SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

12 Months Ended

Sep. 30, 2017

The Consolidated Financial Statements include the accounts of the Company and its wholly-owned subsidiaries. All intercompany accounts and transactions have been eliminated.

Other financial investments or contractual interests that lack the characteristics of a voting interest entity, which are commonly referred to as variable interest entities, are evaluated by the Company to determine if it has the power to direct business activities and, therefore, would be considered a controlling interest that the Company would have to consolidate. Based on those evaluations, NJR has determined that it does not have any investments in variable interest entities as of September 30, 2017, 2016 and 2015.

Investments in entities over which the Company does not have a controlling financial interest are either accounted for under the equity method or cost method of accounting.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires the Company to make estimates that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosure of contingencies during the reporting period. On a monthly basis, the Company evaluates its estimates, including those related to the calculation of the fair value of derivative instruments, debt, unbilled revenues, allowance for doubtful accounts, provisions for depreciation and amortization, regulatory assets and liabilities, income taxes, pensions and other postemployment benefits, contingencies related to environmental matters and litigation. AROs are evaluated as often as needed. The Company’s estimates are based on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources.

The Company has legal, regulatory and environmental proceedings during the normal course of business that can result in loss contingencies. When evaluating the potential for a loss, the Company will establish a reserve if a loss is probable and can be reasonably estimated, in which case it is the Company’s policy to accrue the full amount of such estimates. Where the information is sufficient only to establish a range of probable liability, and no point within the range is more likely than any other, it is the Company’s policy to accrue the lower end of the range. In the normal course of business, estimated amounts are subsequently adjusted to actual results that may differ from estimates.

Business Combinations

The Company accounts for business combinations by applying the acquisition method of accounting. Identifiable assets acquired and liabilities assumed are measured separately at their fair value as of the acquisition date and associated transactions costs are expensed as incurred.

The determination and allocation of fair values to the identifiable assets acquired and liabilities assumed are based on various assumptions and valuation methodologies requiring considerable management judgment. The most significant variables in these valuations are discount rates, the number of years on which to base the cash flow projections, as well as other assumptions and estimates used to determine the cash inflows and outflows. Management determines discount rates based on the risk inherent in the acquired assets and related cash flows. Our valuation of an acquired business is based on available information at the acquisition date and assumptions that we believe are reasonable. However, a change in facts and circumstances as of the acquisition date can result in subsequent adjustments during the measurement period, but no later than one year from the acquisition date.

Regulatory Assets & Liabilities

Under cost-based regulation, regulated utility enterprises generally are permitted to recover their operating expenses and earn a reasonable rate of return on their utility investment.

Our Natural Gas Distribution segment maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and in accordance with the Regulated Operations Topic of the FASB ASC. As a result of the impact of the ratemaking process and regulatory actions of the BPU, NJNG is required to recognize the economic effects of rate regulation. Accordingly, NJNG capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets.

Gas in Storage

Gas in storage is reflected at average cost on the Consolidated Balance Sheets, and represents natural gas and LNG that will be utilized in the ordinary course of business.

Demand Fees

Energy Services expenses demand charges ratably over the term of the service being provided.

Our Natural Gas Distribution segment’s costs associated with demand charges are included in its weighted average cost of gas. The demand charges are expensed based on NJNG’s BGSS sales and recovered as part of its gas commodity component of its BGSS tariff.

Demand Fees

For the purpose of securing storage and pipeline capacity in support of their respective businesses, our Energy Services and Natural Gas Distribution segments enter into storage and pipeline capacity contracts, which require the payment of associated demand fees and charges that allow them access to a high priority of service in order to maintain the ability to access storage or pipeline capacity during a fixed time period, which generally ranges from one to 10 years. Many of these demand fees and charges are based on established tariff rates as established and regulated by FERC. These charges represent commitments to pay storage providers and pipeline companies for the priority right to transport and/or store natural gas utilizing their respective assets.

Derivative Instruments

The Company accounts for its financial instruments, such as futures, options, foreign exchange contracts, interest rate contracts, as well as its physical commodity contracts related to the purchase and sale of natural gas at Energy Services, as derivatives, and therefore recognizes them at fair value on the Consolidated Balance Sheets. The Company’s unregulated subsidiaries record changes in the fair value of their financial commodity derivatives in gas purchases and changes in the fair value of their physical forward contracts in gas purchases or operating revenues, as appropriate, on the Consolidated Statements of Operations. Energy Services designated its foreign exchange contracts, entered into prior to January 1, 2016, as cash flow hedges of Canadian dollar denominated gas purchases. Changes in the fair value of the effective portion of these hedges are recorded to AOCI, a component of stockholders’ equity, and reclassified to gas purchases on the Consolidated Statements of Operations when they settle. Ineffective portions of the cash flow hedges are recognized immediately in earnings. The Company did not have derivatives designated as fair value hedges during fiscal 2016 and 2017.

The Derivatives and Hedging Topic of the ASC also provides for a NPNS scope exception for qualifying physical commodity contracts that are intended for purchases and sales during the normal course of business and for which physical delivery is probable. Effective January 1, 2016, the Company prospectively applies this normal scope exception on a case-by-case basis to physical commodity contracts at NJNG and forward SREC contracts at Clean Energy Ventures. When applied, it does not record changes in the fair value of these contracts until the contract settles and the related underlying natural gas or SREC is delivered. Gains and/or losses on NJNG’s derivatives used to economically hedge its regulated natural gas supply obligations, as well as its exposure to interest rate variability, are recoverable through its BGSS, a component of its tariff. Accordingly, the offset to the change in fair value of these derivatives is recorded as a regulatory asset or liability on the Consolidated Balance Sheets.

See Note 5. Derivative Instruments for additional details regarding natural gas trading and hedging activities.

Fair values of exchange-traded instruments, including futures, swaps, and certain options, are based on unadjusted, quoted prices in active markets. The Company’s non-exchange-traded financial instruments, foreign currency derivatives, over-the-counter physical commodity contracts at Energy Services and NJNG’s Treasury Lock are valued using observable, quoted prices for similar or identical assets when available. In establishing the fair value of contracts for which a quoted basis price is not available at the measurement date, management utilizes available market data and pricing models to estimate fair values. Fair values are subject to change in the near term and reflect management’s best estimate based on a variety of factors. Estimating fair values of instruments that do not have quoted market prices requires management’s judgment in determining amounts that could reasonably be expected to be received from, or paid to, a third party in settlement of the instruments. These amounts could be materially different from amounts that might be realized in an actual sale transaction.

The Company is subject to commodity price risk due to fluctuations in the market price of natural gas, SRECs and electricity. To manage this risk, the Company enters into a variety of derivative instruments including, but not limited to, futures contracts, physical forward contracts, financial options and swaps to economically hedge the commodity price risk associated with its existing and anticipated commitments to purchase and sell natural gas, SRECs and electricity. In addition, the Company may utilize foreign currency derivatives to hedge Canadian dollar denominated gas purchases and/or sales. Therefore, the Company’s primary underlying risks include commodity prices, interest rates and foreign currency. These contracts, with a few exceptions as described below, are accounted for as derivatives. Accordingly, all of the financial and certain of the Company’s physical derivative instruments are recorded at fair value on the Consolidated Balance Sheets. For a more detailed discussion of the Company’s fair value measurement policies and level disclosures associated with the Company’s derivative instruments, see Note 6. Fair Value.

Energy Services

Energy Services chooses not to designate its financial commodity and physical forward commodity derivatives as accounting hedges or to elect NPNS, and therefore changes in the fair value of these derivatives are recorded as a component of gas purchases or operating revenues, as appropriate for Energy Services, on the Consolidated Statements of Operations as unrealized gains or (losses). For Energy Services at settlement, realized gains and (losses) on all financial derivative instruments are recognized as a component of gas purchases and realized gains and (losses) on all physical derivatives follow the presentation of the related unrealized gains and (losses) as a component of either gas purchases or operating revenues.

Energy Services also enters into natural gas transactions in Canada and, consequently, is exposed to fluctuations in the value of Canadian currency relative to the U.S. dollar. Energy Services may utilize foreign currency derivatives to lock in the exchange rate associated with natural gas transactions denominated in Canadian currency. The derivatives may include currency forwards, futures, or swaps and are accounted for as derivatives. These derivatives are typically used to hedge demand fee payments on pipeline capacity, storage and gas purchase agreements. For transactions occurring on or before December 31, 2015, Energy Services designates its foreign exchange contracts as cash flow hedges, and the effective portion of the hedges are recorded in OCI. Effective January 1, 2016, on a prospective basis, the Company has elected not to designate its foreign currency derivatives as accounting hedges. Accordingly, changes in the fair value of foreign exchange contracts entered into from January 1, 2016, are recognized in gas purchases on the Consolidated Statements of Operations.

As a result of Energy Services entering into transactions to borrow natural gas, commonly referred to as “park and loans,” an embedded derivative is recognized relating to differences between the fair value of the amount borrowed and the fair value of the amount that will ultimately be repaid, based on changes in the forward price for natural gas prices at the borrowed location over the contract term. This embedded derivative is accounted for as a forward sale in the month in which the repayment of the borrowed gas is expected to occur, and is considered a derivative transaction that is recorded at fair value on the Consolidated Balance Sheets, with changes in value recognized in current period earnings.

Expected production of SRECs is hedged through the use of forward and futures contracts. All contracts require the Company to physically deliver SRECs through the transfer of certificates as per contractual settlement schedules. For transactions occurring on or before December 31, 2015, the Company elected NPNS accounting treatment on SREC forward and futures contracts. Effective January 1, 2016, on a prospective basis, Energy Services no longer elects NPNS accounting treatment on SREC contracts entered into from January 1, 2016, and recognizes changes in the fair value of these derivatives as a component of operating revenues. Upon settlement of the contract, the related revenue is recognized when the SREC is transferred to the counterparty. NPNS is a contract-by-contract election and, where it makes sense to do so, we can and may elect certain contracts to be normal.

Natural Gas Distribution

Changes in fair value of NJNG’s financial commodity derivatives are recorded as a component of regulatory assets or liabilities on the Consolidated Balance Sheets. The Company elects NPNS accounting treatment on all physical commodity contracts that NJNG entered into on or before December 31, 2015, and accounts for these contracts on an accrual basis. Accordingly, physical natural gas purchases are recognized in regulatory assets or liabilities on the Consolidated Balance Sheets when the contract settles and the natural gas is delivered. The average cost of natural gas is amortized in current period earnings based on the current BPU BGSS factor and therm sales. Effective January 1, 2016, on a prospective basis, NJNG no longer elects NPNS accounting treatment on all of its physical commodity contracts entered into from January 1, 2016. However, since NPNS is a contract-by-contract election, where it makes sense to do so, we can and may elect certain contracts to be normal. Because NJNG recovers these amounts through future BGSS rates as increases or decreases to the cost of natural gas in NJNG’s tariff for gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Consolidated Balance Sheets.

Revenues

Revenues from the sale of natural gas to NJNG customers are recognized in the period that gas is delivered and consumed by customers, including an estimate for unbilled revenue.

NJNG records unbilled revenue for natural gas services. Natural gas sales to individual customers are based on meter readings, which are performed on a systematic basis throughout the month. At the end of each month, the amount of natural gas delivered to each customer after the last meter reading through the end of the respective accounting period is estimated, and recognizes unbilled revenues related to these amounts. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects, unaccounted-for gas and the most current tariff rates.

Clean Energy Ventures recognizes revenue when SRECs are transferred to counterparties. SRECs are physically delivered through the transfer of certificates as per contractual settlement schedules.

Revenues for Energy Services are recognized when the natural gas is physically delivered to the customer. In addition, changes in the fair value of derivatives that economically hedge the forecasted sales of the natural gas are recognized in operating revenues as they occur, as noted above. Energy Services also recognizes changes in the fair value of SREC derivative contracts as a component of operating revenues.

Revenues from all other activities are recorded in the period during which products or services are delivered and accepted by customers, or over the related contractual term.

Gas Purchases

NJNG’s tariff includes a component for BGSS, which is designed to allow it to recover the cost of natural gas through rates charged to its customers and is typically revised on an annual basis. As part of computing its BGSS rate, NJNG projects its cost of natural gas, net of supplier refunds, the impact of hedging activities and cost savings created by BGSS incentive programs. NJNG subsequently recovers or credits the difference, if any, of actual costs compared with those included in current rates. Any underrecoveries or overrecoveries are either credited to customers or deferred and, subject to BPU approval, reflected in the BGSS rates in subsequent years.

Gas purchases at Energy Services are comprised of gas costs to be paid upon completion of a variety of transactions, as well as realized gains and losses from settled derivative instruments and unrealized gains and losses on the change in fair value of derivative instruments that have not yet settled. Changes in the fair value of derivatives that economically hedge the forecasted purchases of natural gas are recognized in gas purchases as they occur.

Income Taxes

The Company computes income taxes using the asset and liability method, whereby deferred income taxes are generally determined based on the difference between the financial statement and tax basis of assets and liabilities using enacted tax rates in effect in the years in which the differences are expected to reverse. See Note 13. Income Taxes. In addition, the Company evaluates its tax positions to determine the appropriate accounting and recognition of future obligations associated with unrecognized tax benefits.

The Company invests in property that qualifies for federal ITCs and utilizes the ITCs, as allowed, based on the cost and life of the assets. ITCs at NJNG are deferred and amortized as a reduction to the tax provision over the average lives of the related equipment in accordance with regulatory treatment. ITCs at NJR’s unregulated subsidiaries are recognized as a reduction to income tax expense when the property is placed in service. The Company invests in property that qualifies for PTCs. PTCs are recognized as reductions to current federal income tax expense as PTCs are generated through the production activities of the assets. Changes to the federal statutes related to ITCs and PTCs, which have the effect of reducing or eliminating the credits, could have a negative impact on earnings and cash flows.

Capitalized and Deferred Interest

NJNG’s base rates include the ability to recover AFUDC on its construction work in progress. For all NJNG construction projects, an incremental cost of equity is recoverable during periods when NJNG’s short-term debt balances are lower than its construction work in progress. For more information on AFUDC treatment with respect to certain accelerated infrastructure projects, see Note 4. Regulation - Infrastructure programs.

Capitalized amounts associated with the debt and equity components of NJNG’s AFUDC are recorded in utility plant on the Consolidated Balance Sheets. Corresponding amounts for the debt component is recognized in interest expense and in other income for the equity component on the Consolidated Statements of Operations and include the following for the fiscal years ended September 30:



($ in thousands)	2017			2016			2015
AFUDC:
Debt	$	1,311		$	5,009		$	2,472
Equity	3,867			4,375			3,825
Total	$	5,178		$	9,384		$	6,297
Weighted average interest rate	6.90		%	5.06		%	4.63		%

Pursuant to a BPU order, NJNG is permitted to recover carrying costs on uncollected balances related to SBC program costs, which include NJCEP, RAC and USF expenditures.

Sale-Leasebacks

The Company utilizes sale-leaseback arrangements to fund certain of its capital expenditures, whereby the physical asset is sold concurrent with an agreement to lease the asset back, with options that allow the Company to renew the lease at the end of the term or repurchase the asset. Proceeds from sale-leaseback transactions are included in long-term debt on the Consolidated Balance Sheets.

For certain of its commercial solar energy projects, the Company enters into lease agreements that provide for the sale of commercial solar energy assets to third-parties and the concurrent leaseback of the assets. For sale-leaseback transactions where the Company has concluded that the terms of the arrangement create a continuing involvement in the asset and the asset is considered integral equipment, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the lessor that constitute a payment to acquire the solar energy asset as a financing arrangement, which is recorded as a component of debt on the Consolidated Balance Sheets.

During fiscal 2017 and 2016, NJNG received $9.6 million and $7.1 million, respectively, in connection with the sale-leaseback of its natural gas meters with terms ranging from seven to 11 years.

In September 2017, Clean Energy Ventures received $32.9 million in proceeds related to the sale of two commercial solar assets. Clean Energy Ventures simultaneously entered into an agreement to lease the assets back over seven-year terms. The Company will continue to operate the solar assets including related expenses and retain the revenue generated from SRECs and energy sales. The ITCs and other tax benefits associated with these solar projects were transferred to the buyer, however, the lease payments are structured so that Clean Energy Ventures is compensated for the transfer of the related tax incentives. Accordingly, Clean Energy Ventures will recognize the equivalent value of the ITC in other income on the Consolidated Statements of Operations over the respective five-year ITC recapture periods that are recognized as the recapture periods expire, starting at the beginning of the second year of the lease.

Sales Tax Accounting

Sales tax that is collected from customers is presented in both operating revenues and operating expenses on the Consolidated Statements of Operations.

Cash and Cash Equivalents

Cash and cash equivalents consist of cash on deposit and temporary investments with maturities of three months or less, and excludes restricted cash of $243,000 and $1.6 million as of September 30, 2017 and 2016, respectively, related to escrow balances for utility plant projects, which is recorded in other current and noncurrent assets on the Consolidated Balance Sheets.

Property Plant and Equipment

Regulated property, plant and equipment and solar and wind equipment are stated at original cost. Regulated property, plant and equipment costs include direct labor, materials and third-party construction contractor costs, AFUDC and certain indirect costs related to equipment and employees engaged in construction. Upon retirement, the cost of depreciable regulated property, plus removal costs less salvage, is charged to accumulated depreciation with no gain or loss recorded.

Depreciation is computed on a straight-line basis over the useful life of the assets for unregulated assets, and using rates based on the estimated average lives of the various classes of depreciable property for NJNG.

Intangible Assets and Long-Lived Assets

Intangible Assets

Finite-lived intangible assets are stated at cost less accumulated amortization. The Company amortizes intangible assets based upon the pattern in which the economic benefits are consumed over the life of the asset unless a pattern cannot be reliably determined, in which case the Company uses a straight-line amortization method. As of September 30, 2017, the Company has an intangible asset, net of amortization, of $41.1 million related to its acquisition of Talen's wholesale natural gas energy contracts. These contracts are being amortized based upon expected cash flows over the respective terms of the agreements. The estimated future amortization expense for the next five years as of September 30, is as follows:



(Thousands)
2018	$	18,222
2019	$	8,424
2020	$	4,925
2021	$	4,604
2022	$	2,561
Thereafter	$	2,348

See Note 3. Acquisition for more information about the acquisition of Talen's gas marketing business.

Long-lived Assets

The Company reviews the recoverability of long-lived assets and finite-lived intangible assets whenever events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. If there are changes indicating that the carrying value of such assets may not be recoverable, an undiscounted cash flows test is performed. If the sum of the expected future undiscounted cash flows is less than the carrying amount of the asset, an impairment loss is recognized by reducing the recorded value of the asset to its fair value.

Investments in Equity Investees

The Company accounts for its investments in Steckman Ridge, PennEast and Iroquois (through September 29, 2015), using the equity method of accounting, where its respective ownership interests are 50 percent or less and/or it has significant influence over operating and management decisions, but is not the primary beneficiary, as defined under ASC 810, Consolidation. The Company’s share of earnings is recognized as equity in earnings of affiliates on the Consolidated Statements of Operations.

Available for Sale Securities

The Company had investments in two publicly traded energy companies that have a fair value of $65.8 million and $55.8 million as of September 30, 2017 and 2016, respectively, which are included in available for sale securities on the Consolidated Balance Sheets. Total unrealized gains associated with these investments are included as a part of accumulated other comprehensive income, a component of common stock equity, and were $18.4 million, $11 million after tax, and $7.2 million, $4.2 million after tax, as of September 30, 2017 and 2016, respectively.

During fiscal 2017, the Company received proceeds of approximately $6.6 million from the sale of available for sale securities and realized a pre-tax gain of approximately $5.4 million, which is included in other income, net on the Consolidated Statements of Operations. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.

Customer Accounts Receivable and Allowance for Doubtful Accounts and Loan Receivable

Customer Accounts Receivable and Allowance for Doubtful Accounts

Receivables consist of natural gas sales and transportation services billed to residential, commercial, industrial and other customers, as well as equipment sales, installations, solar leases and PPAs to commercial and residential customers. The Company evaluates its accounts receivables and, to the extent customer account balances are outstanding for more than 60 days, establishes an allowance for doubtful accounts. The allowance is based on a combination of factors including historical collection experience and trends, aging of receivables, general economic conditions in the company’s distribution or sales territories, and customer specific information. The Company writes-off customers’ accounts once it is determined they are uncollectible.

The following table summarizes customer accounts receivable by company as of September 30:



(Thousands)	2017				2016
Energy Services	$	150,322	77	%	$	102,884	72	%
NJNG ⁽¹⁾	37,432		19		30,951		22
Clean Energy Ventures	2,655		1		1,807		1
NJRHS and other	6,058		3		7,016		5
Total	$	196,467	100	%	$	142,658	100	%


(1)	Does not include unbilled revenues of $7.2 million and $5.7 million as of September 30, 2017 and 2016, respectively.

Loans Receivable

NJNG currently provides loans, with terms ranging from three to 10 years, to customers that elect to purchase and install certain energy efficient equipment in accordance with its BPU-approved SAVEGREEN program. The loans are recognized at net present value on the Consolidated Balance Sheets. Refer to Note 6. Fair Value for a discussion of the Company’s fair value measurement policies and level disclosures. The Company has recorded $8.9 million and $7.8 million in other current assets and $40.4 million and $39.5 million in other noncurrent assets as of September 30, 2017 and 2016, respectively, on the Consolidated Balance Sheets, related to the loans.

NJNG’s policy is to establish an allowance for doubtful accounts when loan balances are in arrears for more than 60 days.

Asset Retirement Obligations

The Company recognizes a liability for its AROs based on the fair value of the liability when incurred, which is generally upon acquisition, construction, development and/or through the normal operation of the asset. Concurrently, the Company also capitalizes an asset retirement cost by increasing the carrying amount of the related asset by the same amount as the liability. In periods subsequent to the initial measurement, the Company is required to recognize changes in the liability resulting from the passage of time (accretion) or due to revisions to either timing or the amount of the originally estimated cash flows to settle the conditional ARO.

Pension and Postemployment Plans

The Company has two noncontributory defined pension plans covering eligible employees, including officers. Benefits are based on each employee’s years of service and compensation. The Company’s funding policy is to contribute annually to these plans at least the minimum amount required under Employee Retirement Income Security Act, as amended, and not more than can be deducted for federal income tax purposes. Plan assets consist of equity securities, fixed-income securities and short-term investments. The Company made a discretionary contribution of $30 million during the first quarter of fiscal 2016 to improve the funded status of the pension plans based on the current actuarial assumptions, which included the adoption of the most recent mortality table. The Company made no discretionary contributions to the pension plans in fiscal 2017 and 2015.

The Company also provides two primarily noncontributory medical and life insurance plans for eligible retirees and dependents. Medical benefits, which make up the largest component of the plans, are based upon an age and years-of-service vesting schedule and other plan provisions. Funding of these benefits is made primarily into Voluntary Employee Beneficiary Association trust funds.

Foreign Currency Transactions

Energy Services’ market area includes Canadian delivery points and as a result, Energy Services incurs certain natural gas commodity costs and demand fees denominated in Canadian dollars. Gains or losses that occur as a result of these foreign currency transactions are reported as a component of gas purchases on the Consolidated Statements of Operations and were not material during the fiscal years ended September 30, 2017, 2016 and 2015.

Recent Updates to the Accounting Standards Codification

Recently Adopted Updates to the Accounting Standards Codification

Stock Compensation

In June 2014, the FASB issued ASU No. 2014-12, an amendment to ASC 718, Compensation - Stock Compensation, which clarifies the accounting for performance awards when the terms of the award provide that a performance target could be achieved after the requisite service period. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.

Consolidation

In February 2015, the FASB issued ASU No. 2015-02, an amendment to ASC 810, Consolidation, which changes the consolidation analysis required under GAAP and reevaluates whether limited partnerships and similar entities must be consolidated. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a full retrospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.

Interest

In April 2015, the FASB issued ASU No. 2015-03, an amendment to ASC 835, Interest - Imputation of Interest, which simplifies the presentation of debt issuance costs by requiring them to be presented on the balance sheet as a deduction from the carrying amount of the liability. The amendment does not affect the recognition and measurement guidance for debt issuance costs. In August 2015, the FASB issued ASU No. 2015-15, which clarified that the amendment contained within ASU No. 2015-03 does not require companies to modify their accounting for costs incurred in obtaining revolving credit facilities. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a full retrospective basis.

In addition, the following amounts on the Consolidated Balance Sheets have been adjusted, retrospectively, as of September 30, 2016.



(Thousands)	As Previously Reported		Effect of Change			As Adjusted
Assets
Other noncurrent assets	$	68,708	$	(8,512	)	$	60,196
Total noncurrent assets	$	712,166	$	(8,512	)	$	703,654
Total assets	$	3,727,082	$	(8,512	)	$	3,718,570
Capitalization and Liabilities
Long-term debt	$	1,063,550	$	(8,512	)	$	1,055,038
Total capitalization	$	2,230,141	$	(8,512	)	$	2,221,629
Total capitalization and liabilities	$	3,727,082	$	(8,512	)	$	3,718,570

Intangibles

In April 2015, the FASB issued ASU No. 2015-05, an amendment to ASC 350, Intangibles - Goodwill and Other - Internal-Use Software, which clarifies the accounting for fees in a cloud computing arrangement. The amendment provides guidance on how an entity should evaluate the accounting for fees paid in a cloud computing arrangement to determine whether an arrangement includes the sale or license of software. The Company adopted the new guidance in the first quarter of fiscal 2017 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption.

Other Recent Updates to the Accounting Standards Codification

Revenue

In May 2014, the FASB issued ASU No. 2014-09, and added Topic 606, Revenue from Contracts with Customers, to the ASC. ASC 606 supersedes ASC 605, Revenue Recognition, as well as most industry-specific guidance, and prescribes a single, comprehensive revenue recognition model designed to improve financial reporting comparability across entities, industries, jurisdictions and capital markets. In August 2015, the FASB issued ASU No. 2015-14, which defers the implementation of the new guidance for one year. The new guidance will not be early adopted and will be effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year. The Company continues to evaluate the provisions of ASC 606; however, based on the review of customer contracts to date, it is not anticipating a material impact to its financial position, results of operations or cash flows upon adoption. The Company anticipates significant new disclosures as a result of the new standard and expects to transition to the new guidance using the modified retrospective approach. The Company is also monitoring industry specific developments that may have an impact on its financial position, results of operation and cash flows.

Inventory

In July 2015, the FASB issued ASU No. 2015-11, an amendment to ASC 330, Inventory, which requires entities to measure most inventory “at the lower of cost or net realizable value,” thereby simplifying the current guidance under which an entity must measure inventory at the lower of cost or market. The guidance is effective for the Company’s fiscal year ending September 30, 2018, and interim periods within that year. Upon adoption, the amendment will be applied on a prospective basis. The Company does not expect any impact on its financial position, results of operations and cash flows upon adoption.

Financial Instruments

In January 2016, the FASB issued ASU No. 2016-01, an amendment to ASC 825, Financial Instruments, to address certain aspects of the recognition, measurement, presentation and disclosure of financial instruments. The standard affects investments in equity securities that do not result in consolidation and are not accounted for under the equity method and the presentation of certain fair value changes for financial liabilities measured at fair value. It also simplifies the impairment assessment of equity investments without a readily determinable fair value by requiring a qualitative assessment. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year. Upon adoption, the amendment will be applied on a modified retrospective basis. The Company evaluated the amendment and noted that, upon adoption, subsequent changes to the fair value of the Company’s available for sale securities will be recorded in the Consolidated Statement of Operations as opposed to other comprehensive income. The Company does not expect any other material impacts to its financial position, results of operations or cash flows upon adoption.

In June 2016, the FASB issued ASU No. 2016-13, an amendment to ASC 326, Financial Instruments - Credit Losses, which changes the impairment model for certain financial assets that have a contractual right to receive cash, including trade and loan receivables. The new model requires recognition based upon an estimation of expected credit losses rather than recognition of losses when it is probable that they have been incurred. The guidance is effective for the Company’s fiscal year ending September 30, 2021, and interim periods within that year, with early adoption permitted. The Company is currently evaluating the amendment to understand the impact on its financial position, results of operations and cash flows upon adoption and will apply the new guidance to its trade and loan receivables on a modified retrospective basis.

Leases

In February 2016, the FASB issued ASU No. 2016-02, an amendment to ASC 842, Leases, which provides for a comprehensive overhaul of the lease accounting model and changes the definition of a lease within the accounting literature. Under the new standard, all leases with a term greater than one year will be recorded on the balance sheet. Amortization of the related asset will be accounted for using one of two approaches prescribed by the guidance. Additional disclosures will be required to allow the user to assess the amount, timing and uncertainty of cash flows arising from leasing activities. A modified retrospective transition approach is required for leases existing at the time of adoption. The guidance is effective for the Company’s fiscal year ending September 30, 2020, and interim periods within that year, with early adoption permitted. The Company continues to evaluate the provisions of ASC 842 and is actively monitoring industry specific developments including the exposure draft issued by the FASB that would introduce a land easement practical expedient to ASC 842. At this time the Company does not plan to early adopt the new guidance and expects to elect the practical expedient package in the new guidance during transition.

Statement of Cash Flows

In August 2016, the FASB issued ASU No. 2016-15, an amendment to ASC 230, Statement of Cash Flows, which addresses eight specific cash flow issues for which there has been diversity in practice. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis. The Company does not expect any material impacts to its cash flows upon adoption.

In November 2016, the FASB issued ASU No. 2016-18, an amendment to ASC 230, Statement of Cash Flows, which requires that any amounts that are deemed to be restricted cash or restricted cash-equivalents be included in cash and cash-equivalent balances on the cash flow statement and, therefore, transfers between cash and restricted cash accounts will no longer be recognized within the statement of cash flows. The guidance is effective for the Company’s fiscal year ending September 30, 2019, with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis. Based on the Company's historical restricted cash balances, it does not expect any material impacts to its financial position, results of operations or cash flows upon adoption.

Business Combinations

In January 2017, the FASB issued ASU No. 2017-01, an amendment to ASC 805, Business Combinations, clarifying the definition of a business in the ASC, which is intended to reduce the complexity surrounding the assessment of a transaction as an asset acquisition or business combination. The amendment provides an initial fair value screen to reduce the number of transactions that would fit the definition of a business, and when the screen threshold is not met, provides an updated model that further clarifies the characteristics of a business. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year, with early adoption permitted. Upon adoption, the amendment will be applied on a prospective basis. The amendment could potentially have material impacts on future transactions that the Company may enter into by altering the Company’s conclusion on what accounting to apply to acquisitions.

Gains and Losses from the Derecognition of Nonfinancial Assets

In February 2017, the FASB issued ASU No. 2017-05, an amendment to ASC 610-20, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets, which clarifies the scope and accounting related to the derecognition of nonfinancial assets, including partial sales and contributions of nonfinancial assets to a joint venture or other non-controlled investee. The guidance is effective concurrently with ASC 606, which is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year with early adoption permitted. ASU No. 2017-05 may be applied retrospectively for all periods presented or retrospectively with a cumulative-effect adjustment at the date of adoption. The Company has determined that to the extent a deferred gain exists related to nonfinancial assets on the balance sheet upon adoption, it would be recognized under the new accounting guidance as a cumulative effect adjustment to the opening balance of retained earnings for the earliest period presented.

Compensation - Retirement Benefits

In March 2017, the FASB issued ASU No. 2017-07, an amendment to ASC 715, Compensation - Retirement Benefits, which changes the presentation of net periodic benefit cost on the income statement by requiring companies to present all components of net periodic benefit cost, other than service cost, outside a subtotal of income from operations. The amendment also states that only the service cost component of net periodic benefits costs is eligible for capitalization, when applicable. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year, with early adoption permitted. Upon adoption, the amendment will be applied on a retrospective basis for presentation and changes to capitalization of costs will be applied on a prospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on its financial position, results of operations and cash flows upon adoption. The Company is also monitoring industry specific developments on the new guidance to determine the appropriate treatment of these changes in a rate regulated environment.

Stock Compensation

In May 2017, the FASB issued ASU No. 2017-09, an amendment to ASC 718, Compensation - Stock Compensation, which clarifies the accounting for changes to the terms or conditions of share-based payments. The guidance is effective for the Company’s fiscal year ending September 30, 2019, and interim periods within that year, with early adoption permitted. Upon adoption, the amendments will be applied prospectively to awards modified on or after the adoption date. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations and cash flows upon adoption.

Derivatives and Hedging

In August 2017, the FASB issued ASU No. 2017-12, an amendment to ASC 815, Derivatives and Hedging, which is intended to make targeted improvements to the accounting for hedging activities by better aligning an entity’s risk management activities and financial reporting for hedging relationships. These amendments modify the accounting for both nonfinancial and financial risk components and align the recognition and presentation of the effects of the hedging instrument and the hedged item in the financial statements. Additionally, the amendments are intended to simplify the application of the hedge accounting guidance and provide relief to companies by easing certain hedge documentation requirements. The guidance is effective for the Company’s fiscal year ending September 30, 2020, and interim periods within that year, with early adoption permitted. Upon adoption, the transition requirements and elections will be applied to hedging relationships existing on the date of adoption. The Company does not currently apply hedge accounting to any of its risk management activities and thus does not expect the amendments to have any impact on its financial position, results of operations and cash flows upon adoption.

Fair Value Hierarchy

The Company applies fair value measurement guidance to its financial assets and liabilities, as appropriate, which include financial derivatives and physical commodity contracts qualifying as derivatives, available for sale securities and other financial assets and liabilities. In addition, authoritative accounting literature prescribes the use of a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value based on the source of the data used to develop the price inputs.

The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to inputs that are based on unobservable market data and includes the following:

Level 1

Unadjusted quoted prices for identical assets or liabilities in active markets. The Company’s Level 1 assets and liabilities include exchange traded natural gas futures and options contracts, listed equities and money market funds. Exchange traded futures and options contracts include all energy contracts traded on the NYMEX, CME and ICE that the Company refers internally to as basis swaps, fixed swaps, futures and financial options that are cleared through a FCM.

Level 2

Other significant observable inputs, such as interest rates or price data, including both commodity and basis pricing that is observed either directly or indirectly from publications or pricing services. The Company’s Level 2 assets and liabilities include over-the-counter physical forward commodity contracts and swap contracts, SREC forward sales or derivatives that are initially valued using observable quotes and are subsequently adjusted to include time value, credit risk or estimated transport pricing components for which no basis price is available. Level 2 financial derivatives consist of transactions with non-FCM counterparties (basis swaps, fixed swaps and/or options). NJNG’s treasury lock is also considered Level 2 as valuation is based on quoted market interest and swap rates as inputs to the valuation model. Inputs are verifiable and do not require significant management judgment. For some physical commodity contracts, the Company utilizes transportation tariff rates that are publicly available and that it considers to be observable inputs that are equivalent to market data received from an independent source. There are no significant judgments or adjustments applied to the transportation tariff inputs and no market perspective is required. Even if the transportation tariff input were considered to be a “model,” it would still be considered to be a Level 2 input as the data is:


•	widely accepted and public;


•	non-proprietary and sourced from an independent third party; and


•	observable and published.

These additional adjustments are generally not considered to be significant to the ultimate recognized values.


Level 3	Inputs derived from a significant amount of unobservable market data. These include the Company’s best estimate of fair value and are derived primarily through the use of internal valuation methodologies.

Financial derivative portfolios of NJNG and Energy Services consist mainly of futures, options and swaps. The Company primarily uses the market approach and its policy is to use actively quoted market prices when available. The principal market for its derivative transactions is the natural gas wholesale market, therefore, the primary sources for its price inputs are CME, NYMEX and ICE. Energy Services uses Platts and Natural Gas Exchange for Canadian delivery points. However, Energy Services also engages in transactions that result in transporting natural gas to delivery points for which there is no actively quoted market price. In most instances, the transportation cost to the final delivery location is not significant to the overall valuation. If required, Energy Services’ policy is to use the best information available to determine fair value based on internal pricing models, which would include estimates extrapolated from broker quotes or other pricing services.

The Company also has available for sale securities and other financial assets that include listed equities, mutual funds and money market funds for which there are active exchange quotes available.

When the Company determines fair values, measurements are adjusted, as needed, for credit risk associated with its counterparties, as well as its own credit risk. The Company determines these adjustments by using historical default probabilities that correspond to the applicable S&P issuer ratings, while also taking into consideration collateral and netting arrangements that serve to mitigate risk.