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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies) | 12 Months Ended
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Sep. 30, 2018
Accounting Policies [Abstract] |
Principles of Consolidation | Principles of Consolidation 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 the entity 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, 2018, 2017 and 2016. 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 | 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 quarterly basis or more frequently whenever events or changes in circumstances indicate a need, the Company evaluates its estimates, including those related to the calculation of the fair value of derivative instruments, debt, investments, unbilled revenues, allowance for doubtful accounts, provisions for depreciation and amortization, long-lived assets, 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 | 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 and 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.
Revenues | 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 | 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 composed 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.
Demand Fees | Demand Fees For the purpose of securing storage and pipeline capacity in support of their respective businesses, the 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. The following table summarizes the demand charges, which are net of capacity releases, and are included as a component of gas purchases on the Consolidated Statements of Operations for the fiscal years ended September 30:
(Millions) | 2018 | 2017 | 2016
Energy Services | $ | 153.0 |  | $ | 126.4 |  | $ | 141.0 |
Natural Gas Distribution | 92.5 |  | 80.2 |  | 77.8 |
Total | $ | 245.5 |  | $ | 206.6 |  | $ | 218.8 |
Energy Services expenses demand charges over the term of the service being provided. The 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.
Operations and Maintenance Expenses | Operations and Maintenance Expenses Operations and maintenance expenses include operations and maintenance salaries and benefits, materials and supplies, usage of vehicles, tools and equipment, payments to contractors, utility plant maintenance, customer service, professional fees and other outside services, insurance expense, accretion of cost of removal for future retirements of utility assets and other administrative expenses and are expensed as incurred. Stock-Based Compensation Stock-based compensation represents costs related to stock-based awards granted to employees and NJR Board of Directors members. NJR recognizes stock-based compensation based upon the estimated fair value of awards. The recognition period for these costs begins at either the applicable service inception date or grant date and continues throughout the requisite service period. The related compensation cost is recognized as O&M expense on the Consolidated Statements of Operations. See Note 9. Stock-Based Compensation for further information.
Sales Tax Accounting | 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. During fiscal 2018, 2017 and 2016, sales tax collected was $41.7 million, $39.4 million and $31 million, respectively. Effective January 1, 2017, the New Jersey sales tax rate decreased from 7 percent to 6.875 percent. Effective January 1, 2018, the New Jersey sales tax rate decreased again to 6.625 percent.
Income Taxes | 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 12. 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 the unregulated subsidiaries of NJR 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.
Investments in Equity Investees | Investments in Equity Investees The Company accounts for its investments in Steckman Ridge and PennEast, 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. See Note 6. Investments in Equity Investees for more information.
Property Plant and Equipment | Property Plant and Equipment Regulated property, plant and equipment is stated at original cost. Costs include direct labor, materials and third-party construction contractor costs, AFUDC and certain indirect costs related to equipment and employees engaged in construction. Nonregulated property, plant and equipment is stated at original cost. Costs include direct labor, materials and third-party construction contractor costs and certain indirect costs related to equipment and employees engaged in construction. Upon retirement, the cost of depreciable 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 entities, and using rates based on the estimated average lives of the various classes of depreciable property for NJNG.
Capitalized and Deferred Interest | 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 3. 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 are recognized in interest expense and in other income for the equity component on the Consolidated Statements of Operations.
Cash and Cash Equivalents | 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 $252,000 and $243,000 as of September 30, 2018 and 2017, respectively, related to escrow balances for utility plant projects, which is recorded in other current and noncurrent assets on the Consolidated Balance Sheets.
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 customer accounts once it is determined they are uncollectible. The following table summarizes customer accounts receivable by company as of September 30:
(Thousands) | 2018 |  | 2017
Energy Services | $ | 157,936 |  | 77 | % |  | $ | 150,322 |  | 77 | %
Natural Gas Distribution (1) | 39,151 |  | 19 |  |  | 37,432 |  | 19 |
Clean Energy Ventures | 3,330 |  | 2 |  |  | 2,655 |  | 1 |
Home Services and Other Operations | 5,073 |  | 2 |  |  | 6,058 |  | 3 |
Total | $ | 205,490 |  | 100 | % |  | $ | 196,467 |  | 100 | %
(1) | Does not include unbilled revenues of $7.2 million as of September 30, 2018 and 2017.
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. The Company has recorded $10.4 million and $8.9 million in other current assets and $39.5 million and $40.4 million in other noncurrent assets as of September 30, 2018 and 2017, respectively, on the Consolidated Balance Sheets, related to the loans. If NJNG determines a loan is impaired, the basis of the loan would be subject to regulatory review for recovery. As of September 30, 2018 and 2017, the Company has not recorded an allowance for doubtful accounts for SAVEGREEN loans.
Regulatory Assets & Liabilities | Regulatory Assets & Liabilities Under cost-based regulation, regulated utility enterprises generally are permitted to recover their operating expenses and earn a reasonable rate of return on their utility investment. Our Natural Gas Distribution segment maintains its accounts in accordance with the FERC Uniform System of Accounts as prescribed by the BPU and in accordance with the ASC 980, Regulated Operations. As a result of the impact of the ratemaking process and regulatory actions of the BPU, NJNG is required to recognize the economic effects of rate regulation. Accordingly, NJNG capitalizes or defers certain costs that are expected to be recovered from its customers as regulatory assets and recognizes certain obligations representing probable future expenditures as regulatory liabilities on the Consolidated Balance Sheets. See Note 3. Regulation for a more detailed description of NJNG’s regulatory assets and liabilities.
Gas in Storage | Gas in Storage Gas in storage is reflected at average cost on the Consolidated Balance Sheets and represents natural gas and LNG that will be utilized in the ordinary course of business. The following table summarizes gas in storage, at average cost by company, as of September 30:
| 2018 | 2017
($ in thousands) | Gas in Storage |  | Bcf | Gas in Storage |  | Bcf
Energy Services |  | $ | 90,166 |  | 34.1 |  |  | $ | 122,884 |  | 53.9 |
Natural Gas Distribution |  | 94,467 |  | 24.9 |  |  | 79,179 |  | 21.8 |
Total |  | $ | 184,633 |  | 59.0 |  |  | $ | 202,063 |  | 75.7 |
Derivative Instruments | Derivative Instruments The Company accounts for its financial instruments, such as futures, options, foreign exchange contracts and 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. Ineffective portions of the cash flow hedges are recognized immediately in earnings. The ASC 815, Derivatives and Hedging 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 4. Derivative Instruments for additional details regarding natural gas trading and hedging activities. Fair values of exchange-traded instruments, including futures and swaps, 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 interest rate contracts 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 5. 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. The 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. 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, NJNG 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.
Assets Held for Sale | Assets Held for Sale The Company classifies an asset as held for sale if there is a commitment to sell the asset, the asset is available for immediate sale, the sale is probable and the sale will be completed within one year. In March 2018, Clean Energy Ventures committed to a plan to sell its wind assets and expects that the sale will be completed within the next 12 months. Accordingly, the Company classified its wind assets and related liabilities as held for sale on the Consolidated Balance Sheets, which resulted in depreciation expense on wind assets no longer being recorded. The wind assets classified as held for sale are measured at the lower of their carrying value or fair value less cost to sell. At September 30, 2018, the Company performed a fair value assessment of its wind assets held for sale. The Company equally weighted the valuation derived from an income approach and a market approach to determine fair value. The Company believes that the estimates and assumptions used in calculating the fair value of our assets and liabilities held for sale are reasonable and appropriate based on the information that was known when the estimates were made. The Company concluded that the fair value of the wind assets was greater than the carrying value and thus no impairment was recorded.
Available for Sale Securities | Available for Sale Securities Available for sale securities are carried at fair value on the Consolidated Balance Sheets. For fiscal years ended September 30, 2018 and prior, total unrealized gains and losses associated are included as a part of accumulated other comprehensive income, a component of common stock equity. Reclassifications of realized gains or losses out of other comprehensive income into earnings are recorded in other income, net on the Consolidated Statements of Operations based on average cost. Management evaluates its equity securities for other-than-temporary impairment on a quarterly basis, and more frequently when economic, market or other concerns warrant such evaluation. Consideration is given to the length of time and the extent to which the fair value has been less than cost; the financial condition and near term prospects of the issuer; whether the market decline was affected by macroeconomic conditions, changes in tax laws, regulations or other governmental policies; and whether the Company has the intent to sell the security or more likely than not will be required to sell the security before the recovery of its amortized cost basis. If the decline in value of our equity securities is determined to be other-than-temporary, an impairment is recognized through earnings within other income, net on the Consolidated Statements of Operations. During fiscal 2018, NJR sold shares of its available for sale securities and received proceeds of approximately $6.6 million and realized a pre-tax gain of approximately $5.3 million, which is included in other income, net on the Consolidated Statements of Operations, or $3.2 million, net of tax. During fiscal 2017, NJR received proceeds of approximately $6.6 million and realized a pre-tax gain of $5.4 million, or $3.2 million, net of tax. Reclassifications of realized gains out of other comprehensive income into income are determined based on average cost.
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, 2018, intangible assets consist of internal-use software costs of $513,000 and $22.9 million, net of amortization, 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) |
2019 | $ | 8,424 |
2020 | $ | 4,925 |
2021 | $ | 4,604 |
2022 | $ | 2,561 |
2023 | $ | 2,271 |
Thereafter | $ | 77 |
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 may not be recoverable, such as significant adverse changes in regulation, business climate or market conditions, including prolonged periods of adverse commodity and capacity prices. 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. During the year, the Company evaluated whether there were such events or circumstances that occurred, including evaluation of the new clean energy legislation signed in May 2018, and concluded that there were no events or circumstances in the current year that indicated that the carrying value of long-lived assets or finite-lived intangibles is not recoverable.
Debt Issuance Costs | Debt Issuance Costs Debt issuance costs are capitalized and amortized as interest expense on a basis which approximates the effective interest method over the term of the related debt. Debt issuance costs are presented as a direct deduction from the carrying amount of the related debt. See Note 8. Debt for the total unamortized debt issuance costs that are recorded as a reduction to long-term debt on the Consolidated Balance Sheets.
Sale-Leasebacks | Sale-Leasebacks NJNG utilizes sale-leaseback arrangements as a financing mechanism to fund certain of its capital expenditures related to natural gas meters, whereby the physical asset is sold concurrent with an agreement to lease the asset back. These agreements include options to renew the lease at the end of the term or repurchase the asset. Proceeds from sale-leaseback transactions are accounted for as financings and are included in long-term debt on the Consolidated Balance Sheets. During fiscal 2018 and 2017, NJNG received $7.8 million and $9.6 million, respectively, in connection with the sale-leaseback of its natural gas meters with terms ranging from seven to 11 years. In addition, 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. Clean Energy Ventures received $71.5 million and $32.9 million in proceeds related to the sale of commercial solar assets during fiscal 2018 and 2017, respectively. Clean Energy Ventures simultaneously entered into agreements to lease the assets back over six to 15-year terms. The Company will continue to operate the solar assets and is responsible for related expenses and entitled to retain the revenue generated from SRECs and energy sales. The ITCs and other tax benefits associated with these solar projects have been 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 recognizes the equivalent value of the ITC in other income on the Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. Clean Energy Ventures did not enter into sale-leaseback during fiscal 2016 and therefore recognized the full ITC in income tax (benefit) provision on the Consolidated Statements of Operations when the assets were placed in service.
Environmental Contingencies | Environmental Contingencies Loss contingencies are recorded as liabilities when it is probable a liability has been incurred and the amount of the loss is reasonably estimable in accordance with accounting standards for contingencies. Estimating probable losses requires an analysis of uncertainties that often depend upon judgments about potential actions by third parties. Accruals for loss contingencies are recorded based on an analysis of potential results. With respect to environmental liabilities and related costs, NJNG periodically, and at least annually, performs an environmental review of the MGP sites, including a review of potential liability for investigation and remedial action. NJNG’s estimate of these liabilities is based upon known facts, existing technology and enacted laws and regulations in place when the review was completed. Where it is probable that costs will be incurred, and the information is sufficient to establish a range of possible liability, NJNG accrues the most likely amount in the range. If no point within the range is more likely than the other, it is NJNG’s policy to accrue the lower end of the range. The actual costs to be incurred by NJNG are dependent upon several factors, including final determination of remedial action, changing technologies and governmental regulations, the ultimate ability of other responsible parties to pay and any insurance recoveries. NJNG will continue to seek recovery of MGP-related costs through the RAC. If any future regulatory position indicates that the recovery of such costs is not probable, the related non-recoverable costs would be charged to income in the period of such determination. See Note 13. Commitments and Contingent Liabilities for more details.
Pension and Postemployment Plans | 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 the 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 2018 and 2017. 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.
Asset Retirement Obligations | Asset Retirement Obligations The Company recognizes AROs related to the costs associated with cutting and capping NJNG’s main and service gas distribution mains, which is required by New Jersey law when taking such gas distribution mains out of service. The Company also recognizes AROs associated with Clean Energy Ventures’ solar and wind assets when there are decommissioning provisions in lease agreements that require removal of the asset at the end of the lease term. AROs are initially recognized when the legal obligation to retire an asset has been incurred and a reasonable estimate of fair value can be made. The discounted fair value is recognized as an ARO liability with a corresponding amount capitalized as part of the carrying cost of the underlying asset. The obligation is subsequently accreted to the future value of the expected retirement cost and the corresponding asset retirement cost is depreciated over the life of the related asset. Accretion expense associated with Clean Energy Ventures’ ARO is recognized as a component of operations and maintenance expense on the Consolidated Statements of Operations. Accretion amounts associated with NJNG’s ARO are recognized as part of its depreciation expense and the corresponding regulatory asset and liability will be shown gross on the Consolidated Balance Sheets. Estimating future removal costs requires management to make significant judgments because most of the removal obligations span long time frames and removal may be conditioned upon future events. Asset removal technologies are also constantly changing, which makes it difficult to estimate removal costs. Accordingly, inherent in the estimate of AROs are various assumptions including the ultimate settlement date, expected cash outflows, inflation rates, credit-adjusted risk-free rates and consideration of potential outcomes where settlement of the ARO can be conditioned upon events. In the latter case, the Company develops possible retirement scenarios and assign probabilities based on management’s reasonable judgment and knowledge of industry practice. Accordingly, AROs are subject to change.
Foreign Currency Transactions | Foreign Currency Transactions The market area of Energy Services 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. Gains and losses recognized for the fiscal years ended September 30, 2018, 2017 and 2016, are considered immaterial.
Recent Updates to the Accounting Standards Codification | Recently Adopted Updates to the Accounting Standards Codification 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 Company adopted the new guidance in the first quarter of fiscal 2018 and applied the new provisions on a prospective basis, which did not impact its financial position, results of operations or cash flows upon adoption. Reporting Comprehensive Income In February 2018, the FASB issued ASU No. 2018-02, an amendment to ASC 220, Income Statement - Reporting Comprehensive Income, which allows for the reclassification from accumulated other comprehensive income to retained earnings for the disproportionate tax effects of the Tax Act. The Company early adopted this guidance in the fourth quarter of fiscal 2018 and reclassified on a prospective basis only, $3.3 million from accumulated other comprehensive income to retained earnings. This did not materially impact the Company’s financial position, results of operations or cash flows. Tax In March 2018, the FASB issued ASU No. 2018-05, an amendment to ASC 740, Income Taxes, which provides relief to entities in their calculation of the effects of the Tax Act by allowing them to record provisional amounts for certain income tax effects to address circumstances in which an entity does not have the necessary information available, prepared or analyzed to complete the accounting. These provisional amounts are subject to change as information and assumptions are updated throughout the measurement period, which may not extend beyond one year from the enactment date. The new guidance was effective immediately upon issuance, and the Company adopted the new guidance in the second quarter of fiscal 2018 and applied the new provision on a prospective basis. Other Recent Updates to the Accounting Standards Codification Revenue In May 2014, the FASB issued ASU No. 2014-09, and added ASC 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. The Company adopted the new guidance on October 1, 2018, and will apply the new provisions on a modified retrospective basis. Management established an implementation team to evaluate the impact on the Company’s financial position, results of operations and cash flows upon adoption of ASC 606. This implementation team reviewed the revenue streams of all of its subsidiaries and formed conclusions to determine if any system, process, controls and organizational changes are necessary upon adoption. The assessment of the impact of this guidance included reviewing the Company’s accounting policies under ASC 605 and identifying potential differences after the adoption of ASC 606. The Company concluded that its tariff-based sales of natural gas will be within the scope of the new guidance and it does not anticipate any modification to the pattern of revenue recognition from such sales. Revenues from derivative instruments such as those related to the Company’s SREC sales and natural gas purchases and sales will continue to be accounted for under ASC 815 and thus are outside the scope of ASC 606. Additionally, NJNG revenues generated by the CIP have been determined to be alternative revenue programs under ASC 980 and are also outside the scope of ASC 606 as they are deemed to be a contract with the regulator. The Company also evaluated its renewable asset PPA arrangements and does not anticipate any modification to the pattern of revenue recognition of the related electricity, capacity and REC sales. Revenues from RECs sold as part of a bundled arrangement will be recognized in the same period as the related generation, consistent with current practice. The Company has completed its evaluation of its revenue streams, and based on the assessment performed, has concluded that the new guidance will not have a material impact on its financial position, results of operations or cash flows upon adoption. Additionally, the Company did not implement significant changes to its business processes, systems or internal controls over financial reporting upon adoption. ASC 606 requires expanded disclosures, including the disclosure of performance obligations, disaggregated revenues and contract balances, which the Company will include in its financial statements beginning in the first quarter of fiscal 2019. 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 beginning October 1, 2018. 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 will reclassify $3.4 million in accumulated other comprehensive income related to available for sale securities to the opening balance of retained earnings as of October 1, 2018. There will be no material impact to the Company’s 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. An entity will apply the amendment through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The guidance is effective for the Company beginning October 1, 2020, 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. In January 2018, the FASB issued ASU No. 2018-01, a further amendment to ASC 842, Leases, which was introduced by ASU No. 2016-02, as discussed above. This update provides an optional practical expedient that allows companies to not evaluate existing or expired land easements that were not previously accounted for under Topic 840 as leases. The Company expects to elect this practical expedient upon adoption. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. In July 2018, the FASB issued ASU No. 2018-11, which provides an optional transition method to ASC 842 that allows the Company to recognize a cumulative effect adjustment to the opening balance of retained earnings in the period of adoption. At this time, the Company does not plan to early adopt the new guidance and expects to transition on a modified retrospective basis. While the Company is currently evaluating the full impact of the standard and its related updates, it expects to recognize additional assets and liabilities arising from current operating leases to its financial position upon adoption. Current operating leases primarily consist of office and land leases related to the Company’s solar and wind assets. 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 beginning October 1, 2018. The amendment will be applied on a retrospective basis and the Company does not expect any material impacts to its statement of cash flows. 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 beginning October 1, 2018, and 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 statement of cash flows. Intangibles In August 2018, the FASB issued ASU No. 2018-15, an amendment to ASC 350, Intangibles - Goodwill and Other, which aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal-use software license). The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendment will be applied on a prospective or retrospective basis. 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 beginning October 1, 2018, and 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 the accounting framework that is applied 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 as of October 1, 2018 and will be applied retrospectively with a cumulative effect adjustment at the date of adoption. The Company had a deferred gain of $6.8 million related to nonfinancial assets on the balance sheet, which will be recognized under the new accounting guidance as a cumulative effect adjustment to the opening balance of retained earnings as of October 1, 2018. 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 amendment establishes a practical expedient that permits entities to use their previously disclosed service and other costs in their pension and other postretirement benefit plan footnotes in the prior comparative periods as the estimation basis when applying the retrospective presentation of these costs in the income statement. The guidance is effective for the Company beginning October 1, 2018, and will be applied on a retrospective basis for income statement presentation, and on a prospective basis for changes to capitalization of costs. The changes related to the costs that will be eligible for capitalization and based on the components of net periodic benefit costs during fiscal year 2018, will not have a material impact on the Company's financial position, results of operations or cash flows upon adoption In August 2018, the FASB issued ASU No. 2018-14, an amendment to ASC 715, Compensation - Retirement Benefits, which removes disclosures that no longer are considered cost-beneficial, clarifies the specific requirements of certain disclosures, and adds new disclosure requirements identified as relevant. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a retrospective basis. The Company is continuing to evaluate the amendment to fully understand the impact on the Company's disclosures upon adoption. 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 beginning October 1, 2018, and will be applied prospectively to awards modified on or after the adoption date. There was no material impact to the Company's financial position, results of operations or cash flows upon adoption. In June 2018, the FASB issued ASU No. 2018-07, an amendment to ASC 718, Compensation - Stock Compensation, which expands the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from non-employees. The guidance is effective for the Company beginning October 1, 2019, with early adoption permitted. The Company is currently evaluating the impact of the amendment on the Company’s 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 beginning October 1, 2019, 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 In August 2018, the FASB issued ASU No. 2018-13, an amendment to ASC 820, Fair Value Measurement, which removes, modifies and adds to certain disclosure requirements of fair value measurements. Disclosure requirements removed include the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy, the policy for timing of transfers between levels and the valuation processes for Level 3 fair value measurements. Modifications include considerations around the requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse. The additions include the requirement to disclose changes in unrealized gains and losses for the period in other comprehensive income for recurring Level 3 fair value measurements held and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. The guidance is effective for the Company beginning October 1, 2020, with early adoption permitted. Upon adoption, the amendments will be applied on a prospective or retrospective basis depending on the specific amendments’ transition requirements. The Company is currently evaluating the amendments to understand the impact on its financial position, results of operations, cash flows and disclosures upon adoption and will apply the new guidance.
Fair Value Hierarchy | 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). 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.
Reclassification | Reclassification Certain prior period amounts related to the amortization of acquired wholesale energy contracts on the Consolidated Statements of Cash Flows and in the deferred tax table in Note 12. Income Taxes for the fiscal year ended September 30, 2017, were reclassified to conform to the current period presentation.

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