NEW JERSEY RESOURCES CORP

Part I

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. NATURE OF THE BUSINESS

The Company provides regulated natural gas distribution services, transmission and storage services and operates certain unregulated businesses primarily through the following:

NJNG provides natural gas utility service to residential and commercial customers throughout Burlington, Middlesex, Monmouth, Morris, Ocean and Sussex counties in New Jersey and is subject to rate regulation by the BPU. NJNG comprises the Natural Gas Distribution segment.

Clean Energy Ventures, the Company's clean energy subsidiary, comprises the CEV segment, which owns and operates clean energy projects, including commercial solar installations located in New Jersey, Rhode Island, New York, Connecticut, Michigan, Indiana and Pennsylvania.

Energy Services comprises the ES segment. ES maintains and transacts around a portfolio of natural gas transportation and storage capacity contracts and provides physical wholesale energy, retail energy and energy management services in the U.S.

NJR Midstream Holdings Corporation, which comprises the S&T segment, invests in energy-related ventures through its subsidiaries. The Company operates natural gas storage and transmission assets through the wholly-owned subsidiaries of Leaf River and Adelphia and is subject to rate regulation by FERC. The Company holds a 50% combined ownership interest in Steckman Ridge, a FERC-jurisdictional natural gas storage facility located in Pennsylvania, which is accounted for under the equity method of accounting.

NJR Retail Holdings Corporation hasone principal subsidiary, NJRHS, which provides heating, central air conditioning, standby generators, solar and other indoor and outdoor comfort products to residential homes throughout New Jersey. NJRHS is included in HSO.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The accompanying Unaudited Condensed Consolidated Financial Statements have been prepared by the Company in accordance with the rules and regulations of the U.S. Securities and Exchange Commission and GAAP. The September 30, 2025 Balance Sheet data is derived from the audited financial statements of the Company. These Unaudited Condensed Consolidated Financial Statements should be read in conjunction with the consolidated financial statements and the notes thereto included in the Company's 2025 Annual Report on Form 10-K.

The Unaudited Condensed Consolidated Financial Statements include the accounts of NJR and its subsidiaries. In the opinion of management, the accompanying Unaudited Condensed Consolidated Financial Statements reflect all adjustments necessary for a fair presentation of the results of the interim periods presented. These adjustments are of a normal and recurring nature. Because of the seasonal nature of the Company's utility and wholesale energy services operations, in addition to other factors, the financial results for the interim periods presented are not indicative of the results that are to be expected for the fiscal year ending September 30, 2026. Intercompany transactions and accounts have been eliminated.

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 equity method investments, lease liabilities, 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 and the fair value of derivative instruments and debt. Asset retirement obligations are evaluated periodically as required. 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.

Revenues

Revenues from the sale of natural gas to NJNG customers are recognized in the period that natural gas is delivered and consumed by customers, including an estimate for unbilled revenue. 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 NJNG recognizes unbilled revenues related to these amounts. The unbilled revenue estimates are based on estimated customer usage by customer type, weather effects, unaccounted-for natural gas and the most current tariff rates.

CEV recognizes revenue when SRECs are transferred to counterparties. SRECs are physically delivered through the transfer of certificates as per contractual settlement schedules. The SREC program closed to all new solar projects in April 2020.

TRECs provide a fixed compensation base multiplied by an assigned project factor in order to determine their value. The project factor is determined by the type and location of the project, as defined.

The ADI program provides administratively set incentives for net metered projects of 5 MW or less. The CSI program is open to qualifying grid supply solar facilities, non-residential net metered solar installations with a capacity greater than 5 MW, and eligible grid supply solar facilities installed in combination with energy storage. RECs generated through the production of electricity under these programs are known as SREC IIs.

TRECs and SREC IIs generated are required to be purchased monthly by a REC program administrator as appointed by the BPU. Revenue for TRECs and SREC IIs are recognized upon generation and are transferred monthly based upon metered solar electricity activity.

Revenues for ES 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. ES also recognizes changes in the fair value of SREC derivative contracts for forward sales as a component of operating revenues.

ES has a series of AMAs with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts. The AMAs include a series of temporary and permanent releases, and revenue under these agreements is recognized as the performance obligations are satisfied. For temporary releases of pipeline capacity, revenue is recognized on a straight-line basis over the agreed-upon term. For permanent releases of pipeline capacity, which represent a transfer of contractual rights for such capacity, revenue is recognized upon the transfer of the underlying contractual rights. ES recognized operating revenue of approximately $4.9 M during both the three months ended June 30, 2026 and 2025, and approximately $14.8 M during both the nine months ended June 30, 2026 and 2025, related to the AMAs on the Unaudited Condensed Consolidated Statements of Operations. Amounts received in excess of revenue recognized totaling approximately $56.4 M and $36.8 M are included in deferred revenue on the Unaudited Condensed Consolidated Balance Sheets as of June 30, 2026 and September 30, 2025, respectively.

S&T generates revenues from firm storage contracts and transportation contracts, related usage fees and hub services for the use of storage space, injections and withdrawals from their natural gas storage facility and the delivery of natural gas to customers. Demand fees are recognized as revenue over the term of the related agreement while usage fees and hub services revenues are recognized as services are performed.

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. See Note 3. Revenue for further information.

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 related to escrow balances for utility plant projects at NJNG, which are recorded in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets.

The following table provides a reconciliation of cash and cash equivalents and restricted cash reported in the Unaudited Condensed Consolidated Balance Sheets to the total amounts in the Unaudited Condensed Consolidated Statements of Cash Flows as follows:

Allowance for Doubtful Accounts

The Company segregates financial assets, primarily trade receivables and unbilled revenues due in one year or less, into portfolio segments based on shared risk characteristics, such as geographical location and regulatory environment, for evaluation of expected credit losses. Historical and current information, such as average write-offs, are applied to each portfolio segment to estimate the allowance for losses on uncollectible receivables. Additionally, the allowance for losses on uncollectible receivables is adjusted for reasonable and supportable forecasts of future economic conditions, which can include changing weather, commodity prices, regulations, and macroeconomic factors, such as unemployment rates among others.

Loans and Notes Receivable

NJNG currently provides loans, with terms ranging from five 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 fair value on the Unaudited Condensed Consolidated Balance Sheets. The Company has approximately $25.6 M and $21.5 M recorded in other current assets and approximately $82.9 M and $69.4 M in other noncurrent assets as of June 30, 2026 and September 30, 2025, respectively, on the Unaudited Condensed Consolidated Balance Sheets, related to the loans.

In August 2025, CEV entered into a seller-based financing arrangement with a third party for the sale of certain solar energy modules totaling approximately $42.5 M. Amounts related to the financing are due to CEV no later than December 31, 2027, and are recorded as notes receivable within the Company’s Unaudited Condensed Consolidated Balance Sheets as of June 30, 2026 and September 30, 2025.

The Company evaluates loans and notes receivable for collectability each reporting period in accordance with the current expected credit loss model. If necessary, an allowance is recorded to reflect potential losses. As of both June 30, 2026 and September 30, 2025, the Company has not recorded a reserve for credit losses associated with outstanding loans and notes receivable.

Natural Gas in Storage

The following table summarizes natural gas in storage, at average cost by segment as of:

Software Costs

The Company capitalizes certain costs, such as software design and configuration, coding, testing and installation, that are incurred to purchase or create and implement computer software for internal use. Capitalized costs include external costs of materials and services utilized in developing or obtaining internal-use software and payroll and payroll-related costs for employees who are directly associated with and devote time to the internal-use software project. Maintenance costs are expensed as incurred. Upgrades and enhancements are capitalized if it is probable that such expenditures will result in additional functionality. Amortization is recorded on the straight-line basis over the estimated useful lives.

The following tables present the software costs included in the Unaudited Condensed Consolidated Financial Statements:

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 or repurchase the asset at the end of the term. As NJNG retains control of the natural gas meters, these arrangements do not qualify as a sale. Proceeds from sale leaseback transactions are accounted for as financing arrangements and are included in long-term debt on the Unaudited Condensed Consolidated Balance Sheets.

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 arrangement does not qualify as a sale as the Company retains control of the underlying assets, the Company uses the financing method to account for the transaction. Under the financing method, the Company recognizes the proceeds received from the buyer-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 Unaudited Condensed Consolidated Balance Sheets.

The Company continues to operate its solar assets and is responsible for related expenses and entitled to retain the revenue generated from RECs and energy sales. ITCs and other tax attributes associated with these solar projects transfer to the buyer; however, the payments are structured so that CEV is compensated for the transfer of the related tax attributes. Accordingly, CEV recognizes the equivalent value of the tax attributes in other income on the Unaudited Condensed Consolidated Statements of Operations over the respective five-year ITC recapture periods, starting with the second year of the lease. See Note 9. Debt for more details regarding sale leaseback transactions recorded as financing arrangements.

Accumulated Other Comprehensive Loss

The following table presents the changes in the components of accumulated other comprehensive loss, net of related tax effects during the three months ended June 30, 2026 and 2025:

(1)Included in the computation of net periodic pension cost, a component of O&M on the Unaudited Condensed Consolidated Statements of Operations.

The following table presents the changes in the components of accumulated other comprehensive loss, net of related tax effects during the nine months ended June 30, 2026 and 2025:

(1)Included in the computation of net periodic pension cost, a component of O&M on the Unaudited Condensed Consolidated Statements of Operations.

Reclassification

Certain prior period amounts have been reclassified to conform to the current period presentation.

Recently Adopted Updates to the Accounting Standards Codification

Income Taxes

In December 2023, the FASB issued ASU No. 2023-09, an amendment to ASC 740, Income Taxes, which requires disaggregated information about a reporting entity’s effective tax rate reconciliation and income taxes paid. It will provide investors more detailed income tax disclosures that would be useful in making capital allocation decisions. The guidance became effective for the Company on October 1, 2025, for the first annual period, and can be applied either prospectively or retrospectively. As the amendments in this update only impact disclosures, there will be no impact on the Company’s financial position, results of operations, and cash flows upon adoption.

Part I

Other Recent Updates to the Accounting Standards Codification

Disaggregation of Income Statement Expenses

In November 2024, the FASB issued ASU No. 2024-03, an amendment to ASC 220, Income Statement Reporting, which requires more detailed information about specified categories of expenses included in certain captions presented on the face of the income statement. The guidance becomes effective for the Company on October 1, 2027, for the first annual period and on October 1, 2028, for the interim periods. The Company can elect to apply it either prospectively or retrospectively to all periods presented, with early adoption permitted. The Company is currently evaluating the amendment to understand the impacts on its disclosures upon adoption.

Internal-Use Software

In September 2025, the FASB issued ASU No. 2025-06, an amendment to ASC 350, Intangibles—Goodwill and Other, which simplifies the capitalization guidance as it relates to Internal-Use Software by removing all references to project stages and clarifying the threshold to apply to begin capitalizing costs. The guidance becomes effective for the Company on October 1, 2028. The Company can elect to apply it prospectively, retrospectively or through a modified transition approach, with early adoption permitted. The Company is currently evaluating the amendment to understand the impacts on its financial position, results of operations and cash flows upon adoption.

Government Grants

In December 2025, the FASB issued ASU No. 2025-10, an amendment to ASC 832, Government Grants, which adds guidance on the recognition, measurement, and presentation of government grants. The guidance becomes effective for the Company on October 1, 2029. The Company can elect to apply it retrospectively, or through a modified prospective or retrospective transition approach, with early adoption permitted. The Company is currently evaluating the amendment to understand the impacts on its financial position, results of operations and cash flows upon adoption.

Environmental Credits and Environmental Credit Obligations

In May 2026, the FASB issued ASU No. 2026-02, Environmental Credits and Environmental Credit Obligations (Topic 818), which establishes comprehensive accounting guidance for environmental credits and related obligations. The guidance becomes effective for the Company on October 1, 2028. The Company is required to apply the amendment retrospectively, with early adoption permitted. The Company is currently evaluating the amendment to determine its impact on the Company’s financial position, results of operations, and disclosures upon adoption.

3. REVENUE

Revenue is recognized when a performance obligation is satisfied by transferring control of a product or service to a customer. Revenue is measured based on consideration specified in a contract with a customer using the output method of progress. The Company elected to apply the invoice practical expedient for recognizing revenue, whereby the amounts invoiced to customers represent the value to the customer and the Company’s performance completion as of the invoice date. Therefore, the Company does not disclose related unsatisfied performance obligations. The Company also elected the practical expedient to exclude from the transaction price all sales taxes that are assessed by a governmental authority and therefore presents sales tax net in operating revenues on the Unaudited Condensed Consolidated Statements of Operations.

Below is a listing of performance obligations that arise from contracts with customers, along with details on the satisfaction of each performance obligation, the significant payment terms and the nature of the goods and services being transferred, by reportable segment and other business operations:

Part I

Part I

Disaggregated revenues from contracts with customers by product line and by reportable segment and other business operations during the three months ended June 30, 2026 and 2025, are as follows:

(1)Includes building rent related to the Wall headquarters, which is eliminated in consolidation.

(2)Consists of transactions between subsidiaries that are eliminated in consolidation.

(3)Includes CIP revenue.

(4)Includes SREC revenue.

Part I

Disaggregated revenues from contracts with customers by product line and by reportable segment and other business operations during the nine months ended June 30, 2026 and 2025, are as follows:

(1)Includes building rent related to the Wall headquarters, which is eliminated in consolidation.

(2)Consists of transactions between subsidiaries that are eliminated in consolidation.

(3)Includes CIP revenue.

(4)Includes SREC revenue.

Part I

Disaggregated revenues from contracts with customers by customer type and by reportable segment and other business operations during the three months ended June 30, 2026 and 2025, are as follows:

Disaggregated revenues from contracts with customers by customer type and by reportable segment and other business operations during the nine months ended June 30, 2026 and 2025, are as follows:

Part I

Customer Accounts Receivable/Credit Balances and Deposits

The timing of revenue recognition, customer billings and cash collections resulting in accounts receivables, billed and unbilled, and customers’ credit balances and deposits on the Unaudited Condensed Consolidated Balance Sheets during the nine months ended June 30, 2026 and 2025, are as follows:

The following table provides information about receivables, which are included within accounts receivable, billed and unbilled, and customers’ credit balances and deposits, respectively, on the Unaudited Condensed Consolidated Balance Sheets as of June 30, 2026 and September 30, 2025:

4. REGULATION

NJNG is subject to cost-based regulation, therefore, it is permitted to recover authorized operating expenses and earn a reasonable return on its utility capital investments based on the BPU's approval. The impact of the ratemaking process and decisions authorized by the BPU allows NJNG to capitalize or defer certain costs that are expected to be recovered from its customers as regulatory assets and to recognize certain obligations representing amounts that are probable future expenditures as regulatory liabilities in accordance with accounting guidance applicable to regulated operations.

NJNG's recovery of costs is facilitated through its base rates, BGSS and other regulatory tariff riders. NJNG is required to make filings to the BPU for review of its BGSS, CIP and other programs and related rates. Annual rate changes are typically requested to be effective at the beginning of the following fiscal year. The current base rates include a weighted average cost of capital of 7.08% and a return on common equity of 9.6%. All rate and program changes are subject to proper notification and BPU review and approval. In addition, NJNG is permitted to implement certain BGSS rate changes on a provisional basis with proper notification to the BPU.

Part I

Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets for NJNG are comprised of the following:

Regulatory assets and liabilities included on the Unaudited Condensed Consolidated Balance Sheets for Adelphia are comprised of the following:

The assets are comprised primarily of the tax benefit associated with the equity component of Allowance for Funds Used During Construction and the liability consists primarily of scheduling penalties. Recovery of regulatory assets is subject to FERC approval.

Part I

Regulatory filings and/or actions that occurred during the current fiscal year include the following:

•On October 31, 2025, NJNG notified the BPU that it intended to self-implement an increase to its BGSS rate, effective December 1, 2025 through September 30, 2026, which will result in an increase of approximately $38.1 M in revenues related to BGSS.

•On December 17, 2025, the BPU approved, on a provisional basis, NJNG's annual BGSS/CIP filing, which included an increase of approximately $6.1 M related to its balancing charge and a decrease of approximately $26.2 M to CIP rates, effective January 1, 2026.

•On December 17, 2025, the BPU approved NJNG's annual SAVEGREEN filing for the recovery of costs, which will increase annual recoveries by approximately $13.3 M, effective January 1, 2026.

•On December 17, 2025, the BPU approved NJNG's final IIP filing, which requested a rate increase for capital expenditures of approximately $33.1 M through October 31, 2025, resulting in a revenue increase of approximately $3.3 M, effective January 1, 2026. In conjunction with this filing, NJNG notified the BPU that it was withdrawing its July 2025 request to extend the program. Any recovery of future infrastructure investments will be requested through a NJNG base rate case.

•On March 18, 2026, the BPU approved NJNG's annual SBC filing of RAC expenditures through June 30, 2025, which included a decrease to the RAC annual recoveries of approximately $0.8 M and a decrease to the NJCEP annual recoveries of approximately $5.2 M, effective April 1, 2026.

•On June 1, 2026, NJNG submitted its annual BGSS/CIP filing to the BPU requesting a decrease of approximately $27.4 M to annual revenues related to BGSS, an increase of approximately $1.0 M related to its balancing charge and a decrease of approximately $46.8 M to CIP rates, effective October 1, 2026.

•On June 1, 2026, NJNG filed a base rate case with the BPU requesting a natural gas revenue increase of $157.6 M including a recovery of infrastructure investments, a change in the Company's overall rate of return on rate base to 7.60% and a change in the return on common equity to 10.10%.

•On June 1, 2026, NJNG submitted its annual SAVEGREEN cost recovery filing to the BPU requesting a decrease to annual recoveries of approximately $18.3 M, effective October 1, 2026.

•On June 29, 2026, NJNG submitted its annual USF filing to the BPU requesting a decrease to annual recoveries of approximately $1.8 M, effective October 1, 2026.

Unless otherwise noted, NJNG cannot predict the outcome or ultimate resolution for open regulatory matters.

5. DERIVATIVE INSTRUMENTS

The Company is subject primarily 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. In addition, the Company is exposed to interest rate risk and may utilize derivatives to reduce exposure to fluctuations in interest rates. These contracts are accounted for as derivatives, unless the Company elects NPNS, which is done on a contract-by-contract election. Accordingly, financial and certain of the Company's physical contracts are recorded at fair value on the Unaudited Condensed 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

ES 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 operating expenses or operating revenues, as appropriate for ES, on the Unaudited Condensed Consolidated Statements of Operations as unrealized gains or losses. For ES at settlement, realized gains and losses on all financial derivative instruments are recognized as a component of natural 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 operating expenses or operating revenues.

Part I

As a result of ES 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 natural gas is expected to occur and is considered a derivative transaction that is recorded at fair value on the Unaudited Condensed Consolidated Balance Sheets, with changes in value recognized in current period earnings.

Expected production of SRECs are 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. ES recognizes changes in the fair value of these derivatives as a component of operating revenues. For SRECs that are acquired by ES, changes in the fair value of these derivatives are reported as a component of operating expenses. Upon settlement of these contracts, the related revenue or expense is recognized when the SREC is transferred to the counterparty or acquired by ES, respectively.

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 Unaudited Condensed Consolidated Balance Sheets. NJNG does not currently elect NPNS on any of its physical commodity derivatives. However, since NPNS is a contract-by-contract election, where it makes sense to do so, NJNG can and may elect to treat certain contracts as 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 natural gas service, the changes in fair value of these contracts are deferred as a component of regulatory assets or liabilities on the Unaudited Condensed Consolidated Balance Sheets.

The Company elects NPNS accounting treatment on PPAs executed by CEV that meet the definition of a derivative and accounts for the contract on an accrual basis. Accordingly, electricity sales are recognized in revenues throughout the term of the PPA as electricity is delivered. NPNS is a contract-by-contract election and where it makes sense to do so, the Company can and may elect to treat certain contracts as normal.

Fair Value of Derivatives

The following table presents the fair value of the Company's derivative assets and liabilities recognized on the Unaudited Condensed Consolidated Balance Sheets as of:

Offsetting of Derivatives

The Company transacts under master netting arrangements or equivalent agreements that allow it to offset derivative assets and liabilities with the same counterparty. However, the Company’s policy is to present its derivative assets and liabilities on a gross basis at the contract level unit of account on the Unaudited Condensed Consolidated Balance Sheets.

Part I

The following table summarizes the reported gross amounts, the amounts that the Company has the right to offset but elects not to, financial collateral and the net amounts the Company could present on the Unaudited Condensed Consolidated Balance Sheets but elects not to.

(1)Derivative assets and liabilities are presented on a gross basis on the Unaudited Condensed Consolidated Balance Sheets as the Company does not elect balance sheet offsetting under ASC 210-20.

(2)Includes transactions with NAESB netting election, transactions held by FCMs with net margining and transactions with ISDA netting.

(3)Financial collateral includes cash balances at FCMs as well as cash received from or pledged to other counterparties.

(4)Net amounts represent presentation of derivative assets and liabilities if the Company were to elect balance sheet offsetting under ASC 210-20.

ES utilizes financial derivatives to economically hedge the gross margin associated with the purchase of physical natural gas to be used for storage injection and its subsequent sale at a later date. The gains or (losses) on the financial transactions that are economic hedges of the cost of the purchased natural gas are recognized prior to the gains or (losses) on the physical transaction, which are recognized in earnings when the natural gas is delivered. Therefore, mismatches between the timing of the recognition of realized gains or (losses) on the financial derivative instruments and gains or (losses) associated with the actual sale of the natural gas that is being economically hedged along with fair value changes in derivative instruments, create volatility in the results of ES, although the Company's intended economic results relating to the entire transaction are unaffected.

The following table presents the effect of derivative instruments recognized on the Unaudited Condensed Consolidated Statements of Operations for the periods set forth below:

Part I

NJNG’s derivative contracts are part of the Company's risk management activities that relate to its natural gas purchases and BGSS incentive programs. At settlement, the resulting gains and/or losses are payable to or recoverable from utility customers and are deferred in regulatory assets or liabilities resulting in no impact to earnings.

The following table reflects the gains (losses) associated with NJNG's derivative instruments for the periods set forth below:

NJNG and ES had the following outstanding long (short) derivatives as of:

Not included in the above table are 0.9 M SRECs that were open as of both June 30, 2026 and September 30, 2025.

Broker Margin

Futures exchanges have contract specific margin requirements that require the posting of cash or cash equivalents relating to traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily marked-to-market relative to maintenance margin requirements. The Company maintains separate broker margin accounts for NJNG and ES.

The balances by reportable segment are as follows:

Wholesale Credit Risk

NJNG, ES, CEV and S&T are exposed to credit risk as a result of their sales/wholesale marketing activities. As a result of the inherent volatility in the prices of natural gas commodities, derivatives and SRECs, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If a counterparty fails to perform the obligations under its contract, then the Company could sustain a loss.

The Company monitors and manages the credit risk of its wholesale operations through credit policies and procedures that management believes reduce overall credit risk. These policies include a review and evaluation of current and prospective counterparties' financial statements and/or credit ratings, daily monitoring of counterparties' credit limits and exposure, daily communication with traders regarding credit status and the use of credit mitigation measures, such as collateral requirements and netting agreements. Examples of collateral include letters of credit and cash received for either prepayment or margin deposit. Collateral may be requested due to the Company's election not to extend credit or because exposure exceeds defined thresholds. Most of the Company's wholesale marketing contracts contain standard netting provisions. These contracts include those governed by ISDA and the NAESB. The netting provisions refer to payment netting, whereby receivables and payables with the same counterparty are offset and the resulting net amount is paid to the party to which it is due.

Part I

Internally-rated exposure applies to counterparties that are not rated by Fitch or Moody's. In these cases, the counterparty's or guarantor's financial statements are reviewed, and similar methodologies and ratios used by credit rating agencies are applied to arrive at a substitute rating. Gross credit exposure is defined as the unrealized fair value of physical and financial derivative commodity contracts, plus any outstanding wholesale receivable for the value of natural gas delivered and/or financial derivative commodity contract that has settled for which payment has not yet been received.

The following is a summary of gross credit exposures grouped by investment and noninvestment grade counterparties, as of June 30, 2026. The amounts presented below have not been reduced by any collateral received or netting and exclude accounts receivable for NJNG retail natural gas sales and services.

Conversely, certain of NJNG's and ES's derivative instruments are linked to agreements containing provisions that would require cash collateral payments from the Company if certain events occur. These provisions vary based upon the terms in individual counterparty agreements and can result in cash payments if NJNG's credit rating were to fall below its current level. Specifically, most, but not all, of these additional payments will be triggered if NJNG's debt is downgraded by the major credit agencies, regardless of investment grade status. In addition, some of these agreements include threshold amounts that would result in additional collateral payments if the values of derivative liabilities were to exceed the maximum values provided for in relevant counterparty agreements. Other provisions include payment features that are not specifically linked to ratings but are based on certain financial metrics.

Collateral amounts associated with any of these conditions are determined based on a sliding scale and are contingent upon the degree to which the Company's credit rating and/or financial metrics deteriorate, and the extent to which liability amounts exceed applicable threshold limits. Derivative instruments with credit-risk-related contingent features that were in a liability position for which collateral is required were immaterial as of June 30, 2026 and September 30, 2025. These amounts differ from the respective net derivative liabilities reflected on the Unaudited Condensed Consolidated Balance Sheets because the agreements also include clauses, commonly known as “Rights of Offset,” that would permit the Company to offset its derivative assets against its derivative liabilities for determining additional collateral to be posted, as previously discussed.

6. FAIR VALUE

Fair Value of Assets and Liabilities

The fair value of cash and cash equivalents, accounts receivable, current loans receivable, accounts payable, commercial paper and borrowings under revolving credit facilities are estimated to equal their carrying amounts due to the short maturity of those instruments. Notes receivable and noncurrent loans receivable are recorded based on what the Company expects to receive, which approximates fair value. Noncurrent loans receivable are in other noncurrent assets on the Unaudited Condensed Consolidated Balance Sheets. The Company regularly evaluates the credit quality and collection profile of its customers to approximate fair value.

The estimated fair value of long-term debt, including current maturities, excluding natural gas meter sale leasebacks, debt issuance costs and solar asset sale leasebacks, is as follows:

(1)Excludes NJNG's debt issuance costs of approximately $11.1 M and $11.3 M as of June 30, 2026 and September 30, 2025, respectively.

(2)Excludes NJR's debt issuance costs of approximately $2.4 M and $2.9 M as of June 30, 2026 and September 30, 2025, respectively.

Part I

The Company enters into sale leaseback transactions for certain commercial solar assets and natural gas meters. These transactions are recorded within long-term debt on the Unaudited Condensed Consolidated Balance Sheets. The carrying value of solar sale leasebacks was approximately $538.0 M and $471.5 M and the estimated fair value was approximately $538.8 M and $481.4 M as of June 30, 2026 and September 30, 2025, respectively. The carrying value of the natural gas meter sale leasebacks was approximately $41.2 M and $33.5 M and the estimated fair value of certain natural gas meter sale leasebacks amounted to approximately $40.4 M and $32.5 M as of June 30, 2026 and September 30, 2025, respectively.

The Company utilizes a discounted cash flow method to determine the fair value of its debt. Inputs include observable municipal and corporate yields, as appropriate for the maturity of the specific debt instrument and the Company's credit rating. As of June 30, 2026 and September 30, 2025, the Company discloses its debt within Level 2 of the 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, investments in equity 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:

Part I

Assets and liabilities measured at fair value on a recurring basis are summarized as follows:

7. INVESTMENTS IN EQUITY INVESTEES

The Company holds a 50% equity method investment in Steckman Ridge, a jointly owned and controlled natural gas storage facility located in Bedford County, Pennsylvania. The Company's investment in Steckman Ridge was approximately $101.4 M and $101.2 M as of June 30, 2026 and September 30, 2025, respectively, which includes loans with a total outstanding principal balance of approximately $70.4 M for both periods. These loans accrue interest at a variable rate that resets quarterly and are due October 1, 2027.

NJNG and ES have entered into storage and park and loan agreements with Steckman Ridge. See Note 15. Related Party Transactions for more information on these intercompany transactions.

8. EARNINGS PER SHARE

The following table presents the calculation of the Company's basic and diluted earnings per share for:

(1)Incremental shares consist primarily of unvested stock awards and performance units, which are calculated using the treasury stock method. Since there was a net loss for the three months ended June 30, 2025, incremental shares of 662,851 were not included in the computation of diluted (loss) per common share. There wereno anti-dilutive shares excluded during the three and nine months ended June 30, 2026 and the nine months ended June 30, 2025.

Part I

9. DEBT

NJR and NJNG finance working capital requirements and capital expenditures through various short-term debt and long-term financing arrangements, including a commercial paper program and committed unsecured credit facilities.

Credit Facilities and Short-term Debt

A summary of NJR's credit facility and NJNG's commercial paper program and credit facility is as follows:

(1)Committed credit facility, which requires commitment fees of 0.10% on the unused amount.

(2)Letters of credit outstanding total approximately $26.1 M and $21.4 M as of June 30, 2026 and September 30, 2025, respectively, which reduces the amount available by the same amount.

(3)Committed credit facility, which requires commitment fees of 0.075% on the unused amount.

(4)Letters of credit outstanding total approximately $0.7 M as of both June 30, 2026 and September 30, 2025, which reduces the amount available by the same amount.

Amounts available under credit facilities are reduced by bank or commercial paper borrowings, as applicable, and any outstanding letters of credit. Neither NJNG nor the results of its operations are obligated or pledged to support the NJR Credit Facility.