SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation and Presentation

These consolidated financial statements include the accounts of PBF Energy and subsidiaries in which PBF Energy has a controlling interest. All intercompany accounts and transactions have been eliminated in consolidation.

Change in Presentation

In 2017, the Company determined that it would revise the presentation of certain line items on its consolidated statements of operations to enhance its disclosure under the requirements of Rule 5-03 of Regulation S-X. The revised presentation is comprised of the inclusion of a subtotal within costs and expenses referred to as “Cost of sales” and the reclassification of total depreciation and amortization expense between such amounts attributable to cost of sales and other operating costs and expenses. The amount of depreciation and amortization expense that is presented separately within the “Cost of Sales” subtotal represents depreciation and amortization of refining and logistics assets that are integral to the refinery production process.

The historical comparative information has been revised to conform to the current presentation. This revised presentation does not have an effect on the Company’s historical consolidated income from operations or net income, nor does it have any impact on its consolidated balance sheets, statements of comprehensive income, statements of changes in equity or statements of cash flows. Presented below is a summary of the effects of this revised presentation on the Company’s historical statements of operations for the years ended December 31, 2016 and 2015 (in thousands):



	Year Ended December 31, 2016
	As Previously Reported		Adjustments	As Reclassified
Cost and expenses:
Cost of products and other	$	13,598,341	—	$	13,598,341
Operating expenses (excluding depreciation and amortization expense as reflected below)	1,423,198		—	1,423,198
Depreciation and amortization expense	—		216,341	216,341
Cost of sales				15,237,880
General and administrative expenses (excluding depreciation and amortization expense as reflected below)	166,452		—	166,452
Depreciation and amortization expense	222,176		(216,341)	5,835
Loss on sale of assets	11,374		—	11,374
Total cost and expenses	$	15,421,541		$	15,421,541



	Year Ended December 31, 2015
	As Previously Reported		Adjustments	As Reclassified
Cost and expenses:
Cost of products and other	$	11,481,614	—	$	11,481,614
Operating expenses (excluding depreciation and amortization expense as reflected below)	904,525		—	904,525
Depreciation and amortization expense	—		187,729	187,729
Cost of sales				12,573,868
General and administrative expenses (excluding depreciation and amortization expense as reflected below)	181,266		—	181,266
Depreciation and amortization expense	197,417		(187,729)	9,688
Gain on sale of assets	(1,004)		—	(1,004)
Total cost and expenses	$	12,763,818		$	12,763,818

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’s consolidated financial statements for prior periods have been reclassified to conform to the 2017 presentation. These reclassifications, in addition to the changes in “Cost and expenses” described above, include certain details about accrued expenses and deferred charges and other assets in those respective footnotes.

Use of Estimates

The preparation of the financial statements in conformity with accounting principles generally accepted in the United States (“GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures. Actual results could differ from those estimates.

Business Combinations

We use the acquisition method of accounting for the recognition of assets acquired and liabilities assumed in business combinations at their estimated fair values as of the date of acquisition. Any excess consideration transferred over the estimated fair values of the identifiable net assets acquired is recorded as goodwill. Significant judgment is required in estimating the fair value of assets acquired. As a result, in the case of significant acquisitions, we obtain the assistance of third-party valuation specialists in estimating fair values of tangible and intangible assets based on available historical information and on expectations and assumptions about the future, considering the perspective of marketplace participants. While management believes those expectations and assumptions are reasonable, they are inherently uncertain. Unanticipated market or macroeconomic events and circumstances may occur, which could affect the accuracy or validity of the estimates and assumptions.

Cash and Cash Equivalents

The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents. The carrying amount of the cash equivalents approximates fair value due to the short-term maturity of those instruments.

Marketable Securities

Debt or equity securities are classified into the following reporting categories: held-to-maturity, trading or available-for-sale securities. The Company does not routinely sell marketable securities prior to their scheduled maturity dates. Some of the Company’s investments may be held and restricted for the purpose of funding future capital expenditures and acquisitions. Such investments are classified as available-for-sale marketable securities as they may occasionally be sold prior to their scheduled maturity dates due to the unexpected timing of cash needs. The carrying value of these marketable securities approximates fair value and is measured using Level 1 inputs (as defined below). The terms of the marketable securities ranged from one to three months and were classified on the balance sheet as current assets for the year ended December 31, 2016.

The marketable securities were fully liquidated as of December 31, 2017 and the PBFX Term Loan (as defined in “Note 9 - Credit Facility and Debt”) that they collateralized was repaid in full during the year ended December 31, 2017.

Concentrations of Credit Risk

For the years ended December 31, 2017, 2016 and 2015 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, 2017 or December 31, 2016.

Revenue, Deferred Revenue and Accounts Receivable

The Company sells various refined products primarily through its refinery subsidiaries and recognizes revenue related to the sale of products when there is persuasive evidence of an agreement, the sales prices are fixed or determinable, collectability is reasonably assured and when products are shipped or delivered in accordance with their respective agreements. Revenue for services is recorded when the services have been provided. Certain of the Company’s refineries have product offtake agreements with third-parties under which these third parties purchase a portion of the refineries’ daily gasoline production. The refineries also sell their products through short-term contracts or on the spot market.

On May 4, 2017 and September 8, 2017, PBF Holding and its subsidiaries, DCR and PRC, entered into amendments to the inventory intermediation agreements (as amended in the second and third quarters of 2017, the “A&R Intermediation Agreements”) with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. (“J. Aron”), pursuant to which certain terms of the existing inventory intermediation agreements were amended, including, among other things, pricing and an extension of the terms. As a result of the amendments (i) the A&R Intermediation Agreement by and among J. Aron, PBF Holding and PRC relating to the Paulsboro refinery extends the term to December 31, 2019, which term may be further extended by mutual consent of the parties to December 31, 2020 and (ii) the A&R 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&R Intermediation Agreement, J. Aron will continue to purchase and hold title to certain of the intermediate and finished products (the “Products”) produced by the Paulsboro and Delaware City refineries (the “Refineries”), respectively, and delivered into tanks at the Refineries. Furthermore, J. Aron agrees to sell the Products back to Paulsboro refinery and Delaware City refinery as the Products are discharged out of the Refineries’ tanks. These purchases and sales are settled monthly at the daily market prices related to those products. These transactions are considered to be made in contemplation of each other and, accordingly, do not result in the recognition of a sale when title passes from the refineries to J. Aron. Additionally, J. Aron has the right to store the Products purchased in tanks under the A&R Intermediation Agreements and will retain these storage rights for the term of the agreements. PBF Holding will continue to market and sell the Products independently to third parties.

Accounts receivable are carried at invoiced amounts. An allowance for doubtful accounts is established, if required, to report such amounts at their estimated net realizable value. In estimating probable losses, management reviews accounts that are past due and determines if there are any known disputes. There was no allowance for doubtful accounts at December 31, 2017 and 2016.

Excise taxes on sales of refined products that are collected from customers and remitted to various governmental agencies are reported on a net basis.

Inventory

Inventories are carried at the lower of cost or market. The cost of crude oil, feedstocks, blendstocks and refined products are determined under the last-in first-out (“LIFO”) method using the dollar value LIFO method with increments valued based on average purchase prices during the year. The cost of supplies and other inventories is determined principally on the weighted average cost method.

Property, Plant and Equipment

Property, plant and equipment additions are recorded at cost. The Company capitalizes costs associated with the preliminary, pre-acquisition and development/construction stages of a major construction project. The Company capitalizes the interest cost associated with major construction projects based on the effective interest rate of total borrowings. The Company also capitalizes costs incurred in the acquisition and development of software for internal use, including the costs of software, materials, consultants and payroll-related costs for employees incurred in the application development stage.

Depreciation is computed using the straight-line method over the following estimated useful lives:



Process units and equipment	5-25 years
Pipeline and equipment	5-25 years
Buildings	25 years
Computers, furniture and fixtures	3-7 years
Leasehold improvements	20 years
Railcars	50 years

Maintenance and repairs are charged to operating expenses as they are incurred. Improvements and betterments, which extend the lives of the assets, are capitalized.

Deferred Charges and Other Assets, Net

Deferred charges and other assets include refinery turnaround costs, catalyst, precious metals catalyst, linefill, deferred financing costs and intangible assets. Refinery turnaround costs, which are incurred in connection with planned major maintenance activities, are capitalized when incurred and amortized on a straight-line basis over the period of time estimated to lapse until the next turnaround occurs (generally 3 to 5 years).

Precious metals catalyst and linefill are considered indefinite-lived assets as they are not expected to deteriorate in their prescribed functions. Such assets are assessed for impairment in connection with the Company’s review of its long-lived assets as indicators of impairment develop.

Deferred financing costs are capitalized when incurred and amortized over the life of the loan (generally 1 to 8 years).

Intangible assets with finite lives primarily consist of emission credits and permits and are amortized over their estimated useful lives (generally 1 to 10 years).

Long-Lived Assets and Definite-Lived Intangibles

The Company reviews its long-lived assets for impairment whenever events or changes in circumstances indicate the carrying value may not be recoverable. Impairment is evaluated by comparing the carrying value of the long-lived assets to the estimated undiscounted future cash flows expected to result from use of the assets and their ultimate disposition. If such analysis indicates that the carrying value of the long-lived assets is not considered to be recoverable, the carrying value is reduced to the fair value.

Impairment assessments inherently involve judgment as to assumptions about expected future cash flows and the impact of market conditions on those assumptions. Although management would utilize assumptions that it believes are reasonable, future events and changing market conditions may impact management’s assumptions, which could produce different results.

Asset Retirement Obligations

The Company records an asset retirement obligation at fair value for the estimated cost to retire a tangible long-lived asset at the time the Company incurs that liability, which is generally when the asset is purchased, constructed, or leased. The Company records the liability when it has a legal or contractual obligation to incur costs to retire the asset and when a reasonable estimate of the fair value of the liability can be made. If a reasonable estimate cannot be made at the time the liability is incurred, the Company will record the liability when sufficient information is available to estimate the liability’s fair value. Certain of the Company’s asset retirement obligations are based on its legal obligation to perform remedial activity at its refinery sites when it permanently ceases operations of the long-lived assets. The Company therefore considers the settlement date of these obligations to be indeterminable. Accordingly, the Company cannot calculate an associated asset retirement liability for these obligations at this time. The Company will measure and recognize the fair value of these asset retirement obligations when the settlement date is determinable.

Environmental Matters

Liabilities for future remediation costs are recorded when environmental assessments and/or remedial efforts are probable and the costs can be reasonably estimated. Other than for assessments, the timing and magnitude of these accruals generally are based on the completion of investigations or other studies or a commitment to a formal plan of action. Environmental liabilities are based on best estimates of probable future costs using currently available technology and applying current regulations, as well as the Company’s own internal environmental policies. The measurement of environmental remediation liabilities may be discounted to reflect the time value of money if the aggregate amount and timing of cash payments of the liabilities are fixed or reliably determinable. The actual settlement of the Company’s liability for environmental matters could materially differ from its estimates due to a number of uncertainties such as the extent of contamination, changes in environmental laws and regulations, potential improvements in remediation technologies and the participation of other responsible parties.

Stock-Based Compensation

Stock-based compensation includes the accounting effect of options to purchase PBF Energy Class A common stock granted by the Company to certain employees, Series A warrants issued or granted by PBF LLC to employees in connection with their acquisition of PBF LLC Series A units, options to acquire Series A units of PBF LLC granted by PBF LLC to certain employees, Series B units of PBF LLC that were granted to certain members of management and restricted PBF LLC Series A Units and restricted PBF Energy Class A common stock granted to certain directors and officers. The estimated fair value of the options to purchase PBF Energy Class A common stock and the PBF LLC Series A warrants and options is based on the Black-Scholes option pricing model and the fair value of the PBF LLC Series B units is estimated based on a Monte Carlo simulation model. The estimated fair value is amortized as stock-based compensation expense on a straight-line method over the vesting period and included in general and administration expense with forfeitures recognized in the period they occur.

Additionally, stock-based compensation also includes unit-based compensation provided to certain officers, non-employee directors and seconded employees of PBFX’s general partner, PBF GP, or its affiliates, consisting of PBFX phantom units. The fair value of PBFX’s phantom units are measured based on the fair market value of the underlying common units on the date of grant based on the common unit closing price on the grant date. The estimated fair value of PBFX’s phantom units is amortized over the vesting period using the straight-line method. Awards vest over a four year service period. The phantom unit awards may be settled in common units, cash or a combination of both. Expenses related to unit-based compensation are also included in general and administrative expenses with forfeitures recognized in the period they occur.

Income Taxes

As a result of the PBF Energy’s acquisition of PBF LLC Series A Units or exchanges of PBF LLC Series A Units for PBF Energy Class A common stock, PBF Energy expects to benefit from amortization and other tax deductions reflecting the step up in tax basis in the acquired assets. Those deductions will be allocated to PBF Energy and will be taken into account in reporting PBF Energy’s taxable income. As a result of a federal income tax election made by PBF LLC, applicable to a portion of PBF Energy’s acquisition of PBF LLC Series A Units, the income tax basis of the assets of PBF LLC, underlying a portion of the units PBF Energy acquired, has been adjusted based upon the amount that PBF Energy paid for that portion of its PBF LLC Series A Units. PBF Energy entered into the Tax Receivable Agreement (as defined in “Note 13 - Commitments and Contingencies”) which provides for the payment by PBF Energy 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 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. As a result of these transactions, PBF Energy’s tax basis in its share of PBF LLC’s assets will be higher than the book basis of these same assets. This resulted in a deferred tax asset of $325,405 as of December 31, 2017, of which the majority is expected to be realized over 10 years as the tax basis of these assets is amortized.

Deferred taxes are provided using a liability method, whereby deferred tax assets are recognized for deductible temporary differences and deferred tax liabilities are recognized for taxable temporary differences. Temporary differences represent the differences between the reported amounts of assets and liabilities and their tax bases. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effect of changes in tax laws and rates on the date of enactment. PBF Energy recognizes tax benefits for uncertain tax positions only if it is more likely than not that the position is sustainable based on its technical merits. Interest and penalties on uncertain tax positions are included as a component of the provision for income taxes on the consolidated statements of operations. As a result of the reduction of the corporate federal tax rate to 21% as part of the Tax Cut and Jobs Act (the “TCJA”), the liability associated with the Tax Receivable Agreement was reduced. Accordingly, the deferred tax assets associated with the payments made or expected to be made related to the Tax Receivable Agreement liability were also reduced.

The Federal tax returns for all years since 2014 and state tax returns for all years since 2013 or 2014 (see “Note 19 - Income Taxes”) are subject to examination by the respective tax authorities.

Net Income Per Share

Net income per share is calculated by dividing the net income available to PBF Energy Class A common stockholders by the weighted average number of shares of PBF Energy Class A common stock outstanding during the period. Diluted net income per share is calculated by dividing the net income available to PBF Energy Class A common stockholders, adjusted for the net income attributable to the noncontrolling interest and the assumed income tax expense thereon, by the weighted average number of PBF Energy Class A common shares outstanding during the period adjusted to include the assumed exchange of all PBF LLC Series A units outstanding for PBF Energy Class A common stock, if applicable under the if converted method, and the potentially dilutive effect of outstanding options to purchase shares of PBF Energy Class A common stock, and options and warrants to purchase PBF LLC Series A Units, subject to forfeiture utilizing the treasury stock method.

Pension and Other Post-Retirement Benefits

The Company recognizes an asset for the overfunded status or a liability for the underfunded status of its pension and post-retirement benefit plans. The funded status is recorded within other long-term liabilities or assets. Changes in the plans’ funded status are recognized in other comprehensive income in the period the change occurs.

Fair Value Measurement

A fair value hierarchy (Level 1, Level 2, or Level 3) is used to categorize fair value amounts based on the quality of inputs used to measure fair value. Accordingly, fair values derived from Level 1 inputs utilize quoted prices in active markets for identical assets or liabilities. Fair values derived from Level 2 inputs are based on quoted prices for similar assets and liabilities in active markets, and inputs other than quoted prices that are either directly or indirectly observable for the asset or liability. Level 3 inputs are unobservable inputs for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability.

The Company uses appropriate valuation techniques based on the available inputs to measure the fair values of its applicable assets and liabilities. When available, the Company measures fair value using Level 1 inputs because they generally provide the most reliable evidence of fair value. In some valuations, the inputs may fall into different levels in the hierarchy. In these cases, the asset or liability level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurements.

Financial Instruments

The estimated fair value of financial instruments has been determined based on the Company’s assessment of available market information and appropriate valuation methodologies. The Company’s non-derivative financial instruments that are included in current assets and current liabilities are recorded at cost in the consolidated balance sheets. The estimated fair value of these financial instruments approximates their carrying value due to their short-term nature. Derivative instruments are recorded at fair value in the consolidated balance sheets.

The Company’s commodity contracts are measured and recorded at fair value using Level 1 inputs based on quoted prices in an active market, Level 2 inputs based on quoted market prices for similar instruments, or Level 3 inputs based on third party sources and other available market based data. The Company’s catalyst lease obligation and derivatives related to the Company’s crude oil and feedstocks and refined product purchase obligations are measured and recorded at fair value using Level 2 inputs on a recurring basis, based on observable market prices for similar instruments.

Derivative Instruments

The Company is exposed to market risk, primarily related to changes in commodity prices for the crude oil and feedstocks used in the refining process as well as the prices of the refined products sold. The accounting treatment for commodity contracts depends on the intended use of the particular contract and on whether or not the contract meets the definition of a derivative.

All derivative instruments, not designated as normal purchases or sales, are recorded in the balance sheet as either assets or liabilities measured at their fair values. Changes in the fair value of derivative instruments that either are not designated or do not qualify for hedge accounting treatment or normal purchase or normal sale accounting are recognized currently in earnings. Contracts qualifying for the normal purchase and sales exemption are accounted for upon settlement. Cash flows related to derivative instruments that are not designated or do not qualify for hedge accounting treatment are included in operating activities.

The Company designates certain derivative instruments as fair value hedges of a particular risk associated with a recognized asset or liability. At the inception of the hedge designation, the Company documents the relationship between the hedging instrument and the hedged item, as well as its risk management objective and strategy for undertaking various hedge transactions. Derivative gains and losses related to these fair value hedges, including hedge ineffectiveness, are recorded in cost of sales along with the change in fair value of the hedged asset or liability attributable to the hedged risk. Cash flows related to derivative instruments that are designated as fair value hedges are included in operating activities.

Economic hedges are hedges not designated as fair value or cash flow hedges for accounting purposes that are used to (i) manage price volatility in certain refinery feedstock and refined product inventories, and (ii) manage price volatility in certain forecasted refinery feedstock purchases and refined product sales. These instruments are recorded at fair value and changes in the fair value of the derivative instruments are recognized currently in cost of sales.

Derivative accounting is complex and requires management judgment in the following respects: identification of derivatives and embedded derivatives, determination of the fair value of derivatives, documentation of hedge relationships, assessment and measurement of hedge ineffectiveness and election and designation of the normal purchases and sales exception. All of these judgments, depending upon their timing and effect, can have a significant impact on the Company’s earnings.

Recently Adopted Accounting Guidance

Effective January 1, 2017, the Company adopted Accounting Standard Update (“ASU”) No. 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments (a consensus of the FASB Emerging Issues Task Force)” (“ASU 2016-06”). ASU 2016-6 was issued in March 2016 by the Financial Accounting Standards Board (“FASB”) to increase consistency in practice in applying guidance on determining if an embedded derivative is clearly and closely related to the economic characteristics of the host contract, specifically for assessing whether call (put) options that can accelerate the repayment of principal on a debt instrument meet the clearly and closely related criterion. The Company’s adoption of this guidance did not materially impact its consolidated financial statements.

Effective January 1, 2017, the Company adopted ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”). ASU 2016-09 was issued by the FASB in March 2016 to simplify certain aspects of the accounting for share-based payments to employees. The guidance in ASU 2016-09 requires all income tax effects of awards to be recognized in the income statement when the awards vest or are settled rather than recording excess tax benefits or deficiencies in additional paid-in capital. The guidance in ASU 2016-09 also allows an employer to repurchase more of an employee’s shares than it could prior to its adoption for tax withholding purposes without triggering liability accounting and to make a policy election to account for forfeitures as they occur. The Company’s adoption of this guidance did not materially impact its consolidated financial statements.

Effective January 1, 2017, the Company adopted ASU No. 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control” (“ASU 2016-17”). ASU 2016-17 was issued by the FASB in October 2016 to amend the consolidation guidance on how a reporting entity that is the single decision maker of a variable interest entity (“VIE”) should treat indirect interests in the entity held through related parties that are under common control with the reporting entity when determining whether it is the primary beneficiary of that VIE. The amendments in this ASU do not change the characteristics of a primary beneficiary in current GAAP. The amendments in this ASU require that a reporting entity, in determining whether it satisfies the second characteristic of a primary beneficiary, include all of its direct variable interests in a VIE and, on a proportionate basis, its indirect variable interests in a VIE held through related parties, including related parties that are under common control with the reporting entity. The Company’s adoption of this guidance did not materially impact its consolidated financial statements.

In January 2017, the FASB issued ASU No. 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business” (“ASU 2017-01”), which provides guidance to assist entities with evaluating when a set of transferred assets and activities is a business. Under ASU 2017-01, it is expected that the definition of a business will be narrowed and more consistently applied. ASU 2017-01 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods. The amendments in this ASU should be applied prospectively on or after the effective date. Early adoption of ASU 2017-01 is permitted and the Company early adopted the new standard in its consolidated financial statements and related disclosures effective January 1, 2017. The Company’s adoption of this guidance did not materially impact its consolidated financial statements.

Recently Issued Accounting Pronouncements

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606)” requiring revenue to be recognized when promised goods or services are transferred to customers in an amount that reflects the expected consideration for these goods or services. The new guidance supersedes the revenue recognition requirements in FASB ASC Topic 605, “Revenue Recognition”, and most industry-specific guidance. The Company has adopted this new standard effective January 1, 2018, using the modified retrospective application, whereby a cumulative effect adjustment will be recognized upon adoption, if applicable, and the guidance will be applied prospectively.

The Company has completed our evaluation of the provisions of this standard and concluded that the adoption will not materially change the amount or timing of revenues recognized by the Company, nor will it materially affect the Company’s financial position. The majority of the Company’s revenues are generated from the sale of refined petroleum products and ethanol. 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 its 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 its customers and when the Company’s performance obligation to its customers is fulfilled. Under the modified retrospective method of adoption, the cumulative effect of initially applying the standard is recognized as an adjustment to the opening balance of retained earnings, and revenues reported in the periods prior to the date of adoption are not changed. The Company does not, however, expect to make such an adjustment to retained earnings as the Company has determined any such adjustment to not be material. The Company is currently developing its revenue disclosures and enhancing its accounting systems to enable the preparation of such 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 additional clarification and implementation guidance for leases related to ASU 2016-02 including ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842 (“ASU 2018-01”) (collectively, the Company refers to ASU 2016-02 and these additional ASUs as the “Updated Lease Guidance”) The Updated 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 is effective for interim and annual periods beginning after December 15, 2018, and requires a modified retrospective approach to adoption. ASU 2018-01 provides a practical expedient whereby land easements (also known as “rights of way”) that are not accounted for as leases under existing GAAP would not need to be evaluated under ASU 2016-02; however the Updated Lease Guidance would apply prospectively to all new or modified land easements after the effective date of ASU 2016-02. In January 2018, the FASB issued a proposed ASU that would provide an additional transition method for the Updated Lease Guidance for lessees and a practical expedient for lessors. As proposed, this additional transition method would allow lessees to initially apply the requirements of ASU 2016-02 by recognizing a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption. The proposed practical expedient would allow lessors to not separate non-lease components from the related lease components in certain situations. Assuming the proposed ASU is approved after the comment period, the proposed ASU would have the same effective date as ASU 2016-02. While early adoption is permitted, the Company will not early adopt this Updated Lease Guidance. The Company has established a working group to study and lead implementation of the Updated Lease Guidance. This working group has been meeting on a regular basis and has instituted a preliminary task plan designed to meet the implementation deadline for ASU 2016-02. The Company has also evaluated and purchased a lease software system and has begun implementation of the selected system. The working group continues to evaluate the impact of the Updated Lease Guidance on its consolidated financial statements and related disclosures. At this time, the Company has identified that the most significant impacts of the Updated Lease Guidance will be to bring nearly all leases on its balance sheet with “right of use assets” and “lease obligation liabilities” as well as accelerating the interest expense component of financing leases. While the assessment of the impacts arising from this standard is progressing, the Company has not fully determined the impacts on its business processes, controls or financial statement disclosures at this time.

In March 2017, the FASB issued ASU No. 2017-07, “Compensation—Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” (“ASU 2017-07”), which provides guidance to improve the reporting of net benefit cost in the income statement and on the components eligible for capitalization in assets. Under the new guidance, employers will present the service cost component of net periodic benefit cost in the same income statement line item(s) as other employee compensation costs arising from services rendered during the period. Only the service cost component will be eligible for capitalization in assets. Additionally, under this guidance, employers will present the other components of the net periodic benefit cost separately from the line item(s) that includes the service cost and outside of any subtotal of operating income, if one is presented. These components will not be eligible for capitalization in assets. Employers will apply the guidance on the presentation of the components of net periodic benefit cost in the income statement retrospectively. The guidance limiting the capitalization of net periodic benefit cost in assets to the service cost component will be applied prospectively. The guidance includes a practical expedient allowing entities to estimate amounts for comparative periods using the information previously disclosed in their pension and other postretirement benefit plan note to the financial statements. The amendments in this ASU are effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. The Company does not expect the adoption of this new standard to have a material impact on its consolidated financial statements and related disclosures.

In May 2017, the FASB issued ASU No. 2017-09, “Compensation—Stock Compensation (Topic 718): Scope of Modification Accounting” (“ASU 2017-09”), which provides guidance to increase clarity and reduce both diversity in practice and cost and complexity when applying the existing accounting guidance on changes to the terms or conditions of a share-based payment award. The amendments in ASU 2017-09 require an entity to account for the effects of a modification unless all the following are met: (i) the fair value of the modified award is the same as the fair value of the original award immediately before the original award is modified; (ii) the vesting conditions of the modified award are the same as the vesting conditions of the original award immediately before the original award is modified; and (iii) the classification of the modified award as an equity instrument or a liability instrument is the same as the classification of the original award immediately before the original award is modified. The guidance in ASU 2017-09 should be applied prospectively. The amendments in this ASU are effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. The Company will apply the guidance prospectively for any modifications to its stock compensation plans occurring after the effective date of the new standard.

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 through changes to both the designation and measurement guidance for qualifying hedging relationships and the presentation of hedge results in the financial statements. The amendments in ASU 2017-12 address specific limitations in current GAAP by expanding hedge accounting for both nonfinancial and financial risk components and by refining the measurement of hedge results to better reflect an entity’s hedging strategies. Thus, the amendments in ASU 2017-12 will enable an entity to better portray the economic results of hedging activities for certain fair value and cash flow hedges and will avoid mismatches in earnings by allowing for greater precision when measuring changes in fair value of the hedged item for certain fair value hedges. Additionally, by aligning the timing of recognition of hedge results with the earnings effect of the hedged item for cash flow and net investment hedges, and by including the earnings effect of the hedging instrument in the same income statement line item in which the earnings effect of the hedged item is presented, the results of an entity’s hedging program and the cost of executing that program will be more visible to users of financial statements. The guidance in ASU 2017-12 concerning amendments to cash flow and net investment hedge relationships that exist on the date of adoption should be applied using a modified retrospective approach (i.e., with a cumulative effect adjustment recorded to the opening balance of retained earnings as of the initial application date). 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 amendments in this ASU are effective for annual periods beginning after December 15, 2018, including interim periods within those annual periods. The Company is currently evaluating the impact of this new standard on its consolidated financial statements and related disclosures.

In January 2018, the FASB issued ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842 (“ASU 2018-01”). This ASU is discussed above in connection with ASU 2016-02 on leases.