property, plant and equipment(388) 205
 
 
 (183)
Equity in earnings of subsidiaries(722,673) 
 
 722,673
 
Changes in operating assets and liabilities:         
Accounts receivable(281,386) 188,535
 
 
 (92,851)
Amounts due to/from related parties626,623
 (611,902) 
 
 14,721
Inventories(153,782) 199,773
 
 
 45,991
Other current assets(40,416) (2,039) 
 
 (42,455)
Accounts payable109,988
 (67,752) 
 
 42,236
Accrued expenses222,194
 (7,377) 
 
 214,817
Deferred revenue7,766
 (210,543) 
 
 (202,777)
Other assets and liabilities(1,140) (19,263) 
 
 (20,403)
Net cash provided by operating activities29,533
 281,738
 
 
 311,271
          
Cash flows from investing activities:         
Expenditures for property, plant and equipment(127,653) (190,741) 
 
 (318,394)
Expenditures for refinery turnarounds costs
 (64,616) 
 
 (64,616)
Expenditures for other assets
 (32,692) 
 
 (32,692)
Proceeds from sale of assets102,428
 
 
 
 102,428
Net cash used in investing activities(25,225) (288,049) 
 
 (313,274)
          
Cash flows from financing activities:         
Proceeds from revolver borrowings1,450,000
 
 
 
 1,450,000
Proceeds from intercompany notes payable31,835
 
 
 
 31,835
Proceeds from member's capital contributions
 1,757
 
 
 1,757
Proceeds from catalyst lease
 14,337
 
 
 14,337
Distributions to members(215,846) 
 
 
 (215,846)
Repayments of revolver borrowings(1,435,000) 
 
 
 (1,435,000)
Payment of contingent consideration related to acquisition of Toledo Refinery
 (21,357) 
 
 (21,357)
Deferred financing costs and other(1,044) 
 
 
 (1,044)
Net cash used in financing activities(170,055) (5,263) 
 
 (175,318)
          
Net increase (decrease) in cash and cash equivalents(165,747) (11,574) 
 
 (177,321)
Cash and equivalents, beginning of period241,926
 12,365
 
 
 254,291
Cash and equivalents, end of period$76,179
 $791
 $
 $
 $76,970
Cash flows from financing activities:         
Contributions from PBF LLC$97,000
 $
 $
 $
 $97,000
Distributions to members(61,149) 
 
 
 (61,149)
Distributions to T&M and Collins shareholders
 
 (9,000) 7,200
 (1,800)
Payment received for affiliate note receivable
 11,600
 
 
 11,600
Proceeds from 2025 Senior Notes725,000
 
 
 
 725,000
Cash paid to extinguish 2020 Senior Notes(690,209) 
 
 
 (690,209)
Proceeds from revolver borrowings490,000
 
 
 
 490,000
Repayments of revolver borrowings(490,000) 
 
 
 (490,000)
Repayments of PBF Rail Term Loan
 
 (6,633) 
 (6,633)
Repayments of note payable
 (1,210) 
 
 (1,210)
Catalyst lease settlements
 10,830
 
 
 10,830
Due to/from affiliates
 856
 
 (856) 
Deferred financing costs and other(13,425) 
 
 
 (13,425)
Net cash provided by (used in) financing activities$57,217
 $22,076
 $(15,633) $6,344
 $70,004
          
Net (decrease) increase in cash and cash equivalents(43,517) (43,261) (15,230) 1,463
 (100,545)
Cash and cash equivalents, beginning of period530,085
 56,717
 41,366
 (1,463) 626,705
Cash and cash equivalents, end of period$486,568
 $13,456
 $26,136
 $
 $526,160








F- 6170

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENTS OF CASH FLOWS
 Year Ended December 31, 2016
 Issuer Guarantor Subsidiaries Non-Guarantor Subsidiaries Combining and Consolidating Adjustments Total
Cash flows from operating activities:         
Net income (loss)$235,887
 $(1,502,244) $(74,507) $1,576,750
 $235,886
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:         
Depreciation and amortization14,873
 194,723
 9,337
 
 218,933
Stock-based compensation
 18,296
 
 
 18,296
Change in fair value of catalyst leases
 (1,422) 
 
 (1,422)
Deferred income taxes
 
 19,802
 
 19,802
Non-cash change in inventory repurchase obligations29,453
 
 
 
 29,453
Non-cash lower of cost or market inventory adjustment(521,348) 
 
 
 (521,348)
Pension and other post-retirement benefit costs7,139
 30,848
 
 
 37,987
Income from equity method investee
 
 (5,679) 
 (5,679)
Loss on sale of assets2,392
 150
 8,832
 
 11,374
Equity in earnings of subsidiaries1,502,243
 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
Inventories217,629
 
 18,973
 
 236,602
Prepaid and other current assets(3,200) (2,675) 92
 
 (5,783)
Accounts payable163,272
 41,025
 7,405
 1,812
 213,514
Accrued expenses531,613
 (353,591) 49,964
 
 227,986
Deferred revenue6,858
 1,438
 1
 
 8,297
Other assets and liabilities(5,833) (16,238) 1,193
 
 (20,878)
Net cash (used in) provided by 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)
Chalmette Acquisition working capital settlement
 (2,659) 
 
 (2,659)
Expenditures for property, plant and equipment(21,563) (255,434) (5,433) 
 (282,430)
Expenditures for deferred turnaround costs
 (198,664) 
 
 (198,664)
Expenditures for other assets
 (42,506) 
 
 (42,506)
Investment in subsidiaries12,800
 
 
 (12,800) 
Capital contributions to subsidiaries(8,287) 
 
 8,287
 
Proceeds from sale of assets4,802
 
 19,890
 
 24,692
Net cash (used in) provided by investing activities$(984,180) $(499,263) $14,457
 $(4,513) $(1,473,499)


F- 71

PBF HOLDING COMPANY LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS, EXCEPT UNIT, BARREL AND PER BARREL DATA)

20. CONSOLIDATING FINANCIAL STATEMENTS OF PBF HOLDING CONSOLIDATING STATEMENTS OF CASH FLOWS (Continued)
Cash flows from financing activities:         
Proceeds from member’s capital contributions$
 $
 $8,287
 $(8,287) $
Contributions from PBF LLC450,300
 
 
 
 450,300
Distribution to parent
 
 (12,800) 12,800
 
Distributions to members(139,434) 
 
 
 (139,434)
Proceeds from affiliate notes payable43,396
 
 
 
 43,396
Repayments of affiliate notes payable(53,524) 
 
 
 (53,524)
Proceeds from revolver borrowings550,000
 
 
 
 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
Catalyst lease settlements
 15,589
 
 
 15,589
Net cash provided by (used in) financing activities$650,738
 $15,589
 $(37,004) $4,513
 $633,836
          
Net (decrease) increase in cash and cash equivalents(352,735) 50,481
 12,398
 1,812
 (288,044)
Cash and cash equivalents, beginning of period882,820
 6,236
 28,968
 (3,275) 914,749
Cash and cash equivalents, end of period$530,085
 $56,717
 $41,366
 $(1,463) $626,705



ITEM 16. FORM 10-K SUMMARY
Not applicable.



SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
 
   
PBF HOLDING COMPANY LLC 
                    (Registrant)
By: /s/ Thomas J. Nimbley
  (Thomas J. Nimbley)
  
Chief Executive Officer
(Principal Executive Officer)
Date: March 24, 20166, 2019
POWER OF ATTORNEY
Each of the officers and directors of PBF Holding Company LLC, whose signature appears below, in so signing, also makes, constitutes and appoints each of Erik Young, Matthew Lucey and Trecia Canty, and each of them, his true and lawful attorneys-in-fact, with full power and substitution, for him in any and all capacities, to execute and cause to be filed with the SEC any and all amendments to this Annual Report on Form 10-K, with exhibits thereto and other documents connected therewith and to perform any acts necessary to be done in order to file such documents, and hereby ratifies and confirms all that said attorneys-in-fact or their substitute or substitutes may do or cause to be done by virtue hereof.
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
 
Signature  Title Date
   
/s/ Thomas J. Nimbley Chief Executive Officer and Director March 24, 20166, 2019
(Thomas J. Nimbley)  (Principal Executive Officer)  
   
/s/ Erik Young Senior Vice President, Chief Financial Officer March 24, 20166, 2019
(Erik Young)  (Principal Financial Officer)  
   
/s/ John Barone Chief Accounting Officer March 24, 20166, 2019
(John Barone)  (Principal Accounting Officer)  
   
/s/ Jeffrey DillTrecia Canty  Director March 24, 20166, 2019
(Jeffrey Dill)Trecia Canty)     
     
/s/ Matthew C. Lucey Director March 24, 20166, 2019
(Matthew C. Lucey)