NEW JERSEY RESOURCES CORP 10-K

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Should there be a significant change in the underlying market prices or pricing assumptions, ES may experience a significant impact on its financial position, results of operations and cash flows. Refer to Item 7A. Quantitative and Qualitative Disclosures About Market Risks for a sensitivity analysis related to the impact to derivative fair values resulting from changes in commodity prices. The valuation methods we use to determine fair values remained consistent for fiscal 2024, 2023 and 2022. We apply a discount to our derivative assets to factor in an adjustment associated with the credit risk of our physical natural gas counterparties and to our derivative liabilities to factor in an adjustment associated with our own credit risk. We determine this amount by using historical default probabilities corresponding to the appropriate S&P issuer ratings. Since the majority of our counterparties are rated investment grade, this results in an immaterial credit risk adjustment. Gains and losses associated with derivatives utilized by NJNG to manage the price risk inherent in its natural gas purchasing activities are recoverable through its BGSS, subject to BPU approval. Accordingly, the offset to the change in fair value of these derivatives is recorded as either a regulatory asset or liability on the Consolidated Balance Sheets. The Company hedges certain of its expected production of SRECs through forward and futures contracts. Upon physical delivery of SRECs to the counterparty, the Company recognizes SREC revenue as operating revenue on the Consolidated Statements of Operations. We have not designated any derivatives as fair value or cash flow hedges as of September 30, 2024 and 2023. Income Taxes The determination of our provision for income taxes requires the use of estimates and the interpretation and application of tax laws. Judgment is required in assessing the deductibility and recoverability of certain tax benefits. We use the asset and liability method to determine and record deferred tax assets and liabilities, representing future tax benefits and taxes payable, which result from the differences in basis recorded in GAAP financial statements and amounts recorded in the income tax returns. The deferred tax assets and liabilities are recorded utilizing the statutorily enacted tax rates expected to be in effect at the time the assets are realized and/or the liabilities settled. An offsetting valuation allowance is recorded when it is more likely than not that some or all of the deferred income tax assets won’t be realized. Any significant changes to the estimates and judgments with respect to the interpretations, timing or deductibility could result in a material change to earnings and cash flows. For state income tax and other taxes, estimates and judgments are required with respect to the apportionment among the various jurisdictions. In addition, we operate within multiple tax jurisdictions and are subject to audits in these jurisdictions. These audits can involve complex issues, which may require an extended period of time to resolve. We maintain a liability for the estimate of potential income tax exposure and, in our opinion, adequate provisions for income taxes have been made for all years reported. Any significant changes to the estimates and judgments with respect to the apportionment factor could result in a material change to earnings and cash flows. Occasionally, the federal and state taxing authorities determine that it is necessary to make certain changes to the income tax laws. These changes may include but are not limited to changes in the tax rates and/or the treatment of certain items of income or expense. Accounting guidance requires that the Company reflect the effect of changes in tax laws or tax rates at the date of enactment. Additionally, the Company is required to re-measure its deferred tax assets and liabilities as of the date of enactment. For non-regulated entities, the effects of changes in tax laws or tax rates are required to be included in income from continuing operations for the period that includes the enactment date. For regulated entities, if as the result of an action by a regulator it is probable that the future increase or decrease in taxes payable for items such as changes in tax laws or rates will be recovered from or returned to customers through future rates, an asset or liability shall be recognized for that probable increase or decrease in future revenue. Accounting guidance also requires that regulatory liabilities and/or assets be considered a temporary difference for which a related deferred tax asset and/or liability shall be recognized. Accounting guidance requires that we establish reserves for uncertain tax positions when it is more likely than not that the positions will not be sustained when challenged by taxing authorities. Any changes to the estimates and judgments with respect to the interpretations, timing or deductibility could result in a change to earnings and cash flows. Interest and penalties related to unrecognized tax benefits, if any, are recognized within income tax expense, and accrued interest and penalties are recognized within accrued taxes on the Consolidated Balance Sheets. Page 33 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) To the extent that NJNG invests in property that qualifies for ITCs, the ITC is deferred and amortized to income over the life of the equipment in accordance with regulatory treatment. In general, for our unregulated subsidiaries, we record ITCs on the balance sheet as a contra-asset as a reduction to property, plant and equipment when the property is placed in service. The contra-asset is amortized on the Consolidated Statements of Operations as a reduction to depreciation expense over the useful lives of the related assets. Changes to the federal statutes related to ITCs that have the effect of reducing or eliminating the credits could have a negative impact on earnings and cash flows. Recently Issued Accounting Standards Refer to Note 2. Summary of Significant Accounting Policies in the accompanying Consolidated Financial Statements for discussion of recently issued accounting standards. MANAGEMENT’S OVERVIEW Consolidated NJR is a diversified energy services holding company providing retail natural gas service in New Jersey and wholesale natural gas and related energy services to customers in the U.S. In addition, we invest in clean energy projects and storage and transportation assets and provide various repair, sales and installation services. A more detailed description of our organizational structure can be found in Item 1. Business . The following sections include a discussion of results for fiscal 2024 compared to fiscal 2023. The comparative results for fiscal 2023 with fiscal 2022 have been omitted from this Form 10-K, but may be found in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations on Form 10-K of our Annual Report for the fiscal year ended September 30, 2023, filed with the SEC on November 21, 2023. Reporting Segments We have four primary reporting segments as presented in the chart below: In addition to our four reporting segments above, we have nonutility operations that either provide corporate support services or do not meet the criteria to be treated as a separate reporting segment. These operations, which comprise HSO, include appliance repair services, sales and installations at NJRHS and commercial real estate holdings at CR&R. Page 34 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Operating Results Net income (loss) and assets by reporting segment and other business operations for the fiscal years ended September 30, are as follows: (Thousands) 2024 2023 2022 Net Income Assets Net Income Assets Net Income Assets NJNG $ 133,400 $ 4,789,835 $ 131,414 $ 4,414,829 $ 140,124 $ 4,030,686 CEV 33,662 1,157,573 44,458 1,128,577 39,403 1,015,065 ES 106,745 108,710 78,848 123,775 69,650 333,064 S&T 12,229 1,025,457 13,154 1,011,959 26,598 999,520 HSO 26 159,444 4,758 171,275 (781) 159,068 Intercompany (1) 3,713 (259,374) (7,908) (312,919) (72) (275,987) Total $ 289,775 $ 6,981,645 $ 264,724 $ 6,537,496 $ 274,922 $ 6,261,416 (1) Consists of transactions between subsidiaries that are eliminated in consolidation. Consolidated net income increased approximately $25.1M during fiscal 2024, compared with fiscal 2023, due primarily to the following factors: • $27.9M increase in earnings at ES primarily due to increased operating revenue related to the timing of permanent releases of certain capacity related to the AMAs, reduced by unrealized gains and losses on hedging transactions; partially offset by • $10.8M decrease in earnings at CEV due to the reversal of a valuation allowance for certain deferred tax assets during fiscal 2023 that did not reoccur. The primary drivers of the changes noted above are described in more detail in the individual reporting segment and other business operations discussions. Consolidated assets increased approximately $444.1M as of September 30, 2024, compared with September 30, 2023, due primarily to the following factors: • $301.7M increase in utility plant expenditures at NJNG; and • $79.4M increase in nonutility plant and equipment, net at CEV and S&T. Non-GAAP Financial Measures Our management uses NFE, a non-GAAP financial measure, when evaluating our operating results. ES economically hedges its natural gas inventory with financial derivative instruments. NFE is a measure of the earnings based on eliminating timing differences surrounding the recognition of certain gains or losses, to effectively match the earnings effects of the economic hedges with the physical sale of natural gas and, therefore, eliminates the impact of volatility to GAAP earnings associated with the derivative instruments. To the extent we utilize forwards, futures or other derivatives to hedge forecasted SREC production, unrealized gains and losses are also eliminated from NFE. NFE also excludes certain transactions associated with equity method investments, including impairment charges, which are non-cash charges, and return of capital in excess of the carrying value of our investment. These are considered unusual in nature and occur infrequently such that they are not indicative of our performance for ongoing operations. Included in the tax effects are current and deferred income tax expense corresponding with the components of NFE. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for or a replacement of, the comparable GAAP measure and should be read in conjunction with those GAAP results. Page 35 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Below is a reconciliation of consolidated net income, the most directly comparable GAAP measure, to NFE for the fiscal years ended September 30: (Thousands, except per share data) 2024 2023 2022 Net income $ 289,775 $ 264,724 $ 274,922 Add: Unrealized loss (gain) on derivative instruments and related transactions 19,574 (38,081) (59,906) Tax effect (4,652) 9,050 14,248 Effects of economic hedging related to natural gas inventory (1) (18,192) 34,699 19,939 Tax effect 4,323 (8,246) (4,738) Gain on equity method investment — (300) (5,521) Tax effect — (19) 1,377 Net financial earnings $ 290,828 $ 261,827 $ 240,321 Basic earnings per share $ 2.94 $ 2.73 $ 2.86 Add: Unrealized loss (gain) on derivative instruments and related transactions 0.20 (0.39) (0.62) Tax effect (0.05) 0.09 0.15 Effects of economic hedging related to natural gas inventory (1) (0.18) 0.36 0.21 Tax effect 0.04 (0.09) (0.05) Gain on equity method investment — — (0.06) Tax effect — — 0.01 Basic NFE per share $ 2.95 $ 2.70 $ 2.50 (1) Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period. NFE by reporting segment and other business operations for the fiscal years ended September 30, discussed in more detail within the operating results sections of each reporting segment and other business operations, is summarized as follows: (Thousands) 2024 2023 2022 NJNG $ 133,400 46 % $ 131,414 50 % $ 140,124 58 % CEV 33,662 12 44,458 17 39,403 17 ES 111,515 38 68,517 26 39,121 16 S&T 12,229 4 12,835 5 22,454 9 HSO 26 — 4,758 2 (781) — Eliminations (1) (4) — (155) — — — Total $ 290,828 100 % $ 261,827 100 % $ 240,321 100 % (1) Consists of transactions between subsidiaries that are eliminated in consolidation. Consolidated NFE increased approximately $29.0M during fiscal 2024, compared with fiscal 2023, due primarily to the following factors: • $43.0M increase in earnings at ES as a result of higher operating revenues from AMAs, as previously discussed; partially offset by • $10.8M decrease in earnings at CEV due to the reversal of a valuation allowance in fiscal year 2023 that did not reoccur as previously discussed. Natural Gas Distribution Overview Natural Gas Distribution is comprised of NJNG, a natural gas utility that provides regulated natural gas service to residential and commercial customers throughout Burlington, Middlesex, Monmouth, Morris, Ocean and Sussex counties in New Jersey and also participates in the off-system sales and capacity release markets. The business is subject to various risks, which may include but are not limited to impacts to customer growth and customer usage, customer collections, the timing and costs of capital expenditures and construction of infrastructure projects, operating and financing costs, fluctuations in commodity prices and customer conservation efforts. In addition, NJNG may be subject to adverse economic conditions such as inflation and rising natural gas costs, certain regulatory actions, environmental remediation and severe weather conditions. It is often difficult to predict the impact of events or trends associated with these risks. Page 36 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) NJNG’s business is seasonal by nature, as weather conditions directly influence the volume of natural gas delivered to customers on an annual basis. Specifically, customer demand substantially increases during the winter months when natural gas is used for heating purposes. As a result, NJNG generates most of its natural gas distribution revenues during the first and second fiscal quarters and is subject to variations in earnings and working capital during the fiscal year. As a regulated company, NJNG is required to recognize the impact of regulatory decisions on its financial statements. See Note 4. Regulation in the accompanying Consolidated Financial Statements for a more detailed discussion of regulatory actions, including filings related to programs and associated expenditures, as well as rate requests related to recovery of capital investments and operating costs. NJNG’s operations are managed with the goal of providing safe and reliable service, growing its customer base, diversifying its Utility Gross Margin, promoting clean energy programs and mitigating the risks discussed above. Base Rate Case On January 31, 2024, NJNG filed a base rate case with the BPU requesting a natural gas revenue increase of approximately $222.6M including a recovery of infrastructure investments, a change in the Company’s overall rate of return on rate base to 7.57% and a change in the return on common equity to 10.42%. On May 15, 2024, the filing was updated to reflect actual results through March 31, 2024, which reduced the requested increase to approximately $219.6M. On August 7, 2024, the filing was updated to reflect actual results through June 30, 2024, which modified the requested increase to approximately $219.9M. On November 21, 2024, the BPU issued an order adopting a stipulation of settlement approving a $157.0M increase to base rates, effective November 21, 2024. The increase includes an overall rate of return on rate base of 7.08%, return on common equity of 9.6%, a common equity ratio of 54.0% and a composite depreciation rate of 3.21%. Infrastructure Projects NJNG has significant annual capital expenditures associated with the management of its natural gas distribution and transmission system, including new utility plant expenditures associated with customer growth and its associated PIM and infrastructure programs. Below is a summary of NJNG’s capital expenditures, including accruals for fiscal 2024 and estimates of expected investments over the next fiscal year: Estimated capital expenditures are reviewed on a regular basis and may vary based on the ongoing effects of regulatory oversight, environmental regulations, unforeseen events and the ability to access capital. NJNG continues to implement BPU-approved infrastructure projects that are designed to enhance the reliability and integrity of NJNG’s natural gas distribution system. Page 37 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Infrastructure Investment Program In October 2020, the BPU approved NJNG’s five-year IIP filing for $150.0M of transmission and distribution investments, effective November 1, 2020, which will be recovered through annual filings to adjust base rates. In September 2023, the BPU approved NJNG’s annual IIP filing, which requested a rate increase for capital expenditures of $28.2M through June 30, 2023, which resulted in a $3.2M revenue increase, effective October 1, 2023. On March 28, 2024, NJNG submitted its annual IIP filing to the BPU requesting a rate increase for capital expenditures of $43.5M through June 30, 2024. The filing was updated July 26, 2024, to reflect actual expenses of $41.2M. The BPU approved this filing on September 25, 2024, which resulted in a $4.7M revenue increase, effective October 1, 2024. Customer Growth In conducting NJNG’s business, management focuses on factors it believes may have significant influence on its future financial results. NJNG’s policy is to work with all stakeholders, including customers, regulators and policymakers, to achieve favorable results. These factors include the rate of NJNG’s customer growth in its service territory, which can be influenced by political and regulatory policies, the delivered cost of natural gas compared with competing fuels, interest rates and general economic and business conditions. NJNG’s total customers as of September 30, include the following: 2024 2023 2022 Firm customers Residential 528,502 520,682 512,264 Commercial, industrial & other 31,927 31,725 31,227 Residential transport 14,470 15,457 17,316 Commercial transport 7,972 8,033 8,397 Total firm customers 582,871 575,897 569,204 Other 45 103 96 Total customers 582,916 576,000 569,300 During fiscal 2024, 2023 and 2022, NJNG added 8,079, 8,800 and 7,808 new customers, respectively. NJNG expects new customer additions, and those customers who added additional natural gas services to their premises, to contribute approximately $6.8M of incremental Utility Gross Margin on an annualized basis. Energy Efficiency Programs SAVEGREEN conducts home energy audits and provides various grants, incentives and financing alternatives designed to encourage the installation of high-efficiency heating and cooling equipment and other energy efficiency upgrades. Depending on the specific incentive or approval, NJNG recovers costs associated with the programs over a three- to 10-year period through a tariff rider mechanism. In March 2021, the BPU approved a three-year SAVEGREEN program consisting of approximately $126.1M of direct investment, $109.4M in financing options and approximately $23.4M in O&M. In September 2023, the BPU approved an increase to the energy efficiency rate for the SAVEGREEN programs established from 2010 through the present, which increased annual recoveries by $9.0M, effective October 1, 2023. On November 9, 2023, NJNG filed a letter of petition seeking BPU approval to extend NJNG’s current SAVEGREEN program through December 31, 2024, with an additional $76.9M in order to meet customer demand for this program, which was approved by the BPU on April 30, 2024. On December 1, 2023, NJNG filed a petition seeking BPU approval of its 2024 SAVEGREEN program, which would support new energy efficiency, demand response and building decarbonization start-up programs for two-and-a-half-years from January 1, 2025 through June 30, 2027. The 2024 SAVEGREEN program filing, which totals $482.4M, includes $245.1M of direct investment, $217.2M in financing options and $20.1M in O&M. On October 30, 2024, the BPU approved a settlement consisting of $205.0M of direct investment, $160.5M in financing options and $20.1M in O&M, which totals $385.6M. On May 31, 2024, NJNG submitted its annual EE filing with the BPU for the recovery of SAVEGREEN costs, proposing an increase in annual recoveries of approximately $5.6M, to be effective January 1, 2025, if approved. Page 38 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Loans amounted to approximately $37.5M and $23.3M and grants, rebates and related investments amounted to approximately $33.8M and $36.5M during the fiscal years ended September 30, 2024 and 2023, respectively. Program recoveries from customers during the fiscal years ended September 30, 2024 and 2023, were $28.6M and $26.3M, respectively. The recovery includes a weighted average cost of capital that ranges from 6.84% to 6.9%, with a return on equity of 9.6% to 9.75%. Conservation Incentive Program/BGSS The CIP facilitates normalizing NJNG’s Utility Gross Margin for variances due not only to weather but also other factors affecting customer usage, such as conservation and energy efficiency. Recovery of Utility Gross Margin for the non-weather variance through the CIP is limited to the amount of certain natural gas supply cost savings achieved and is subject to a variable margin revenue test. Additionally, recovery of the CIP Utility Gross Margin is subject to an annual earnings test. An annual review of the CIP must be filed by June 1, coincident with NJNG’s annual BGSS filing, during which NJNG can request rate changes to the CIP. NJNG’s total utility firm gross margin includes the following adjustments related to the CIP mechanism: (Thousands) 2024 2023 2022 Weather (1) $ 36,907 $ 44,675 $ 22,263 Usage 9,386 3,276 2,032 Total $ 46,293 $ 47,951 $ 24,295 (1) Compared with the 20-year average, weather was 11.3%, 13.4% and 8.3% warmer-than-normal during fiscal 2024, 2023 and 2022, respectively. Recovery of Natural Gas Costs NJNG’s cost of natural gas is passed through to our customers, without markup, by applying NJNG’s authorized BGSS rate to actual therms delivered. There is no Utility Gross Margin associated with BGSS costs; therefore, changes in such costs do not impact NJNG’s earnings. NJNG monitors its actual natural gas costs in comparison to its BGSS rates to manage its cash flows associated with its allowed recovery of natural gas costs, which is facilitated through BPU-approved deferred accounting and the BGSS pricing mechanism. Accordingly, NJNG occasionally adjusts its periodic BGSS rates or can issue credits or refunds, as appropriate, for its residential and small commercial customers when the commodity cost varies from the existing BGSS rate. BGSS rates for its large commercial customers are adjusted monthly based on NYMEX prices. NJNG’s residential and commercial markets are currently open to competition, and its rates are segregated between BGSS (i.e., natural gas commodity) and delivery (i.e., transportation) components. NJNG earns Utility Gross Margin through the delivery of natural gas to its customers and, therefore, is not negatively affected by customers who use its transportation service and purchase natural gas from another supplier. Under an existing order from the BPU, BGSS can be provided by suppliers other than the state’s natural gas utilities; however, customers who purchase natural gas from another supplier continue to use NJNG for transportation service. In April 2023, the BPU approved, on a final basis, NJNG’s February 2023 filing for a reduction to the BGSS rate, which reduced annual recoveries by approximately $29.9M, effective March 1, 2023. NJNG’s February 2023 filing also advised the BPU of a bill credit for residential and small commercial customers. Total bill credits given back to customers from March 2023 through May 2023, totaled approximately $32.4M. On April 30, 2024, the BPU approved, on a final basis, NJNG's June 2023 annual filing, which included a decrease of approximately $38.6M to the annual revenues credited to BGSS, an annual decrease of approximately $7.4M related to its balancing charge and an increase of approximately $27.0M to CIP rates for residential and small business customers, effective October 1, 2023. On September 25, 2024, the BPU approved, on a provisional basis, NJNG’s May 2024 annual filing, which included a decrease of approximately $31.0M to the annual revenues credited to BGSS, an annual increase of approximately $40.3M related to its balancing charge and a decrease of approximately $0.8M to CIP rates, effective October 1, 2024. The balancing charge rate includes the cost of balancing natural gas deliveries with customer usage for sales and transportation customers, and balancing charge revenues are credited to BGSS. Page 39 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) BGSS Incentive Programs NJNG is eligible to receive financial incentives for reducing BGSS costs through a series of Utility Gross Margin-sharing programs that include off-system sales, capacity release and storage incentive programs. These programs are designed to encourage better utilization and hedging of NJNG’s natural gas supply and transportation and storage assets. Depending on the program, NJNG shares 80 or 85% of Utility Gross Margin generated by these programs with firm customers. Utility Gross Margin from incentive programs was $17.9M, $20.0M and $19.6M during the fiscal years ended September 30, 2024, 2023 and 2022, respectively. Hedging In order to provide relative price stability to its natural gas supply portfolio, NJNG employs a hedging strategy with the goal of having at least 75% of the Company’s projected winter periodic BGSS natural gas sales volumes hedged by each November 1 and at least 25% of the projected periodic BGSS natural gas sales hedged for the following April-through-March period. The hedging goal is typically achieved with gas in storage and the use of financial instruments to hedge storage injections. NJNG may also use various financial instruments including futures, swaps, options and weather-related products to hedge its future delivery obligations. Commodity Prices NJNG is affected by the price of natural gas, which can have a significant impact on our cash flows and short-term financing costs, the price of natural gas charged to our customers through the BGSS clause, our ability to collect accounts receivable, which impacts our bad debt expense, and our ability to maintain a competitive advantage over other energy sources. Natural gas commodity prices are shown in the graph below, which illustrates the daily natural gas prices (1) in the Northeast market region, also known as TETCO M-3. (1) Data sourced from Standard & Poor’s Financial Services, LLC Global Platts. The maximum price per MMBtu was $20.98, $32.46 and $17.69 and the minimum price was $0.89, $0.67 and $2.42 for the fiscal years ended September 30, 2024, 2023 and 2022, respectively. A more detailed discussion of the impacts of the price of natural gas on operating revenues, natural gas purchases and cash flows can be found in the Operating Results and Cash Flow sections of Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations . Page 40 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Societal Benefits Charge NJNG’s qualifying customers are eligible for the USF program, which is administered by the New Jersey Department of Community Affairs, to help make energy bills more affordable. In April 2023, the BPU approved on a final basis NJNG’s annual SBC filing, which included an increase to the RAC annual recoveries of approximately $3.7M and a decrease to the NJCEP annual recoveries of approximately $0.9M, effective May 1, 2023. In September 2023, the BPU approved NJNG’s annual USF filing, which included an increase to the statewide USF rate of approximately $0.7M, effective October 1, 2023. On March 20, 2024, the BPU approved NJNG’s annual SBC filing of RAC expenditures through June 30, 2023, which included an increase to the RAC annual recoveries of approximately $2.4M and an increase to the NJCEP annual recoveries of approximately $5.5M, effective April 1, 2024. On June 28, 2024, NJNG submitted its annual USF filing to the BPU requesting an increase to the statewide USF rate. On September 25, 2024, the BPU approved the filing, which resulted in a $6.8M increase to annual recoveries, effective October 1, 2024. On September 30, 2024, NJNG submitted its annual SBC filing to the BPU requesting approval of RAC expenditures through June 2024, which included an increase to the RAC annual recoveries of approximately $2.4M and an increase to the NJCEP annual recoveries of approximately $1.6M, which would be effective April 1, 2025. Environmental Remediation NJNG is responsible for the environmental remediation of former MGP sites, which contain contaminated residues from former gas manufacturing operations that ceased operating at these sites by the mid-1950s and, in some cases, had been discontinued many years earlier. Actual MGP remediation costs may vary from management’s estimates due to the developing nature of remediation requirements, regulatory decisions by the NJDEP and related litigation. NJNG reviews these costs periodically, and at least annually, and adjusts its liability and corresponding regulatory asset as necessary to reflect its expected future remediation obligation. Accordingly, NJNG recognized a regulatory asset and an obligation of $161.7M as of September 30, 2024, a decrease of $7.8M compared with the prior fiscal period. See Note 14. Commitments and Contingent Liabilities for a more detailed description of MGP expenditures. Other regulatory filings and a more detailed discussion of the filings in this section can be found in Note 4. Regulation in the accompanying Consolidated Financial Statements. Page 41 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Operating Results NJNG’s operating results for the fiscal years ended September 30, are as follows: (Thousands) 2024 2023 2022 Operating revenues (1) $ 1,019,832 $ 1,012,633 $ 1,128,767 Operating expenses Natural gas purchases (2) (3) 414,635 425,457 557,232 Operation and maintenance 225,260 226,780 198,546 Regulatory rider expense (4) 60,327 50,542 59,437 Depreciation and amortization 112,492 102,326 94,579 Total operating expenses 812,714 805,105 909,794 Operating income 207,118 207,528 218,973 Other income, net 20,363 13,546 7,686 Interest expense, net of capitalized interest 62,288 56,595 46,394 Income tax provision 31,793 33,065 40,141 Net income $ 133,400 $ 131,414 $ 140,124 (1) Includes nonutility revenue of approximately $1.4M, $1.3M and $1.4M for fiscal 2024, 2023 and 2022, respectively, for lease agreements with various NJR subsidiaries leasing office space from NJNG at the Company’s headquarters, which are eliminated in consolidation. (2) Includes the purchased cost of the natural gas, fees paid to pipelines and storage facilities, adjustments as a result of BGSS incentive programs and hedging transactions. These expenses are passed through to customers and are offset by corresponding revenues. (3) Includes related party transactions of approximately $9.3M for fiscal 2024, 2023 and 2022, a portion of which is eliminated in consolidation. (4) Consists of expenses associated with state-mandated programs, the RAC and energy efficiency programs, which are calculated on a per-therm basis. These expenses are passed through to customers and are offset by corresponding revenues. Operating Revenues and Natural Gas Purchases Operating revenues increased 0.7% during fiscal 2024 compared with fiscal 2023. Natural gas purchases decreased 2.5% during fiscal 2024 compared with fiscal 2023. The factors contributing to the increases and decreases in operating revenues and natural gas purchases during fiscal 2024 are as follows: 2024 v. 2023 (Thousands) Operating revenues Natural gas purchases BGSS incentives $ 15,264 $ 17,408 Bill credits 31,581 31,581 Firm sales 17,255 6,470 Average BGSS rates (64,786) (64,786) CIP adjustments (1,658) — Riders and other (1) 9,543 (1,495) Total increase (decrease) $ 7,199 $ (10,822) (1) Riders and other includes changes in rider rates, including those related to Energy Efficiency, NJCEP and other programs, which is offset in regulatory rider expense. Non-GAAP Financial Measures Management uses Utility Gross Margin, a non-GAAP financial measure, when evaluating the operating results of NJNG. NJNG’s Utility Gross Margin is defined as operating revenues less natural gas purchases, sales tax and regulatory rider expenses. This measure differs from gross margin as presented on a GAAP basis, as it excludes certain operations and maintenance expense and depreciation and amortization. Utility Gross Margin may also not be comparable to the definition of gross margin used by others in the natural gas distribution business and other industries. Management believes that Utility Gross Margin provides a meaningful basis for evaluating utility operations since natural gas costs, sales tax and regulatory rider expenses are included in operating revenues and passed through to customers and, therefore, have no effect on Utility Gross Margin. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measure. Page 42 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Utility Gross Margin A reconciliation of gross margin, the closest GAAP financial measure to NJNG’s Utility Gross Margin for the fiscal years ended September 30, is as follows: (Thousands) 2024 2023 2022 Operating revenues $ 1,019,832 $ 1,012,633 $ 1,128,767 Less: Natural gas purchases 414,635 425,457 557,232 Operation and maintenance (1) 113,984 115,292 93,164 Regulatory rider expense 60,327 50,542 59,437 Depreciation and amortization 112,492 102,326 94,579 Gross margin 318,394 319,016 324,355 Add: Operation and maintenance (1) 113,984 115,292 93,164 Depreciation and amortization 112,492 102,326 94,579 Utility Gross Margin $ 544,870 $ 536,634 $ 512,098 (1) Excludes SG&A of approximately $111.3M, $111.5M and $102.8M for the fiscal years 2024, 2023 and 2022, respectively. Utility Gross Margin consists of three components: • Utility firm gross margin generated from only the delivery component of either a sales tariff or a transportation tariff from residential and commercial customers who receive natural gas service from NJNG; • BGSS incentive programs, where revenues generated or savings achieved from BPU-approved off-system sales, capacity release or storage incentive programs are shared between customers and NJNG; and • Utility Gross Margin generated from off-tariff customers, as well as interruptible customers. The following provides more information on the components of Utility Gross Margin and associated throughput (Bcf) of natural gas delivered to customers: 2024 2023 2022 ($ in thousands) Margin Bcf Margin Bcf Margin Bcf Utility Gross Margin/Throughput Residential $ 369,522 44.5 $ 360,138 43.4 341,167 45.5 Commercial, industrial and other 78,033 8.5 76,550 8.4 77,629 8.7 Firm transportation 75,641 11.7 76,114 12.1 69,933 13.0 Total utility firm gross margin/throughput 523,196 64.7 512,802 63.9 488,729 67.2 BGSS incentive programs 17,876 85.0 20,020 72.6 19,587 95.2 Interruptible/off-tariff agreements 3,798 25.8 3,812 29.5 3,782 32.4 Total Utility Gross Margin/Throughput $ 544,870 175.5 $ 536,634 166.0 $ 512,098 194.8 Utility Firm Gross Margin Utility firm gross margin increased approximately $10.4M during fiscal 2024 compared with fiscal 2023, due primarily to an increase in customers. Page 43 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) BGSS Incentive Programs The factors contributing to the change in Utility Gross Margin generated by BGSS incentive programs are as follows: (Thousands) 2024 v. 2023 Storage $ (1,454) Capacity release (139) Off-system sales (551) Total decrease $ (2,144) The decrease in BGSS incentive programs was due primarily to decreased margins from storage incentives along with lower off-system sales margin due to less market volatility and lower capacity release volumes. Net Income Net income increased approximately $2.0M during fiscal 2024, compared with fiscal 2023, due primarily to the following factors: • $8.2M increase in Utility Gross Margin, as previously discussed; • $6.8M increase in other income, net resulting from the remeasurement of the Company's other postretirement benefits; and • $1.5M decrease in O&M due to lower consulting fees; partially offset by • $10.2M increase in depreciation expense as a result of additional utility plant being placed into service; and • $5.7M increase in interest expense due to higher outstanding long-term debt. Clean Energy Ventures Overview CEV actively pursues opportunities in the renewable energy markets, which includes the development, construction and operation of net-metered and grid-connected commercial solar projects. In addition, CEV enters into various long-term agreements, including PPAs, to supply energy from commercial solar projects. Capital expenditures related to clean energy projects are subject to change due to a variety of factors that may affect our ability to commence operations at these projects on a timely basis or at all, including logistics associated with the start-up of commercial solar projects, such as timing of construction schedules, the permitting and regulatory process, any delays related to electric grid interconnection, economic trends, unforeseen events and the ability to access capital or allocation of capital to other investments or business opportunities. CEV is also subject to various risks, which may include our ability to identify and develop commercial solar asset investments, impacts to our supply chain and our ability to source materials for construction. The primary contributors toward the value of qualifying clean energy projects are tax incentives, RECs and electricity sales. Changes in the federal statutes related to the ITC and/or relevant state legislation and regulatory policies affecting the market for solar renewable energy credits could significantly affect future results. Solar projects placed in service and related expenditures for the fiscal years ended September 30, are as follows: ($ in Thousands) 2024 2023 2022 Placed in service Projects MW Costs Projects MW Costs Projects MW Costs Grid-connected (1) — — $ — 5 42.0 $ 106,558 3 14.0 $ 31,411 Net-metered: Commercial (1) (2) 2 5.1 18,931 5 36.1 50,610 2 1.0 2,440 Sunlight Advantage® 282 3.4 10,660 339 4.1 12,677 360 3.9 11,544 Total placed in service 284 8.5 $ 29,591 349 82.2 $ 169,845 365 18.9 $ 45,395 (1) Includes projects subject to sale leaseback arrangements. (2) Fiscal 2023 includes two operational commercial solar projects acquired in July 2023, totaling 20.7 MW. Page 44 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) As of September 30, 2024, CEV has approximately 477 MW of solar capacity in service. Projects that were placed in service through December 31, 2019, qualified for a 30% federal ITC. The credit declined to 26% for property under construction during 2020 through the end of 2022. In August 2022, the federal ITC was restored to 30% through the end of 2032. There are additional opportunities to increase the credit amount for certain facilities that are placed in service after December 31, 2022, based upon the type of project and location. CEV may enter into transactions to sell certain of its commercial solar assets concurrent with agreements to lease the assets back over a period of five to seven years. The Company will continue to operate the 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 if applicable; however, the lease payments are structured so that CEV is compensated for the transfer of the related tax incentives. Accordingly, for solar projects financed under sale leasebacks for which the assets were sold during the first five years of in-service life, CEV 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. During fiscal 2024, 2023 and 2022, CEV received proceeds of $64.7M, $167.8M and $24.1M, respectively, in connection with the sale leaseback of commercial solar assets. As part of its solar investment portfolio, CEV operates a residential and small commercial solar program, The Sunlight Advantage®, which provides qualifying homeowners and small business owners with the opportunity to have a solar system installed at their home or place of business with no installation or maintenance expenses. CEV owns, operates and maintains the system over the life of the lease in exchange for monthly lease payments. The program is operated by CEV using qualified contracting partners in addition to strategic suppliers for material standardization and sourcing. On November 25, 2024, CEV completed the sale of its 91 MW residential solar portfolio, and related assets and liabilities included in The Sunlight Advantage® program to a third party for a total purchase price of $132.5M. For solar installations placed in-service in New Jersey prior to April 30, 2020, each MWh of electricity produced creates an SREC that represents the renewable energy attribute of the solar-electricity generated that can be sold to third parties, predominantly load-serving entities that are required to comply with the solar requirements under New Jersey’s renewable portfolio standard. Following the close of the SREC market in New Jersey, the BPU established the TREC as the successor program to the SREC program. 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. All TRECs generated are required to be purchased monthly by a TREC program administrator as appointed by the BPU. In July 2021, the BPU established a new successor solar incentive program. This ADI Program provides administratively set incentives for net metered projects of 5 MW or less. RECs generated through the production of electricity under this program are known as SREC IIs. In December 2022, the BPU established the CSI program, which provides incentives to larger solar facilities. It 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. Pricing is determined based on a competitive bid solicitation process. REC activity consisted of the following: Inventory balance as of October 1, RECs Inventory balance as of September 30, Average Generated Delivered Sale Price 2024 SRECs 144,138 402,056 (419,266) 126,928 $197 TRECs (1) 10,120 93,913 (92,796) 11,237 $141 SREC IIs (1) 6,013 19,087 (20,078) 5,022 $90 2023 SRECs 116,005 422,039 (393,906) 144,138 $202 TRECs 10,759 80,520 (81,159) 10,120 $144 SREC IIs 247 10,260 (4,494) 6,013 $90 (1) TREC and SREC II inventory balances are due primarily to the timing of generation and when RECs are delivered to the state administrator. Page 45 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) CEV hedges its expected SREC production through the use of forward sales contracts. The following table reflects the hedged percentage of our projected inventory of SRECs related to CEV’s in-service commercial and residential assets at September 30, 2024: Energy Year (1) Percent of SRECs Hedged 2025 90% 2026 89% 2027 51% 2028 39% (1) Energy years are compliance periods for New Jersey’s renewable portfolio standard that run from June 1 to May 31. There are no direct costs associated with the production of RECs by our solar assets. All related costs are included as a component of O&M on the Consolidated Statements of Operations, including such expenses as facility maintenance and broker fees. Operating Results CEV’s financial results for the fiscal years ended September 30, are summarized as follows: (Thousands) 2024 2023 2022 Operating revenues $ 130,563 $ 124,131 $ 128,280 Operating expenses Operation and maintenance 44,042 40,089 40,706 Depreciation and amortization 27,869 25,320 21,396 Total operating expenses 71,911 65,409 62,102 Operating income 58,652 58,722 66,178 Other income, net 14,961 6,622 6,554 Interest expense, net 28,545 28,569 21,968 Income tax provision (benefit) 11,406 (7,683) 11,361 Net income $ 33,662 $ 44,458 $ 39,403 Net income decreased approximately $10.8M during fiscal 2024, compared with fiscal 2023, due primarily to the following factors: • $19.1M increase in income tax expense due primarily to the reversal of a valuation allowance for certain deferred tax assets during fiscal 2023 that did not reoccur; and • $4.0M increase in O&M due to higher project maintenance expenses and lease expenses; partially offset by • $8.3M increase in other income, net due primarily to the recognition of ITCs associated with solar sale leaseback financing transactions; and • $6.4M increase in operating revenues due to higher SREC, TREC and electricity sales. Energy Services Overview ES markets and sells natural gas to wholesale and retail customers and manages natural gas transportation and storage assets throughout major market areas across North America. ES maintains a strategic portfolio of natural gas transportation and storage contracts that it utilizes in conjunction with its market expertise to provide service and value to its customers. Availability of these transportation and storage contracts allows ES to generate market opportunities by capturing price differentials over specific time horizons and between geographic market locations. ES also provides management of transportation and storage assets for natural gas producers and regulated utilities. These management transactions typically involve the release of producer/utility-owned storage and/or transportation capacity in combination with an obligation to purchase and/or deliver physical natural gas. In addition to the contractual purchase and/or sale of physical natural gas, ES generates or pays fee-based margin in exchange for its active management and may provide the producer and/or utility with additional margin based on actual results. Page 46 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) In conjunction with the active management of these contracts, ES generates Financial Margin by identifying market opportunities and simultaneously entering into natural gas purchase/sale, storage or transportation contracts and financial derivative contracts. In cases where storage is utilized to fulfill these contracts, these forecast sales and/or purchases are economically hedged through the use of financial derivative contracts. The financial derivative contracts consist primarily of exchange-traded futures, options and swap contracts, and are frequently used to lock in anticipated transactional cash flows and to help manage volatility in natural gas market prices. Generally, when its transportation and storage contracts are exposed to periods of increased market volatility, ES is able to implement strategies that allow it to capture margin by improving the respective time or geographic spreads on a forward basis. ES accounts for its physical commodity contracts and its financial derivative instruments at fair value on the Consolidated Balance Sheets. Changes in the fair value of physical commodity contracts and financial derivative instruments are included in earnings as a component of operating revenues or natural gas purchases on the Consolidated Statements of Operations. Volatility in reported net income at ES can occur over periods of time due to changes in the fair value of derivatives, as well as timing differences related to certain transactions. Unrealized gains and losses can fluctuate as a result of changes in the price of natural gas and SRECs from the original transaction price. Volatility in earnings can also occur as a result of timing differences between the settlement of financial derivatives and the sale of the underlying physical commodity. For example, when a financial instrument settles and the physical natural gas is injected into inventory, the realized gains and losses associated with the financial instrument are recognized in earnings. However, the gains and losses associated with the physical natural gas are not recognized in earnings until the natural gas inventory is withdrawn from storage and sold, at which time ES realizes the entire margin on the transaction. During December 2020, ES entered into a series of AMAs with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts. The utility provides certain asset management services, and ES may deliver natural gas to the utility in exchange for aggregate net proceeds of approximately $500M, payable through November 1, 2030. The AMAs include a series of initial and permanent releases, which commenced in November 2021. NJR received a total of approximately $260M in cash from fiscal 2022 through fiscal 2024 and will receive approximately $34M per year from fiscal 2025 through fiscal 2031 under the agreements. During fiscal 2024 and 2023, ES recognized $137.2M and $48.5M, respectively, of operating revenue related to the AMAs on the Consolidated Statements of Operations. Amounts received in excess of revenue, totaling $22.3M and $58.7M as of September 30, 2024 and 2023, respectively, are included in deferred revenue on the Consolidated Balance Sheets. Operating Results ES’s financial results for the fiscal years ended September 30, are summarized as follows: (Thousands) 2024 2023 2022 Operating revenues (1) $ 485,391 $ 691,616 $ 1,529,272 Operating expenses Natural gas purchases (including demand charges (2)(3) ) 305,938 558,932 1,394,405 Operation and maintenance 24,969 19,351 39,080 Depreciation and amortization 205 221 148 Total operating expenses 331,112 578,504 1,433,633 Operating income 154,279 113,112 95,639 Other income, net 1,030 1,479 512 Interest expense, net 15,233 11,400 4,725 Income tax provision 33,331 24,343 21,776 Net income $ 106,745 $ 78,848 $ 69,650 (1) Includes related party transactions of approximately $(4.9)M, $10.2M and $0.1M for fiscal 2024, 2023 and 2022, respectively, which are eliminated in consolidation. (2) Costs associated with pipeline and storage capacity are expensed over the term of the related contracts, which generally varies from less than one year to 10 years. (3) Includes related party transactions of approximately $1.2M, $0.9M and $1.0M for fiscal 2024, 2023 and 2022, respectively, a portion of which is eliminated in consolidation. Page 47 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) ES’s portfolio of financial derivative instruments is composed of: (in Bcf) 2024 2023 2022 Net short futures and swaps contracts 7.7 6.9 0.7 During fiscal 2024, 2023 and 2022 the net short position resulted in unrealized gains (losses) of $3.1M, $16.2M and $(8.5)M, respectively. Operating revenues decreased approximately $206.2M and natural gas purchases decreased approximately $253.0M during fiscal 2024, compared with fiscal 2023, due primarily to a 36.0% decrease in natural gas prices, partially offset by increased operating revenue related to the timing of permanent releases of certain capacity related to the AMAs. Future results at ES are contingent upon natural gas market price volatility driven by variations in both the supply and demand balances caused by weather and other factors. As a result, variations in weather patterns in the key market areas served may affect earnings during the fiscal year. Changes in market fundamentals, such as an increase in supply and decrease in demand due to warmer temperatures and reduced volatility, can negatively impact ES’s earnings. See Item 7. Management ’ s Discussion and Analysis of Financial Condition and Results of Operations - Natural Gas Distribution for TETCO M-3 Daily Prices, which illustrates the daily natural gas prices in the Northeast market region. Net income increased approximately $27.9M during fiscal 2024, compared with fiscal 2023, due primarily to the following factors: • $253.0M decrease in natural gas purchases, as previously discussed; partially offset by • $206.2M decrease in operating revenues, as previously discussed; • $9.0M increase in income tax expense related to higher operating income; • $5.6M increase in O&M due to higher employee-related expenses and a reduction in the reserve for bad debt in the prior year; and • $3.8M increase in interest expense due to increased borrowings and higher interest rates. Non-GAAP Financial Measures Management uses Financial Margin and NFE, non-GAAP financial measures, when evaluating the operating results of ES. Financial Margin and NFE are based on removing timing differences associated with certain derivative instruments. Management views these measures as representative of the overall expected economic result and uses these measures to compare ES’s results against established benchmarks and earnings targets, as these measures eliminate the impact of volatility on GAAP earnings as a result of timing differences associated with the settlement of derivative instruments. To the extent that there are unanticipated impacts from changes in the market value related to the effectiveness of economic hedges, ES’s actual non-GAAP results can differ from the results anticipated at the outset of the transaction. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measure. When ES reconciles the most directly comparable GAAP measure to both Financial Margin and NFE, the current period unrealized gains and losses on derivatives are excluded as a reconciling item. Financial Margin and NFE also exclude the effects of economic hedging of the value of our natural gas in storage and, therefore, only include realized gains and losses related to natural gas withdrawn from storage, effectively matching the full earnings effects of the derivatives with realized margins on the related physical natural gas flows. To the extent we utilize forwards, futures or other derivatives to hedge natural gas transactions and forecasted SREC production, the resulting unrealized gains and losses are also eliminated from NFE. Financial Margin differs from gross margin as defined on a GAAP basis, as it excludes certain operations and maintenance expense and depreciation and amortization as well as the effects of derivatives, as discussed above. Page 48 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Financial Margin A reconciliation of gross margin, the closest GAAP financial measure, to ES’s Financial Margin is as follows: (Thousands) 2024 2023 2022 Operating revenues (1) $ 485,391 $ 691,616 $ 1,529,272 Less: Natural gas purchases 305,938 558,932 1,394,405 Operation and maintenance (2) 23,189 20,199 23,709 Depreciation and amortization 205 221 148 Gross margin 156,059 112,264 111,010 Add: Operation and maintenance (2) 23,189 20,199 23,709 Depreciation and amortization 205 221 148 Unrealized loss (gain) on derivative instruments and related transactions 24,449 (48,251) (60,000) Effects of economic hedging related to natural gas inventory (3) (18,192) 34,699 19,939 Financial Margin $ 185,710 $ 119,132 $ 94,806 (1) Includes unrealized (gains) losses related to intercompany transactions between NJNG and ES that have been eliminated in consolidation of approximately $(4.9)M, $7.8M and $0.1M for fiscal 2024, 2023 and 2022, respectively. (2) Excludes SG&A of approximately $1.8M, $(0.8)M and $15.4M for fiscal 2024, 2023 and 2022, respectively. (3) Effects of hedging natural gas inventory transactions where the economic impact is realized in a future period. Financial Margin increased approximately $66.6M during fiscal 2024, compared with fiscal 2023, due primarily to increased operating revenue related to the AMAs, as previously discussed, partially offset by higher natural gas price volatility in fiscal 2023 as a result of cold weather in regions where ES had contracted rights to transportation and storage assets. Net Financial Earnings A reconciliation of ES’s net income, the most directly comparable GAAP financial measure to NFE, is as follows for the fiscal years ended September 30: (Thousands) 2024 2023 2022 Net income $ 106,745 $ 78,848 $ 69,650 Add: Unrealized loss (gain) on derivative instruments and related transactions 24,449 (48,251) (60,000) Tax effect (1) (5,810) 11,467 14,270 Effects of economic hedging related to natural gas inventory (18,192) 34,699 19,939 Tax effect 4,323 (8,246) (4,738) Net financial earnings $ 111,515 $ 68,517 $ 39,121 (1) Includes taxes related to intercompany transactions between NJNG and ES that have been eliminated in consolidation of approximately $1.2M and $(2.4)M for fiscal 2024 and 2023, respectively. Taxes that were eliminated in consolidation during fiscal 2022 were immaterial. NFE increased approximately $43.0M during fiscal 2024, compared with fiscal 2023, due primarily to higher Financial Margin, as previously discussed. Future results are subject to the ability of ES to expand its wholesale sales and service activities and are contingent upon many other factors, including an adequate number of appropriate and credit-qualified counterparties in an active and liquid natural marketplace; volatility in the natural gas market due to weather or other fundamental market factors impacting supply and/or demand; transportation, storage and/or other market arbitrage opportunities; sufficient liquidity in the overall energy trading market; and continued access to liquidity in the capital markets. Page 49 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Storage and Transportation Overview S&T invests in natural gas assets, such as natural gas transportation and storage facilities. We believe that acquiring, owning and developing these storage and transportation assets, which operate under a tariff structure that has either cost- or market-based rates, can provide us organic growth opportunities. S&T is subject to various risks, including the construction, development and operation of our transportation and storage assets, as well as our ability to obtain necessary governmental, environmental and regulatory approvals, property rights and financing at reasonable costs for the construction, operation and maintenance of our assets. S&T is comprised of Leaf River, a 32.2M Dth salt dome natural gas storage facility that operates under market-based rates, and Adelphia, a FERC-regulated interstate pipeline in southeastern Pennsylvania that operates under cost-of-service rates but can enter into negotiated rates with counterparties. The northern portion of the pipeline was operational upon acquisition, and currently serves two natural gas generation facilities.The southern zone of the pipeline became fully operational in September 2022. On September 30, 2024, Adelphia filed a Section 4 rate case with the FERC seeking approval to revise its transportation cost-of-service rates to reflect investments made in its pipeline system, as well as the ongoing costs of operating and maintaining the system. Adelphia anticipates that FERC will allow it to place the rates into effect during the second half of 2025, subject to refund and the outcome of a hearing to be established by FERC. S&T has a 50% ownership interest in Steckman Ridge, a storage facility located in western Pennsylvania that operates under market-based rates. As of September 30, 2024, our investment in Steckman Ridge was $101.7M. S&T also had a 20% interest in PennEast, a partnership whose purpose was to construct and operate a 120-mile natural gas pipeline that would have extended from northeast Pennsylvania to western New Jersey. During fiscal 2021, we evaluated our equity investment in PennEast for impairment and determined that it was other-than-temporarily impaired. In December 2021, the PennEast project ceased further development. During fiscal 2022, the PennEast board of managers approved cash distributions to members of the partnership following the sale of certain project-related assets and refunds of interconnection fees received from interstate pipelines. The return of capital received by the Company, which totaled $11.0M, reduced the remaining carrying value of its equity method investment in PennEast to zero, with the excess recorded in equity in earnings (loss) of affiliates in the Consolidated Statements of Operations. The Company received additional return of capital of $0.3M during fiscal 2023, which is recognized in equity in earnings of affiliates in the Consolidated Statements of Operations. Operating Results The financial results of S&T for the fiscal years ended September 30, are summarized as follows: (Thousands) 2024 2023 2022 Operating revenues (1) $ 96,209 $ 92,859 $ 67,735 Operating expenses Natural gas purchases 1,028 1,601 2,702 Operation and maintenance 43,083 34,648 30,568 Depreciation and amortization 24,900 24,185 12,302 Total operating expenses 69,011 60,434 45,572 Operating income 27,198 32,425 22,163 Other income, net 10,207 6,850 8,546 Interest expense, net 23,441 25,803 12,097 Income tax provision 4,551 3,444 1,879 Equity in earnings of affiliates 2,816 3,126 9,865 Net income $ 12,229 $ 13,154 $ 26,598 (1) Includes related party transactions of approximately $1.4M, $4.2M and $2.4M for the fiscal years ended September 30, 2024, 2023 and 2022, respectively, which are eliminated in consolidation. Page 50 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Net income decreased approximately $0.9M during fiscal 2024, compared with fiscal 2023, due primarily to the following factors: • $8.4M increase in O&M due to increased employee-related expenses and consulting fees; partially offset by • $3.4M increase in operating revenues due to higher fixed price contract revenue for Adelphia; and • $3.4M increase in other income due to increased interest income from the outstanding loan with Steckman Ridge, as a result of higher interest rates. Non-GAAP Financial Measures Management uses NFE, a non-GAAP financial measure, when evaluating the operating results of S&T. Certain transactions associated with equity method investments and their impact, including impairment charges, which are non-cash charges, and the return of capital in excess of the carrying value of our investment, are excluded for NFE purposes. The details of such adjustments can be found in the table below. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP, and should be considered in addition to, and not as a substitute for, the comparable GAAP measure. A reconciliation of S&T’s net income, the most directly comparable GAAP financial measure to NFE, is as follows: (Thousands) 2024 2023 2022 Net income $ 12,229 $ 13,154 $ 26,598 Add: Gain on equity method investment — (300) (5,521) Tax effect — (19) 1,377 Net financial earnings $ 12,229 $ 12,835 $ 22,454 NFE decreased $0.6M during fiscal 2024, compared with fiscal 2023, due to lower net income, as previously discussed. Home Services and Other Overview The financial results of HSO consist primarily of the operating results of NJRHS. NJRHS provides service, sales and installation of appliances to service contract customers and has been focused on growing its installation business and expanding its service contract customer base. HSO also includes organizational expenses incurred at NJR. Operating Results The condensed financial results of HSO for the fiscal years ended September 30, are summarized as follows: (Thousands) 2024 2023 2022 Operating revenues $ 62,635 $ 57,638 $ 56,182 Income before income taxes $ 2,692 $ 3,281 $ 278 Income tax provision (benefit) 2,666 (1,477) 1,059 Net income (loss) $ 26 $ 4,758 $ (781) Net income decreased approximately $4.7M during fiscal 2024, compared with fiscal 2023, due primarily to the following factors: • $4.6M increase in O&M due to increased employee-related and contractor expenses; and • $4.1M increase in income tax expense due to a tax benefit in fiscal 2023 that did not reoccur; partially offset by • $5.0M increase in operating revenues due to higher installation and service contract revenue at NJRHS. Page 51 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Liquidity and Capital Resources Our objective is to maintain an efficient consolidated capital structure that reflects the different characteristics of each reporting segment and other business operations and provides adequate financial flexibility for accessing capital markets as required. Our consolidated capital structure as of September 30, was as follows: 2024 2023 Common stock equity 39 % 39 % Long-term debt 52 54 Short-term debt 9 7 Total 100 % 100 % Common Stock Equity We satisfy our external common equity requirements, if any, through issuances of our common stock, including the proceeds from stock issuances under our DRP. The DRP allows us, at our option, to use treasury shares or newly issued shares to raise capital. NJR raised approximately $14.7M and $15.0M of equity through the DRP during fiscal 2024 and 2023, respectively. We also raised approximately $59.7M and $42.8M of equity by issuing approximately 1,380,000 and 948,000 shares through the waiver discount feature of the DRP during fiscal 2024 and 2023, respectively. In 1996, the Board of Directors authorized us to implement a share repurchase program, which was expanded seven times since the inception of the program, authorizing a total of 19.5M shares of common stock for repurchase. Since inception, we repurchased a total of approximately 17.8M of those shares and may repurchase an additional 1.7M shares under the approved program. There were no shares repurchased during fiscal 2024 and 2023. Debt NJR and its unregulated subsidiaries generally rely on cash flows generated from operating activities and the utilization of committed credit facilities to provide liquidity to meet working capital and short-term debt financing requirements. NJNG also relies on the issuance of commercial paper for short-term funding. NJR and NJNG, as borrowers, periodically access the capital markets to fund long-life assets through the issuance of long-term debt securities. We believe that our existing borrowing availability, equity proceeds and cash flows from operations will be sufficient to satisfy our working capital, capital expenditures and dividend requirements for at least the next 12 months. NJR, NJNG, CEV, S&T and ES currently anticipate that each of their financing requirements for the next 12 months will be met primarily through the issuance of short- and long-term debt, and meter or solar asset sale leasebacks. We believe that as of September 30, 2024, NJR and NJNG were, and currently are, in compliance with all existing debt covenants, both financial and non-financial. Short-Term Debt We use our short-term borrowings primarily to finance ES’s short-term liquidity needs, share repurchases and, on an initial basis, CEV’s investments. ES’s use of high-volume storage facilities and anticipated pipeline park and loan arrangements, combined with related economic hedging activities in the volatile wholesale natural gas market, create significant short-term cash requirements. As of September 30, 2024, NJR had a revolving credit facility totaling $575M, with $326.0M available under the facility. NJNG satisfies its debt needs by issuing short-term and long-term debt based on its financial profile. The seasonal nature of NJNG’s operations creates large short-term cash requirements, primarily to finance natural gas purchases and customer accounts receivable. NJNG obtains working capital for these requirements and for the temporary financing of construction and MGP remediation expenditures and energy tax payments, based on its financial profile, through the issuance of commercial paper supported by the NJNG Credit Facility or through short-term bank loans under the NJNG Credit Facility. Page 52 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) NJNG’s commercial paper is sold through several commercial banks under an issuing and paying agency agreement and is supported by the $250M NJNG Credit Facility. As of September 30, 2024, there was $194.2M available under the NJNG Credit Facility, including amounts allocated to the backstop under the commercial paper program and the issuance of letters of credit. Short-term borrowings for the twelve months ended September 30, 2024, were as follows: (Thousands) NJR Notes Payable to banks: Balance at end of period $ 236,700 Weighted average interest rate at end of period 6.23 % Average balance for the period $ 216,996 Weighted average interest rate for average balance 6.53 % Month end maximum for the period $ 301,550 NJNG Commercial Paper and Notes Payable to banks: Balance at end of period $ 55,100 Weighted average interest rate at end of period 4.98 % Average balance for the period $ 52,868 Weighted average interest rate for average balance 5.46 % Month end maximum for the period $ 106,700 Due to the seasonal nature of natural gas prices and demand, and because inventory levels are built up during its natural gas injection season (April through October), NJR and NJNG’s short-term borrowings tend to peak in the November through January time frame. NJR On August 7, 2024, NJR entered into a second amendment to NJR’s Second Amended and Restated Credit Agreement, which reduced the NJR Credit Facility from $650M to $575M and extended the maturity date of the facility to August 7, 2029, pursuant to NJR’s option to extend the maturity date under the NJR Second Amended and Restated Credit Agreement, and permits NJR to request that the maturity date be extended up to two times for an additional period of one year each. The NJR Credit Facility includes an accordion feature, which allows NJR, in the absence of a default or event of default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJR Credit Facility in increments of at least $50M with the total revolving credit commitments not exceeding $750M. The NJR Credit Facility also permits the borrowing of revolving loans and swingline loans, as well as a $75M sublimit for the issuance of letters of credit. Certain of NJR’s unregulated subsidiaries have guaranteed all of NJR’s obligations under the NJR Credit Facility. The credit facility is used primarily to finance its share repurchases, to satisfy ES’s short-term liquidity needs and to finance, on an initial basis, unregulated investments. As of September 30, 2024, NJR had eleven letters of credit outstanding totaling $12.3M, which reduced the amount available under the NJR Credit Facility by the same amount. NJR does not anticipate that these letters of credit will be drawn upon by the counterparties. Based on its average borrowings during fiscal 2024, NJR’s average interest rate was 6.53%, resulting in interest expense of approximately $14.4M. Based on average borrowings of $217.0M during the period, a 100 basis point change in the underlying average interest rate would have caused a change in interest expense of approximately $2.2M during fiscal 2024. Neither NJNG nor its assets are obligated or pledged to support the NJR Credit Facility. Page 53 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) NJNG On August 7, 2024, NJNG entered into a second amendment to NJNG’s Second Amended and Restated Credit Agreement governing a $250M NJNG Credit Facility, which extended the maturity date of the facility to August 7, 2029, pursuant to NJNG’s option to extend the maturity date under the NJNG Second Amended and Restated Credit Agreement, and permits NJNG to request that the maturity date be extended up to two times for an additional period of one year each. The NJNG Credit Facility includes an accordion feature, which would allow NJNG, in the absence of a default or event of default, to increase from time to time, with the existing or new lenders, the revolving credit commitments under the NJNG Credit Facility in increments of at least $50M with total revolving credit commitments not exceeding $350M. The NJNG Credit Facility also permits the borrowing of revolving loans and swingline loans, as well as a $30M sublimit for the issuance of letters of credit. As of September 30, 2024, NJNG had two letters of credit outstanding for $0.7M, which reduced the amount available under the NJNG Credit Facility by the same amount. NJNG does not anticipate that these letters of credit will be drawn upon by the counterparties. Based on its average borrowings during fiscal 2024, NJNG’s average interest rate was 5.46%, resulting in interest expense of $2.9M. Based on average borrowings of $52.9M during the period, a 100 basis point change in the underlying average interest rate would have caused a change in interest expense of approximately $0.6M during fiscal 2024. Short-Term Debt Covenants Borrowings under the NJR Credit Facility, term loan credit agreement and NJNG Credit Facility are conditioned upon compliance with a maximum leverage ratio (consolidated total indebtedness to consolidated total capitalization as defined in the applicable agreements) of not more than .70 to 1.00 for NJR and .65 to 1.00 for NJNG. These revolving credit facilities and term loan credit agreement contain customary representations and warranties for transactions of this type. They also contain customary events of default and certain covenants that will limit NJR’s or NJNG’s ability, beyond agreed upon thresholds, to, among other things: • incur additional debt; • incur liens and encumbrances; • make dispositions of assets; • enter into transactions with affiliates; and • merge, consolidate, transfer, sell or lease all or substantially all of the borrowers’ or guarantors’ assets. These covenants are subject to a number of exceptions and qualifications set forth in the applicable agreements. Default Provisions The agreements governing our long-term and short-term debt obligations include provisions that, if not complied with, could require early payment or similar actions. Default events include, but are not limited to, the following: • defaults for non-payment; • defaults for breach of representations and warranties; • defaults for insolvency; • defaults for non-performance of covenants; • cross-defaults to other debt obligations of the borrower; and • guarantor defaults. The occurrence of an event of default under these agreements could result in all loans and other obligations of the borrower becoming immediately due and payable and the termination of the credit facilities or term loan. Page 54 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Long-Term Debt NJR As of September 30, 2024, NJR had the following outstanding: • $100M of 3.48% senior notes due November 7, 2024; • $100M of 3.54% senior notes due August 18, 2026; • $110M of 4.38% senior notes due June 23, 2027; • $100M of 3.96% senior notes due June 8, 2028; • $150M of 3.29% senior notes due July 17, 2029; • $130M of 3.60% senior notes due July 23, 2032; • $130M of 3.50% senior notes due July 23, 2030; • $120M of 3.13% senior notes due September 1, 2031; • $80M of 3.25% senior notes due September 1, 2033; • $50M of 3.64% senior notes due September 19, 2034; and • $50M of 6.14% senior notes due December 15, 2032. On November 7, 2024, NJR entered into a Note Purchase Agreement under which NJR issued $100M senior notes at a fixed interest rate of 5.55%, maturing in 2034. Neither NJNG nor its assets are obligated or pledged to support NJR’s long-term debt. NJNG As of September 30, 2024, NJNG’s long-term debt consisted of approximately $1.6B in fixed-rate debt issuances secured by the Mortgage Indenture, with maturities ranging from 2025 to 2061, and approximately $31.6M in sale leasebacks of natural gas meters with various maturities ranging from 2025 to 2030. In September 2023, NJNG entered into a Note Purchase Agreement for $100M aggregate principal amount of its senior notes consisting of $50M of 5.56% senior notes due September 28, 2033, which closed on September 28, 2023, and $50M of 5.85% senior notes due October 30, 2053, which closed on October 30, 2023. On June 26, 2024, NJNG entered into a Note Purchase Agreement for $200M aggregate principal amount of its senior notes consisting of $125M of 5.82% senior notes due June 26, 2054, which closed on June 26, 2024, and $75M of 5.49% senior notes due September 30, 2034, which closed on September 30, 2024. Senior notes are secured by an equal principal amount of NJNG’s FMBs issued under NJNG’s Mortgage Indenture. NJR is not obligated directly nor contingently with respect to NJNG’s fixed-rate debt issuances. Long-Term Debt Covenants and Default Provisions The NJR and NJNG long-term debt instruments contain customary representations and warranties for transactions of their type. They also contain customary events of default and certain covenants that will limit NJR or NJNG’s ability beyond agreed upon thresholds to, among other things: • incur additional debt (including a covenant that limits the amount of consolidated total debt of the borrower at the end of a fiscal quarter to 70% for NJR and 65% for NJNG of the consolidated total capitalization of the borrower, as those terms are defined in the applicable agreements, and a covenant limiting priority debt to 20% of the borrower’s consolidated total capitalization, as those terms are defined in the applicable agreements); • incur liens and encumbrances; • make loans and investments; • make dispositions of assets; • make dividends or restricted payments; • enter into transactions with affiliates; and • merge, consolidate, transfer, sell or lease substantially all of the borrower’s assets. The aforementioned covenants are subject to a number of exceptions and qualifications set forth in the applicable note purchase agreements. Page 55 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) In addition, the FMBs issued by NJNG under the Mortgage Indenture are subject to certain default provisions. Events of Default, as defined in the Mortgage Indenture, consist mainly of: • failure for 30 days to pay interest when due; • failure to pay principal or premium when due and payable; • failure to make sinking fund payments when due; • failure to comply with any other covenants of the Mortgage Indenture after 30 days’ written notice from the Trustee; • failure to pay or provide for judgments in excess of $30M in aggregate amount within 60 days of the entry thereof; or • certain events that are or could be the basis of a bankruptcy, reorganization, insolvency or receivership proceeding. Upon the occurrence and continuance of such an Event of Default, the Mortgage Indenture, subject to any provisions of law applicable thereto, provides that the Trustee may take possession and conduct the business of NJNG, may sell the trust estate or proceed to foreclose the lien of the Mortgage Indenture. The interest rate on defaulted principal and interest, to the extent permitted by law, on the FMBs issued under the Mortgage Indenture is the rate stated in the applicable supplement or, if no such rate is stated, 6% per annum. Sale Leaseback NJNG NJNG received approximately $8.8M, $8.4M and $17.3M in fiscal 2024, 2023 and 2022, respectively, in connection with the sale leaseback of its natural gas meters. 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 repurchase the assets sold or renew the lease at the end of the term. As NJNG retains control of the natural gas meters, these arrangements do not qualify as a sale. NJNG uses the financing method to account for the transactions. NJNG continues to evaluate this sale leaseback program based on current market conditions. Natural gas meters are excluded from the lien on NJNG property under the Mortgage Indenture. CEV CEV enters into transactions to sell the commercial solar assets concurrent with agreements to lease the assets back over a period of five to seven years. The Company has concluded that these arrangements do not qualify as a sale for accounting purposes, as the Company retains control of the underlying assets, and are therefore treated as financing obligations, which are typically secured by the renewable energy facility asset and its future cash flows from RECs and energy sales. ITCs and other tax benefits associated with these solar projects are transferred to the buyer, if applicable; however, the lease payments are structured so that CEV is compensated for the transfer of the related tax incentives. CEV continues to operate the solar assets, including related expenses, and retain the revenue generated from RECs and energy sales, and has the option to renew the lease or repurchase the assets sold at the end of the lease term. During fiscal 2024, 2023 and 2022, CEV received proceeds of approximately $64.7M, $167.8M and $24.1M, respectively, in connection with the sale leaseback of commercial solar projects. The proceeds received were recognized as a financing obligation on the Consolidated Balance Sheets. Contractual Obligations and Capital Expenditures As of September 30, 2024, there were NJR guarantees covering approximately $174.3M of natural gas purchases and ES demand fee commitments and thirteen outstanding letters of credit totaling approximately $13.0M, as previously mentioned, not yet reflected in accounts payable on the Consolidated Balance Sheets. Estimated capital expenditures are reviewed on a regular basis and may vary based on the ongoing effects of regulatory constraints, environmental regulations, unforeseen events and the ability to access capital. NJNG’s total capital expenditures spent or accrued during fiscal 2024 were approximately $431.8M. During fiscal 2025 capital expenditures are projected to be between $365M and $415M. NJNG expects to fund its obligations with a combination of cash flows from operations, cash on hand, issuance of commercial paper, available capacity under its revolving credit facility and the issuance of long-term debt. As of September 30, 2024, NJNG’s future MGP expenditures are estimated to be approximately $161.7M. For a more detailed description of MGP expenditures, see Note 14. Commitments and Contingent Liabilities in the accompanying Consolidated Financial Statements. Page 56 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) During fiscal 2024, S&T had capital expenditures spent or accrued for the Adelphia project totaling approximately $6.6M, and capital expenditures spent or accrued for Leaf River totaling approximately $39.0M. During fiscal 2025, we expect expenditures related to the Adelphia project to be between $5M and $15M and expenditures related to Leaf River to be between $15M and $20M. During fiscal 2024, total capital expenditures spent or accrued related to the purchase and installation of solar equipment were approximately $95.8M. CEV’s expenditures include clean energy projects that support our goal to promote renewable energy. Accordingly, CEV enters into agreements to install solar equipment for commercial projects. We estimate solar-related capital expenditures during fiscal 2025 to be between $160M and $265M. Capital expenditures related to clean energy projects are subject to change due to a variety of factors that may affect our ability to commence operations at these projects on a timely basis or at all, including sourcing projects that meet our investment criteria, logistics associated with the start-up of commercial solar projects, such as timing of construction schedules, the permitting and regulatory process, any delays related to electric grid interconnection, economic trends or unforeseen events and the ability to access capital or allocation of capital to other investments or business opportunities. ES does not currently anticipate any significant capital expenditures during fiscal 2025 and 2026. During December 2020, ES entered into a series of AMAs with an investment grade public utility to release pipeline capacity associated with certain natural gas transportation contracts. The utility provides certain asset management services, and ES may deliver natural gas to the utility in exchange for aggregate net proceeds of approximately $500M, payable through November 1, 2030. The AMAs include a series of initial and permanent releases which commenced in November 2021. NJR received a total of approximately $260M in cash from fiscal 2022 through fiscal 2024 and will receive $34M per year from fiscal 2025 through fiscal 2031 under the agreements. During fiscal 2024 and 2023, ES recognized approximately $137.2M and $48.5M, respectively, of operating revenue related to the AMAs on the Consolidated Statements of Operations. Amounts received in excess of revenue, totaling approximately $22.3M and $58.7M as of September 30, 2024 and 2023, respectively, are included in deferred revenue on the Consolidated Balance Sheets. Cash Flows Operating Activities Cash flows from operating activities during fiscal 2024 totaled approximately $427.4M compared with approximately $479.0M during fiscal 2023. Operating cash flows are primarily affected by variations in working capital, which can be impacted by several factors, including: • seasonality of our business; • fluctuations in wholesale natural gas prices and other energy prices, including changes in derivative asset and liability values; • timing of storage injections and withdrawals; • deferral and recovery of natural gas costs; • changes in contractual assets utilized to optimize margins related to natural gas transactions; • broker margin requirements; • impact of unusual weather patterns on our wholesale business; • timing of the collections of receivables and payments of current liabilities; • volumes of natural gas purchased and sold; and • timing of SREC deliveries. The decrease of approximately $51.6M in cash flows from operating activities during fiscal 2024, compared with fiscal 2023, was due primarily to the changes in the mix of working capital components, partially offset by timing of cash received from certain ES AMAs. Investing Activities Cash flows used in investing activities totaled approximately $569.1M during fiscal 2024, compared with approximately $538.6M during fiscal 2023. The increase of approximately $30.5M was due primarily to increased utility plant expenditures. Page 57 New Jersey Resources Corporation Part II ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Financing Activities Financing cash flows generally are seasonal in nature and are impacted by the volatility in pricing in the natural gas and other energy markets. NJNG’s inventory levels are built up during its natural gas injection season (April through October) and reduced during withdrawal season (November through March) in response to the supply requirements of its customers. Changes in financing cash flows can also be impacted by natural gas management and marketing activities at ES and clean energy investments at CEV. Cash flows from financing activities totaled approximately $141.8M during fiscal 2024, compared with approximately $59.7M during fiscal 2023. The increase of approximately $82.1M is due primarily to reduced net short-term debt payments of approximately $61.6M, along with a payment of a $150M term loan in the prior year that did not occur in the current year, and an increase of approximately $16.9M from the waiver discount issuance of common stock, partially offset by a decrease in solar sale leaseback proceeds of approximately $103.1M and a $70.0M payment of long-term debt. Credit Ratings The table below summarizes NJNG’s credit ratings as of September 30, 2024, issued by two rating entities, Moody’s and Fitch: Moody’s Fitch Corporate Rating N/A A- Commercial Paper P-2 F-2 Senior Secured A1 A+ Ratings Outlook Stable Stable The Moody’s ratings and outlook were reaffirmed on July 3, 2024. The Fitch ratings and outlook were reaffirmed on April 15, 2024. NJNG’s Moody’s and Fitch ratings are investment-grade ratings. NJR is not rated by Moody’s or Fitch. Although NJNG is not party to any lending agreements that would accelerate the maturity date of any obligation caused by a failure to maintain any specific credit rating, if such ratings are downgraded below investment grade, borrowing costs could increase, as would the costs of maintaining certain contractual relationships, and future financing and our access to capital markets would be reduced. Even if ratings are downgraded without falling below investment grade, NJR and NJNG could face increased borrowing costs under their credit facilities. A rating set forth above is not a recommendation to buy, sell or hold NJR’s or NJNG’s securities and may be subject to revision or withdrawal at any time. Each rating set forth above should be evaluated independently of any other rating. The timing and mix of any external financings will target a common equity ratio that is consistent with maintaining NJNG’s current short-term and long-term credit ratings. ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK Financial Risk Management Commodity Market Risks Natural gas is a nationally traded commodity. Its prices are determined effectively by the NYMEX, ICE and over-the-counter markets. The prices on the NYMEX, CME, ICE and over-the-counter markets generally reflect the national balance of natural gas supply and demand, but are also significantly influenced from time to time by other events. Our regulated and unregulated businesses are subject to market risk due to fluctuations in the price of natural gas. To economically hedge against such fluctuations, we have entered into forwards, futures, options and swap agreements. To manage these derivative instruments, we have well-defined risk management policies and procedures that include daily monitoring of volumetric limits and monetary guidelines. Our natural gas businesses are conducted through two of our operating subsidiaries. NJNG is a regulated utility that uses futures, options and swaps to provide relative price stability, and its recovery of natural gas costs is governed by the BPU. ES uses futures, options, swaps and physical contracts to economically hedge purchases and sales of natural gas. Page 58 New Jersey Resources Corporation Part II ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued) The following table reflects the changes in the fair market value of financial derivatives related to natural gas purchases and sales: Balance Increase Less Balance (Thousands) September 30, 2023 (Decrease) in Fair Market Value Amounts Settled September 30, 2024 NJNG $ 6,090 $ (13,199) $ (7,107) $ (2) ES 16,178 26,911 39,954 3,135 Total $ 22,268 $ 13,712 $ 32,847 $ 3,133 There were no changes in methods of valuations during the fiscal year ended September 30, 2024. The following is a summary of fair market value of financial derivatives as of September 30, 2024, by method of valuation and by maturity for each fiscal year period: (Thousands) 2025 2026 2027 - 2029 After 2029 Total Fair Value Price based on ICE $ 3,786 $ (325) $ (328) $ — $ 3,133 The following is a summary of financial derivatives by type as of September 30, 2024: Volume Bcf Price per MMBtu Amounts included in Derivatives (Thousands) NJNG Futures 31.9 $2.57 - $3.58 $ (2) ES Futures (7.7) $1.69 - $4.22 3,135 Total $ 3,133 The following table reflects the changes in the fair market value of physical commodity contracts: Balance Increase Less Balance (Thousands) September 30, 2023 (Decrease) in Fair Market Value Amounts Settled September 30, 2024 NJNG - Prices based on other external data $ (445) (2,201) (2,088) $ (558) ES - Prices based on other external data (13,616) 5,666 4,767 (12,717) Total $ (14,061) 3,465 2,679 $ (13,275) Our market price risk is predominately linked with changes in the price of natural gas at the Henry Hub, the delivery point for the NYMEX natural gas futures contracts. Based on price sensitivity analysis, an illustrative 10% movement in the natural gas futures contract price, for example, increases (decreases) the reported derivative fair value of all open, unadjusted Henry Hub natural gas futures and fixed price swap positions by approximately $3.1M. This analysis does not include potential changes to reported credit adjustments embedded in the $3.0M reported fair value. Derivative Fair Value Sensitivity Analysis (Thousands) Henry Hub Futures and Fixed Price Swaps Percent increase in NYMEX natural gas futures prices 0% 5% 10% 15% 20% Estimated change in derivative fair value $ — $ (1,562) $ (3,124) $ (4,686) $ (6,248) Ending derivative fair value $ 2,993 $ 1,431 $ (131) $ (1,693) $ (3,255) Percent decrease in NYMEX natural gas futures prices 0% (5)% (10)% (15)% (20)% Estimated change in derivative fair value $ — $ 1,562 $ 3,124 $ 4,686 $ 6,248 Ending derivative fair value $ 2,993 $ 4,555 $ 6,117 $ 7,679 $ 9,241 Page 59 New Jersey Resources Corporation Part II