NEW JERSEY RESOURCES CORP

Long-term Debt

NJNG

NJNG received approximately $15.0 M and $11.7 M during the six months ended March 31, 2026 and 2025, respectively, in connection with the sale leaseback of its natural gas meters. NJNG records the sale leaseback as a financing obligation for accounting purposes that is paid over the term of the arrangement and has the option to purchase the meters back at fair value upon expiration of the lease.

On April 1, 2026, NJNG remarketed a $15.0 M FMB, with an interest rate of 3.75% and a maturity date of April 1, 2059.

CEV received proceeds of approximately $49.3 M and $25.7 M during the six months ended March 31, 2026 and 2025, respectively, in connection with the sale leaseback of commercial solar assets. CEV records the sale leaseback as a financing obligation for accounting purposes and continues to operate the solar assets, including related expenses, retains the revenue generated from RECs and energy sales, and has the option to repurchase the assets sold or renew the lease at the end of the lease term.

10. EMPLOYEE BENEFIT PLANS

Pension and Other Postemployment Benefit Plans

In January 2024, the Company announced changes to its postretirement medical benefits plan that replaced the existing retiree medical coverage for certain eligible employees and their dependents with an employer funded Health Reimbursement Arrangement beginning on January 1, 2025. The liability associated with postretirement medical benefits was remeasured as of January 1, 2024. The change in post-retirement medical benefits is being amortized into earnings over approximately eight years, the average remaining service to retirement for all plan participants.

Part I

The components of the net periodic cost for pension benefits, including the Company's Pension Equalization Plan, and OPEB costs (principally health care and life insurance) for employees and covered dependents were as follows:

The Company does not expect to make additional contributions to fund the pension plans during fiscal 2026 based on current actuarial assumptions; however, funding requirements are uncertain and can depend significantly on changes in actuarial assumptions, returns on plan assets and changes in the demographics of eligible employees and covered dependents. In addition, as in the past, the Company may elect to make contributions in excess of the minimum required amount to the plans. There wereno discretionary contributions made during the six months ended March 31, 2026 and 2025.

11. INCOME TAXES

ASC Topic 740, Income Taxes requires the use of an estimated annual effective tax rate for purposes of determining the income tax provision during interim reporting periods. In calculating its estimated annual effective tax rate, the Company considers forecasted annual pre-tax income and estimated permanent book versus tax differences. Adjustments to the effective tax rate and management's estimates will occur as information and assumptions change.

Changes in tax laws or tax rates are recognized in the financial reporting period that includes the enactment date, the date on which the act is signed into law. Similarly, the tax effect of unusual or infrequent events and transactions are recognized in the financial reporting period in which they occur. These items are excluded from the calculation of the estimated annual effective tax rate and are reported discretely in each interim reporting period.

NJR evaluates its tax positions to determine the appropriate accounting and recognition of potential future obligations associated with uncertain tax positions. A tax benefit claimed, or expected to be claimed, on a tax return may be recognized only if it is more likely than not that the tax position will be upheld upon examination by the applicable taxing authority and is measured based on the largest tax benefit that is more than 50% likely to be realized. Interest and penalties related to unrecognized tax benefits, if any, are recognized within income tax expense, and accrued interest and penalties are recognized within other noncurrent liabilities on the Unaudited Condensed Consolidated Balance Sheets.

Effective Tax Rate

The estimated annual effective tax rates were 23.0% and 23.2%, for the six months ended March 31, 2026 and 2025, respectively.

To the extent there are discrete tax items that are not included in the estimated annual effective tax rate, the actual reported effective tax rate may differ from the estimated annual effective tax rate. Discrete tax items primarily relate to the vesting of share-based awards during the six months ended March 31, 2026, and income tax effects associated with the sale of the Company’s residential solar energy projects and host customer contracts during the six months ended March 31, 2025. NJR’s effective tax rate was 22.7% and 22.8% during the six months ended March 31, 2026 and 2025, respectively.

Part I

Other Tax Items

As of March 31, 2026 and September 30, 2025, the Company has tax credit carryforwards of approximately $97.7 M and $149.7 M, respectively, which each have a life of 20 years. The Company expects to utilize this entire carryforward prior to expiration, which would begin in fiscal 2036.

As of March 31, 2026 and September 30, 2025, the Company has state income tax net operating losses of approximately $353.9 M and $476.1 M, respectively. The Company’s state net operating loss carryforwards are subject to varying expiration periods based on the jurisdiction in which they were generated, generally ranging from seven to 20 years, with the majority expiring after 2037. The Company expects to utilize this entire carryforward prior to expiration, except for state income tax attributes for which the Company has a valuation allowance of approximately $0.4 M as of both March 31, 2026 and September 30, 2025, for which the Company could not conclude were realizable on a more-likely-than-not basis.

In July 2025, the President of the U.S. signed OBBBA into law, which includes a broad range of tax reform provisions, including extending and modifying certain key provisions of the federal Tax Cuts and Jobs Act of 2017, as enacted on December 22, 2017, and expanding certain incentives under the federal Inflation Reduction Act. OBBBA also modified tax legislation affecting clean energy tax credits and accelerated the phase-out of ITCs. The Company evaluated the provisions of OBBBA and concluded it did not have a material impact on its Unaudited Condensed Consolidated Financial Statements.

12. LEASES

The Company determines if an arrangement is a lease at inception based on whether the Company has the right to control the use of an identified asset, the right to obtain substantially all of the economic benefits from the use of the asset and the right to direct the use of the asset. After the criteria are satisfied, the Company accounts for these arrangements as leases in accordance with ASC 842, Leases. Right-of-use assets represent the Company’s right to use the underlying asset for the lease term and lease liabilities represent the Company's obligation to make lease payments arising from the lease. Right-of-use assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Company is the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. The Company has not entered into any material agreements as of March 31, 2026, in which it is a lessor.

The Company’s lease agreements primarily consist of commercial solar land leases, storage and capacity leases, equipment and real property, including land and office facilities, office equipment and the sale leaseback of certain natural gas meters.

Certain leases contain escalation provisions for inflation metrics. The storage leases contain a variable payment component that relates to the change in the inflation metrics that are not known past the current payment period. The variable components of these lease payments are excluded from the lease payments that are used to determine the related right-of-use lease asset and liability. The variable portion of these leases are recognized as leasing expenses when they are incurred. The capacity lease payments are fully variable and based on the amount of natural gas stored in the storage caverns.

Generally, the Company’s solar land lease terms are between 20 and 50 years and may include multiple options to extend the terms for an additional five to 20 years. The Company’s office leases vary in duration, ranging fromtwo to 11 years and may or may not include extension or early purchase options. The Company’s meter lease terms are between seven and 10 years with purchase options available prior to the end of the term. Equipment leases, including general office equipment, also vary in duration, with an average term often years. The Company's storage and capacity leases have assumed terms of 50 years to coincide with the expected useful lives of the cavern assets with which the leases are associated. The Company's lease terms may include options to extend, purchase the leased asset or terminate a lease and they are included in the lease liability calculation when it is reasonably certain that those options will be exercised. The Company has elected an accounting policy, which applies to all asset classes, that exempts leases with an original term of one year or less from the recognition requirements of ASC 842, Leases.

Part I

The Company has lease agreements with lease and non-lease components and has elected the practical expedient not to separate lease components from the associated non-lease components for certain classes of leases, such as office buildings, solar land leases and office equipment. The Company’s lease agreements do not contain any material residual value guarantees, material restrictions or material covenants. In July 2021, NJNG entered into 16-year lease agreements, as Lessor, with various NJR subsidiaries, as Lessees, for office space at the Company’s headquarters in Wall, New Jersey, the effects of which are eliminated in consolidation.

The following table presents the Company's lease costs included in the Unaudited Condensed Consolidated Statements of Operations:

The following table presents supplemental cash flow information related to leases:

Operating lease assets obtained in exchange for new or modified operating lease liabilities totaled approximately $0.8 M and $5.4 M during the three and six months ended March 31, 2026, respectively, and $5.5 M during both the three and six months ended March 31, 2025. There wereno finance lease assets obtained in exchange for new or modified finance lease liabilities during the three and six months ended March 31, 2026 and 2025.

The following table presents the balance and classifications of the Company's right of use assets and lease liabilities included in the Unaudited Condensed Consolidated Balance Sheets:

For operating lease assets and liabilities, the weighted average remaining lease term was 28.0 years and 28.4 years and the weighted average discount rate used in the valuation over the remaining lease term was 4.1% and 4.0% as of March 31, 2026 and September 30, 2025, respectively. For finance lease assets and liabilities, the weighted average remaining lease term was 2.1 years and 2.4 years as of March 31, 2026 and September 30, 2025, respectively, and the weighted average discount rate used in the valuation over the remaining lease term was 3.4% as of both March 31, 2026 and September 30, 2025.

Part I

13. COMMITMENTS AND CONTINGENT LIABILITIES

Cash Commitments

NJNG has entered into long-term contracts, expiring at various dates through July 2039, for the supply, transportation and storage of natural gas. These contracts include annual fixed charges of approximately $126.3 M at current contract rates and volumes for the remainder of the fiscal year, which are recoverable through BGSS.

For the purpose of securing storage and pipeline capacity, ES enters into storage and pipeline capacity contracts, which require the payment of certain demand charges by ES to maintain the ability to access such natural gas storage or pipeline capacity, during a fixed time period, which generally ranges fromone to 10 years. Demand charges are established by interstate storage and pipeline operators and are regulated by FERC. These demand charges represent commitments to pay storage providers or pipeline companies for the right to store and/or transport natural gas utilizing their respective assets.

Commitments as of March 31, 2026, for natural gas purchases and future demand fees for the next five fiscal year periods are as follows:

Certain pipeline demand fees totaling approximately $4.0 M per year, for which ES is the responsible party, are being paid for by the counterparty to a capacity release transaction, which began in November 2021, for a period of 10 years.

Guarantees

As of March 31, 2026, there were NJR guarantees covering approximately $151.5 M of ES’s natural gas purchases and demand fee commitments not yet reflected in accounts payable on the Unaudited Condensed Consolidated Balance Sheets.

Legal Proceedings

Manufactured Gas Plant Remediation

NJNG is responsible for the remedial cleanup of certain former MGP sites, dating back to gas operations in the late 1800s and early 1900s, which contain contaminated residues from former gas manufacturing operations. NJNG is currently involved in administrative proceedings with the NJDEP and is participating in various studies and investigations by outside consultants, to determine the nature and extent of any such contaminated residues and to develop appropriate programs of remedial action, where warranted, under NJDEP regulations.

NJNG periodically, and at least annually, performs an environmental review of former MGP sites located in Atlantic Highlands, Berkeley, Long Branch, Manchester, Toms River, Freehold and Aberdeen, New Jersey, including a review of potential liability for investigation and remedial action. NJNG estimated at the time of the most recent review that total future expenditures at the former MGP sites for which it is responsible, including potential liabilities for natural resource damages that might be brought by the NJDEP for alleged injury to groundwater or other natural resources concerning these sites, will range from approximately $144.3 M to $200.2 M. 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.

Part I

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. Accordingly, as of March 31, 2026, NJNG recorded a MGP remediation liability and a corresponding regulatory asset of approximately $166.1 M on the Unaudited Condensed Consolidated Balance Sheets based on the most likely amount. 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 insurance recoveries, if any.

NJNG recovers its remediation expenditures, including carrying costs, over rolling seven-year periods pursuant to a RAC approved by the BPU. As of March 31, 2026, approximately $61.2 M of previously incurred remediation costs, net of recoveries from customers and insurance proceeds, are included in regulatory assets on the Unaudited Condensed Consolidated Balance Sheets. 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.

General

The Company is involved, and from time to time in the future may be involved, in a number of pending and threatened judicial, regulatory and arbitration proceedings relating to matters that arise in the ordinary course of business. In view of the inherent difficulty of predicting the outcome of litigation matters, particularly when such matters are in their early stages or where the claimants seek indeterminate damages, the Company cannot state with confidence what the eventual outcome of the pending litigation will be, what the timing of the ultimate resolution of these matters will be, or what the eventual loss, fines or penalties related to each pending matter will be, if any. In accordance with applicable accounting guidance, the Company establishes accruals for litigation for those matters that present loss contingencies as to which it is both probable that a loss will be incurred and the amount of such loss can be reasonably estimated. The Company also discloses contingent matters for which there is a reasonable possibility of a loss. Based upon currently available information, the Company believes that the results of litigation that are currently pending, taken together, will not have a materially adverse effect on the Company’s financial condition, results of operations or cash flows. The actual results of resolving the pending litigation matters may be substantially different than the amounts accrued.

The foregoing statements about the Company’s litigation are based upon the Company’s judgments, assumptions and estimates and are necessarily subjective and uncertain. The Company has a number of threatened and pending litigation matters at various stages.

14. REPORTABLE SEGMENT DATA

The Company hasfour reportable segments which are determined based upon a combination of factors, including the nature of business activities, product and service offerings and the regulatory environment in which the businesses operate. NJNG consists of regulated utility operations that provide energy and off-system, capacity and storage management operations primarily to residential and commercial customers; CEV consists of capital investments in clean energy projects, primarily in commercial solar installations; ES consists of unregulated wholesale and retail energy operations and asset management services; S&T consists of the Company’s investments in natural gas transportation and storage facilities.

The accounting policies of the Company, as described in Note 2. Summary of Significant Accounting Policies, are the same as those of the reportable segments. Intercompany transactions are eliminated in consolidation.

The Chief Operating Decision Maker, the Chief Executive Officer of the Company, uses net income and NFE, as well as various other financial and operational metrics as measures of profitability. Net income is the measure of segment profit or loss that most closely aligns with GAAP. Performance is evaluated based upon profitability and budget and/or forecast-to-actual variances when making decisions about the allocation of resources and capital to segment operations.

Part I

Information related to the Company's various reportable segments during the three months ended March 31, 2026 and 2025, is detailed below:

(2)Interest income is included in other income, net on the Unaudited Condensed Consolidated Statements of Operations.

(3)Includes other income, net less interest income on the Unaudited Condensed Consolidated Statements of Operations.

Part I

Information related to the Company's various reportable segments during the six months ended March 31, 2026 and 2025, is detailed below:

(2)Interest income is included in other income, net on the Unaudited Condensed Consolidated Statements of Operations.

(3)Includes other income, net less interest income on the Unaudited Condensed Consolidated Statements of Operations.

Part I

The Company's capital expenditures for the various reportable segments are detailed below:

The Company's assets for the various reportable segments are detailed below:

15. RELATED PARTY TRANSACTIONS

In April 2020, NJNG entered into afive-year agreement for 3 Bcf of firm storage capacity with Steckman Ridge, which expired in March 2025. In March 2025, NJNG entered into atwo-year agreement for 3 Bcf of firm storage capacity with Steckman Ridge, which expires on March 31, 2027. Under the terms of the new agreement, NJNG incurs demand fees, at market rates, of approximately $6.5 M annually, a portion of which is eliminated in consolidation. These fees are recoverable through NJNG’s BGSS mechanism and are included as a component of regulatory assets.

ES may periodically enter into storage or park and loan agreements with Steckman Ridge. As of March 31, 2026, ES entered into transactions with Steckman Ridge for varying terms, all of which expire by March 31, 2027.

Demand fees, net of eliminations, associated with Steckman Ridge were as follows:

The following table summarizes demand fees payable to Steckman Ridge as of:

Part I

NJNG entered intotwo transportation agreements with Adelphia, each for committed capacity of 130,000 Dths per day. The first is forfive years in Zone South with an expiration date of August 8, 2027, and the second is for 15 years in Zone North with an expiration date of October 31, 2038.

NJNG and CEV entered into a 15-year sublease and PPA related to an onsite solar array and the related energy output at the Company’s headquarters in Wall, New Jersey, with an expiration date of March 1, 2036, the effects of which are immaterial to the Unaudited Condensed Consolidated Financial Statements.

NJNG entered into 16-year lease agreements, as Lessor, with various NJR subsidiaries, as Lessees, for office space at the Company’s headquarters in Wall, New Jersey, each with an expiration date of July 1, 2037, the effects of which are eliminated in consolidation.

NJNG and CEV entered into a 20-year sublease and PPA related to an onsite solar array and the related energy output at the Company’s liquefied natural gas plant in Howell, New Jersey, with an expiration date of June 1, 2042, the effects of which are immaterial to the Unaudited Condensed Consolidated Financial Statements.

The intercompany profits for certain transactions between NJNG and ES and NJNG and Adelphia are not eliminated in accordance with ASC 980, Regulated Operations.

16. DISPOSITIONS

In November 2024, CEV completed the sale of its residential solar portfolio to a third party, which primarily included residential solar energy projects and host customer contracts, for a purchase price of $132.5 M. The transaction also included a post-closing working capital adjustment and was subject to a transition services agreement.

CEV had certain residential solar energy projects under contract and in various stages of development that were transferred to the buyer once the assets became operational. The transfer of these projects commenced in January 2025 and continued throughout fiscal 2025. As of September 30, 2025, CEV received approximately $4.7 M related to the transfer of these assets. There wereno projects transferred during the three and six months ended March 31, 2026.

During the three and six months ended March 31, 2025, the Company recognized a pre-tax gain on sale of assets of approximately $0.7 M and $55.5 M, respectively, on the Unaudited Condensed Consolidated Statements of Operations. There wasno activity during the three and six months ended March 31, 2026.

Also, in connection with the sale, CEV entered into an agreement with the buyer to leaseback certain residential solar energy projects that have not yet passed the fifth anniversary of their placed-in-service dates. The assets are subject to leaseback until the fifth anniversary of the applicable placed-in-service date of the project. The impact of these transactions is considered immaterial to the Company’s Unaudited Condensed Consolidated Financial Statements.