UGI CORP /PA/

Note 1 — Nature of Operations

UGI is a holding company that, through subsidiaries and affiliates, distributes, stores, transports and markets energy products and related services in the U.S. and Europe. We own and operate (1) natural gas and electric distribution utilities; (2) energy marketing, midstream infrastructure, storage, natural gas gathering and processing, natural gas production, and energy services businesses; and (3) retail propane and other LPG marketing and distribution businesses.

Our Utilities segment includes UGI Utilities and Mountaineer. PA Gas Utility serves customers in eastern and central Pennsylvania and in portions of one Maryland county, and WV Gas Utility serves customers in West Virginia. Electric Utility serves customers in portions of Luzerne and Wyoming counties in northeastern Pennsylvania. PA Gas Utility is subject to regulation by the PAPUC and FERC and, with respect to its customers in Maryland, the MDPSC. WV Gas Utility is subject to regulation by the WVPSC and FERC. Electric Utility is subject to regulation by the PAPUC and FERC (see Note 5 for pending disposition of Electric Utility).

Energy Services conducts, directly and through subsidiaries and affiliates, energy marketing, including RNG, midstream transmission, LNG storage, natural gas gathering and processing, natural gas and RNG production, and energy services businesses primarily in the eastern region of the U.S., eastern Ohio, the panhandle of West Virginia and California. Energy Services and its subsidiaries’ storage, LNG and portions of its midstream transmission operations are subject to regulation by the FERC.

UGI International, LLC, through its subsidiaries and affiliates, primarily conducts an LPG distribution business throughout much of Europe. The LPG business is conducted principally through our subsidiaries, UGI France, AvantiGas and, prior to the sales in June and November 2025, UniverGas and Flaga.

We conduct a domestic propane marketing and distribution business through AmeriGas Partners. AmeriGas Partners conducts its propane marketing and distribution business through its principal operating subsidiary AmeriGas OLP.

Note 2 — Summary of Significant Accounting Policies

The accompanying condensed consolidated financial statements and footnotes are unaudited and have been prepared in accordance with GAAP and the rules and regulations of the SEC. They include all adjustments that we consider necessary for a fair statement of the results for the interim periods presented. Such adjustments consisted only of normal recurring items unless otherwise disclosed. The September 30, 2025, Condensed Consolidated Balance Sheet was derived from audited financial statements but does not include all footnote disclosures from the annual financial statements.

These financial statements should be read in conjunction with the financial statements and related notes included in the Company’s 2025 Annual Report. Due to the seasonal nature of our businesses, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.

Restricted Cash. Restricted cash principally represents those cash balances in our commodity futures brokerage accounts that are restricted from withdrawal. The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Condensed Consolidated Balance Sheets to the corresponding amounts reported on the Condensed Consolidated Statements of Cash Flows.

Earnings Per Common Share. Basic earnings per share attributable to UGI Corporation stockholders reflect the weighted-average number of common shares outstanding. Diluted earnings per share attributable to UGI Corporation stockholders include the effects of dilutive stock options, common stock awards, and UGI Corporation Senior Notes. Shares used in computing basic and diluted earnings per share are as follows:

(a)For the three months ended June 30, 2026 and 2025,6,546 and 5,853 shares, respectively, have been excluded from the computation of diluted earnings per share as such incremental shares would be antidilutive due to the net losses for the periods. For the nine months ended June 30, 2026 and 2025, there were 5,555 and 5,212 shares, respectively, associated with outstanding stock option awards that were not included in the computation of diluted earnings per share above because their effect was antidilutive.

(b)See Note 8 for additional information on the UGI Corporation Senior Notes.

Derivative Instruments. Derivative instruments are reported on the Condensed Consolidated Balance Sheets at their fair values, unless the NPNS exception is elected. The accounting for changes in fair value depends upon the purpose of the derivative instrument, whether it is subject to regulatory ratemaking mechanisms or if it qualifies and is designated as a hedge for accounting purposes.

Certain of our derivative instruments qualify and are designated as cash flow hedges. For cash flow hedges, changes in the fair values of the derivative instruments are recorded in AOCI, to the extent effective at offsetting changes in the hedged item, until earnings are affected by the hedged item. We discontinue cash flow hedge accounting if occurrence of the forecasted transaction is determined to be no longer probable. Hedge accounting is also discontinued for derivatives that cease to be highly effective. We do not designate our commodity and certain foreign currency derivative instruments as hedges under GAAP. Changes in the fair values of these derivative instruments are reflected in net income. Gains and losses on substantially all of the commodity derivative instruments used by Utilities are included in regulatory assets or liabilities because it is probable such gains or losses will be recoverable from, or refundable to, customers. From time to time, we also enter into net investment hedges. Gains and losses on net investment hedges that relate to our foreign operations are included in the cumulative translation adjustment component in AOCI until such foreign net investment is substantially sold or liquidated.

Cash flows from derivative instruments, other than certain net investment hedges, are included in cash flows from operating activities on the Condensed Consolidated Statements of Cash Flows. Cash flows from net investment hedges are included in cash flows from investing activities on the Condensed Consolidated Statements of Cash Flows.

See Note 11 for a more detailed description of the derivative instruments we use, our accounting for derivatives, our objectives for using them and other information.

Use of Estimates. The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based on management’s knowledge of current events, historical experience and various other assumptions that are believed to be reasonable under the circumstances. Accordingly, actual results may be different from these estimates and assumptions.

Goodwill. We do not amortize goodwill, but test it at least annually for impairment at the reporting unit level. A reporting unit is an operating segment, or one level below an operating segment (a component) if it constitutes a business for which discrete financial information is available and regularly reviewed by segment management. Components are aggregated into a single reporting unit if they have similar economic characteristics. Each of our reporting units with goodwill is required to perform impairment tests annually or whenever events or circumstances indicate that the value of goodwill may be impaired.

With respect to AmeriGas Propane's Fiscal 2025 goodwill impairment test, the Company performed a quantitative assessment. Based on our evaluation, we determined that AmeriGas Propane’s fair value exceeded its carrying value by more than 25%. While the Company believes that its judgments used in the quantitative assessment of AmeriGas Propane’s fair value are reasonable based upon currently available facts and circumstances, if AmeriGas Propane were not able to achieve its anticipated results and/or if its discount rate were to increase, its fair value would be adversely affected, which may result in an impairment. There was $1.1 billion of goodwill in the AmeriGas Propane reporting unit as of June 30, 2026.

The Company will continue to monitor its reporting units and related goodwill for any possible future non-cash impairment charges.

Note 3 — Accounting Changes

Accounting Standards Not Yet Adopted

Environmental Credits and Environmental Credit Obligations. In May 2026, the FASB issued ASU 2026-02, "Environmental Credits and Environmental Credit Obligations (Topic 818)" which provides authoritative guidance for the recognition, measurement, presentation, and disclosure of environmental credits and environmental credit obligations. This new guidance is effective for the Company for annual and interim periods beginning October 1, 2028 (Fiscal 2029). Early adoption is permitted. The amendments in this ASU should be applied using the modified retrospective method. The Company is in the process of assessing the impact on its financial statements and the period in which the new guidance will be adopted.

Interim Reporting: Narrow-Scope Improvements. In December 2025, the FASB issued ASU 2025-11, “Narrow-Scope Improvements (Topic 270)” which clarifies disclosure requirements and applicability for interim financial statements. This new guidance is effective for the Company for interim periods beginning October 1, 2028 (Fiscal 2029). Early adoption is permitted. The amendments in this ASU may be adopted using the prospective or retrospective methods. The Company is in the process of assessing the impact on its financial statements and determining the transition method and the period in which the new guidance will be adopted.

Targeted Improvements to the Accounting for Internal-Use Software. In September 2025, the FASB issued ASU 2025-06, “Targeted Improvements to the Accounting for Internal-Use Software (Subtopic 350-40)” which, among other things, removes the prescriptive project stage requirements and allows entities to capitalize internal-use software costs when management authorizes and commits funding to the project and it is probable the software will be completed and used as intended. This new guidance is effective for the Company for annual and interim periods beginning October 1, 2028 (Fiscal 2029). Early adoption is permitted. The amendments in this ASU may be adopted using the prospective, modified, or retrospective methods. The Company is in the process of assessing the impact on its financial statements and determining the transition method and the period in which the new guidance will be adopted.

Measurement of Credit Losses for Accounts Receivable and Contract Assets. In July 2025, the FASB issued ASU 2025-05, “Measurement of Credit Losses for Accounts Receivable and Contract Assets (Topic 326)” which provides a practical expedient that allows entities to assume that current conditions as of the balance sheet date do not change for the remaining life of the asset when estimating expected credit losses for current accounts receivable and current contract assets. This new guidance is effective for the Company for annual and interim periods beginning October 1, 2026 (Fiscal 2027). Early adoption is permitted. The amendments in this ASU should be adopted using the prospective method. The Company is in the process of assessing the impact on its financial statements and the period in which the new guidance will be adopted.

Disaggregation of Income Statement Expenses. In November 2024, the FASB issued ASU 2024-03, “Disaggregation of Income Statement Expenses (Subtopic 220-40)” which requires enhanced disclosure of income statement expense categories to improve transparency and provide financial statement users with more detailed information about the nature, amount and timing of expenses impacting financial performance. This new guidance is effective for the Company for annual periods beginning October 1, 2027 (Fiscal 2028) and interim periods beginning October 1, 2028 (Fiscal 2029). Early adoption is permitted. The amendments in this ASU may be adopted using the prospective or retrospective methods. The Company is in the process of assessing the impact on its financial statements and determining the transition method and the period in which the new guidance will be adopted.

Improvements to Income Tax Disclosures. In December 2023, the FASB issued ASU 2023-09, “Improvements to Income Tax Disclosures (Topic 740)” which requires entities to disclose, among other items, disaggregated information about a reporting entity’s effective tax rate reconciliation and income taxes paid. This new guidance is effective for the Company for annual periods beginning October 1, 2025 (Fiscal 2026). Early adoption is permitted. The amendments in this ASU may be adopted using the prospective or retrospective methods. The Company will adopt the new guidance effective for the year ending September 30, 2026 and provide the additional disclosures as required by the new guidance.

Note 4 — Revenue from Contracts with Customers

The Company recognizes revenue when control of promised goods or services is transferred to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. See Note 4 in the Company’s 2025 Annual Report for additional information on our revenues from contracts with customers.

Revenue Disaggregation

The following tables present our disaggregated revenues by reportable segment:

(a)Includes intersegment revenues principally among Midstream & Marketing and Utilities.

(b)Primarily represents (1) revenues from tank rentals at UGI International and AmeriGas Propane; (2) revenues from alternative revenue programs at Utilities, including the weather normalization adjustment rider for Gas Utility; and (3) gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP.

Contract Balances

The timing of revenue recognition may differ from the timing of invoicing to customers or cash receipts. Contract assets represent our right to consideration after the performance obligations have been satisfied when such right is conditioned on something other than the passage of time. Contract assets were not material for all periods presented. Substantially all of our receivables are unconditional rights to consideration and are included in “Accounts receivable” and, in the case of Utilities, “Accrued utility revenues” on the Condensed Consolidated Balance Sheets. Amounts billed are generally due within the following month.

Contract liabilities arise when payment from a customer is received before the performance obligations have been satisfied and represent the Company’s obligations to transfer goods or services to a customer for which we have received consideration. The balances of contract liabilities were $100, $132 and $110 at June 30, 2026, September 30, 2025 and June 30, 2025, respectively, and are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets. Revenues recognized for the nine months ended June 30, 2026 and 2025, from the amounts included in contract liabilities at September 30, 2025 and 2024, were $92 and $99, respectively.

Remaining Performance Obligations

The Company excludes disclosures related to the aggregate amount of the transaction price allocated to certain performance obligations that are unsatisfied as of the end of the reporting period because these contracts have an initial expected term of one year or less, or we have a right to bill the customer in an amount that corresponds directly with the value of services provided to the customer to date. Certain contracts with customers at Midstream & Marketing and Utilities contain minimum future performance obligations through 2047 and 2053, respectively. At June 30, 2026, the Company expects to record approximately $1.2 billion of revenues related to the minimum future performance obligations over the remaining terms of the related contracts.

Note 5 — Dispositions

Electric Utility

In April 2026, UGI Utilities entered into a definitive agreement to divest its Electric Utility for a sale price of $470, subject to changes in working capital and other adjustments. The transaction includes the sale of approximately 2,700 miles of transmission and distribution lines and 14 substations in Pennsylvania’s Luzerne and Wyoming counties. At June 30, 2026, the Electric Utility’s assets and liabilities were classified as held for sale and included in “Held for sale assets” and “Held for sale liabilities”, respectively, on the Condensed Consolidated Balance Sheet. The Company expects to recognize a gain upon closing, which is expected in the second quarter of Fiscal 2027, subject to customary closing conditions and applicable regulatory approvals.

The major classes of assets and liabilities of the Electric Utility business which are held for sale at June 30, 2026 are as follows:

Global LPG Business Transactions

As part of the Company’s global LPG business portfolio optimization efforts, the Company has strategically divested operations in non-core markets to focus resources where it can achieve superior operational results and deliver enhanced customer value.

UGI International. In January 2026, UGI International, through a wholly-owned subsidiary, entered into a definitive agreement to divest its LPG distribution businesses in Czech Republic, Hungary, Poland, and Slovakia. The sale was completed in May 2026, subject to customary post-closing working capital adjustments. During the second quarter of Fiscal 2026, the Company classified the assets and liabilities associated with these businesses, primarily comprised of long-lived assets and goodwill allocated to the disposal group, as held for sale and recognized a non-cash, pre-tax impairment charge of $64 to record such assets at estimated fair value less costs to sell. During the third quarter of Fiscal 2026, in conjunction with the completion of the sale, the Company recognized an incremental loss on disposal of $7, resulting in a total loss of $71 for the nine months ended June 30, 2026.

In February 2026, UGI International, through a wholly-owned subsidiary, completed the sale of its LPG business in Romania. For the nine months ended June 30, 2026, the Company recognized a pre-tax loss on sale of $2.

In November 2025, UGI International, through a wholly-owned subsidiary, completed the sale of Flaga, its LPG distribution business in Austria. For the nine months ended June 30, 2026, the Company recognized a pre-tax gain on the sale of $29.

In October 2025, UGI International, through a wholly-owned subsidiary, completed the sale of its cylinder business in the United Kingdom. For the nine months ended June 30, 2026, the Company recognized a pre-tax gain on the sale of $2.

In aggregate, the aforementioned divestitures resulted in pre-tax net losses of $7 and $42 for the three and nine months ended June 30, 2026, respectively, which were reflected in “Net loss (gain) on disposals of businesses” on the Condensed Consolidated Statements of Income and included in the UGI International reportable segment. The Company has received or expects to receive total net cash proceeds of approximately $145 from these divestitures.

See Note 5 in the Company’s 2025 Annual Report for additional information on the Company’s global LPG business transactions.

Note 6 — Inventories

Inventories comprise the following:

Note 7 — Utility Regulatory Assets and Liabilities and Regulatory Matters

For a description of the Company’s regulatory assets and liabilities, other than those described below, see Note 9 in the Company’s 2025 Annual Report. Other than removal costs, Utilities currently does not recover a rate of return on the regulatory assets listed below. The following regulatory assets and liabilities associated with our Utilities reportable segment are included in our Condensed Consolidated Balance Sheets:

(a)Regulatory assets are recorded in “Prepaid expenses and other current assets” and “Other assets” on the Condensed Consolidated Balance Sheets. Regulatory liabilities are recorded in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets.

Deferred fuel and power - costs and refunds. Utilities’ tariffs contain clauses that permit recovery of all prudently incurred purchased gas and power costs through the application of PGC rates, PGA rates and DS tariffs. These clauses provide for periodic adjustments to PGC, PGA and DS rates for differences between the total amount of purchased gas and electric generation supply costs billed to customers and recoverable costs incurred. Net underbilled costs are classified as a regulatory asset and net overbillings are classified as a regulatory liability.

PA Gas Utility uses derivative instruments to reduce volatility in the cost of gas it purchases for retail core-market customers. Realized and unrealized gains or losses on natural gas derivative instruments are included in deferred fuel and power costs or refunds. Net unrealized gains (losses) on such contracts at June 30, 2026, September 30, 2025 and June 30, 2025 were $(5), $(5) and $1, respectively.

Other Regulatory Matters

UGI Utilities. On March 27, 2026, Electric Utility filed a rate request with the PAPUC to increase its annual base distribution revenues by $17. The increased revenues would fund ongoing system improvements and operations necessary to maintain safe and reliable electric service. Electric Utility requested that the new electric rates become effective June 1, 2026. The PAPUC entered an order on April 16, 2026, suspending the effective date for the rate increase to allow for investigation and public hearings. Unless a settlement is reached sooner, the review process is expected to last up to nine months from the date of filing. The Company cannot predict the timing or the ultimate outcome of the rate case review process.

On January 28, 2026, PA Gas Utility filed a request with the PAPUC to increase its base operating revenues for residential, commercial and industrial customers by $99 annually. On July 6, 2026, a joint petition for approval of settlement of all issues was filed with the PAPUC. It provided for a $65 annual base distribution rate increase, through a phased approach, with an increase of $40 effective October 1, 2026 and an additional increase of $25 effective October 1, 2027. It also provided for maintenance of the weather normalization adjustment through the end of the second pilot period with modification. In accordance with the terms of the joint petition, PA Gas Utility will not be permitted to file a general rate increase request prior to January 15, 2029. On July 31, 2026, the presiding PAPUC administrative law judges recommended that the settlement be approved without modification. The joint petition remains subject to receipt of a final order of the PAPUC approving the settlement. The Company cannot predict the timing or the ultimate outcome of the rate case review process.

On January 27, 2025, PA Gas Utility filed a request with the PAPUC to increase its base operating revenues for residential, commercial and industrial customers by $110 annually. On September 11, 2025, the PAPUC issued a final order approving a settlement providing for a $70 annual base distribution rate increase, effective October 28, 2025, and maintenance of the weather normalization adjustment through the end of its pilot period with modification.

Mountaineer. On February 3, 2026, WV Gas Utility submitted a base rate case filing with the WVPSC seeking a net revenue increase of $27, which consisted of an increase in base rates of $44 and a decrease in the IREP rates of $17 annually. The increased revenues would fund ongoing system improvements and operations necessary to maintain safe and reliable natural gas service. WV Gas Utility requested the new gas rates become effective March 5, 2026. The WVPSC entered an order on March 2, 2026, suspending the effective date for the rate increase to allow for a full review of the filing and public hearings. Unless a settlement is reached sooner, the review process is expected to last up to 270 days from the date of filing. The Company cannot predict the timing or the ultimate outcome of the rate case review process.

On July 31, 2026, WV Gas Utility submitted its 2026 IREP filing to the WVPSC requesting recovery of $14, an increase of $9, for costs associated with capital investments after September 30, 2025, that total $180, including $83 in calendar year 2027. The filing included capital investments totaling $475 over the 2027 - 2031 period. An order from the WVPSC is expected in December with new rates effective January 1, 2027.

On July 31, 2025, WV Gas Utility submitted its 2025 IREP filing to the WVPSC requesting recovery of $24, an increase of $5, for costs associated with capital investments after December 31, 2022, that total $274, including $77 in calendar year 2026. The filing included capital investments totaling $445 over the 2026 - 2030 period. On December 17, 2025, the WVPSC issued an order approving WV Gas Utility’s request, with new rates effective January 1, 2026.

On July 31, 2024, WV Gas Utility submitted its 2024 IREP filing to the WVPSC requesting recovery of $19, which includes $3 of prior year under-recovery, for costs associated with capital investments after December 31, 2022, that total $197, including $74 in calendar year 2025. The filing included capital investments totaling $418 over the 2025 - 2029 period. On October 28, 2024, the WVPSC issued an order approving WV Gas Utility’s request, with new rates effective January 1, 2025.

Note 8 — Debt

Significant Financing Activities

The following significant financing activities occurred during Fiscal 2026.

AmeriGas Partners Senior Notes. In May 2026, AmeriGas Partners and AmeriGas Finance Corp. issued $500 aggregate principal amount of 6.875% Senior Notes due June 2031. The net proceeds from the issuance of the 6.875% Senior Notes, together with cash on hand and a $300 equity contribution from UGI, funded through a dividend from UGI International, LLC, were used to (1) repay in full the $512 outstanding principal balance of the 5.750% Senior Notes, due May 2027, pursuant to a tender offer and notice of redemption, plus tender and make-whole premiums and accrued and unpaid interest; (2) repurchase $175 aggregate principal amount of the 9.375% Senior Notes, due June 2028, pursuant to a tender offer, plus tender premiums and accrued and unpaid interest, resulting in $318 aggregate principal amount of 9.375% Senior Notes outstanding as of June 30, 2026; (3) repay in full the $150 outstanding borrowings of the intercompany loan with UGI International, plus accrued and unpaid interest; and (4) pay related fees and expenses. The 6.875% Senior Notes rank equally with AmeriGas Partners’ existing and future senior unsecured indebtedness and contain customary covenants and default provisions.

UGI International Senior Notes. In May 2026, UGI International, LLC issued €300 aggregate principal amount of 5.00% Senior Notes due June 2031. The net proceeds from the issuance of the 5.00% Senior Notes, together with the $150 intercompany loan repayment received from AmeriGas Partners, were used to (1) prepay €70 aggregate principal amount of the Term Loan, due March 2028, plus accrued and unpaid interest, resulting in €230 aggregate principal amount of the Term Loan outstanding as of June 30, 2026; (2) pay related fees and expenses; (3) reduce short-term borrowings; and (4) fund general corporate purposes. The 5.00% Senior Notes rank equally with UGI International's existing and future senior unsecured indebtedness, including borrowings under the Credit Facilities Agreement, and contain customary covenants and default provisions. We have designated the UGI International 5.00% Senior Notes as a net investment hedge.

UGI Utilities Senior Notes. In July 2025, UGI Utilities entered into a note purchase agreement with a consortium of lenders. Pursuant to the note purchase agreement, in November 2025, UGI Utilities issued $150 aggregate principal amount of 5.10% Senior Notes due November 15, 2030, and $125 aggregate principal amount of 5.68% Senior Notes due November 15, 2035. UGI Utilities used the net proceeds from the issuance of these senior notes to (1) repay the $100 outstanding principal balance of the 1.59% Senior Notes, due June 2026 and $75 outstanding principal balance of the 1.64% Senior Notes, due September 2026; (2) reduce short-term borrowings; and (3) for general corporate purposes. These senior notes are unsecured and rank equally with UGI Utilities’ existing outstanding senior debt. The note purchase agreement contains customary covenants and default provisions and requires compliance with certain financial covenants including a leverage ratio and priority debt ratio as defined in the agreement.

In June 2026, UGI Utilities repaid the $100 outstanding principal balance of the 2.95% Senior Notes due June 2026 upon maturity.

Energy Services Term Loan Credit Agreement. In June 2026, Energy Services entered into the fourth amendment to the Energy Services Term Loan Credit Agreement. The Energy Services Term Loan Credit Agreement, as amended, provides, among other items, that the applicable margin shall be 2.00% per annum for Term SOFR loans and 1.00% per annum for base rate loans. All other significant terms of the term loan credit agreement remain unchanged.

Energy Services Receivables Facility. Energy Services has a Receivables Facility with an issuer of receivables-backed commercial paper. In October 2025, the expiration date of the Receivables Facility was extended to October 2026. The Receivables Facility provides Energy Services with the ability to borrow up to $150 of eligible receivables during the period October 17, 2025 to April 30, 2026, and up to $75 of eligible receivables during the period May 1, 2026 to October 16, 2026, with the option to request consent for an increase of $50. Energy Services uses the Receivables Facility to fund working capital, margin calls under commodity futures contracts, capital expenditures, dividends and for general corporate purposes.

UGI Corporation

UGI Corporation Senior Notes. The Company has $700 aggregate principal amount of outstanding 5.00% UGI Corporation Senior Notes due June 2028. The UGI Corporation Senior Notes are convertible subject to the occurrence of certain events and circumstances. As of June 30, 2026, none of the events permitting the noteholders to convert their notes early existed. Accordingly, the UGI Corporation Senior Notes are classified as “Long-term debt” on the Condensed Consolidated Balance Sheet. For the three and nine months ended June 30, 2026 and 2025, the Company recognized $10 and $30, respectively, in both periods, of interest expense, including amortization of debt issuance costs, related to the UGI Corporation Senior Notes at the effective interest rate of 5.68% for all periods.

We estimate the fair value of long-term debt by using current market rates and by discounting future cash flows using rates available for similar type debt (Level 2). The estimated fair values of the UGI Corporation Senior Notes were $944 and $894 at June 30, 2026 and September 30, 2025, respectively.

See the Company’s 2025 Annual Report for additional information on our UGI Corporation Senior Notes.

Loss on Extinguishments of Debt

In conjunction with the amendment to the Energy Services Term Loan Credit Agreement and the early repayments of AmeriGas Partners’ Senior Notes, during the third quarter of Fiscal 2026, the Company recognized a pre-tax loss of $15, primarily comprising tender and make whole premiums and the write-off of unamortized debt issuance costs.

During the third quarter of Fiscal 2025, pursuant to a tender offer and notice of redemption, AmeriGas Partners repaid in full all AmeriGas Partners’5.875% Senior Notes having an aggregate principal balance of $664. During the third quarter of Fiscal 2025, the Company recognized a pre-tax loss of $10, primarily related to AmeriGas Propane, comprising tender and make whole premiums and the write-off of unamortized debt issuance costs.

Losses in connection with early repayment of debt are reflected in “Loss on extinguishments of debt” on the Condensed Consolidated Statements of Income.

Supplemental Cash Flow Information

The Company regularly uses its credit facilities (other than the UGI Corporation 2025 Credit Agreement) and, in the case of Energy Services, the Receivables Facility, to support its working capital needs with borrowings of $1,809 and repayments of $1,958 during the nine months ended June 30, 2026.

Note 9 — Commitments and Contingencies

Environmental Matters

UGI Utilities

From the late 1800s through the mid-1900s, UGI Utilities and its former subsidiaries owned and operated a number of MGPs prior to the general availability of natural gas. Some constituents of coal tars and other residues of the manufactured gas process are today considered hazardous substances under the Superfund Law and may be present on the sites of former MGPs. Between 1882 and 1953, UGI Utilities owned the stock of subsidiary gas companies in Pennsylvania and elsewhere and also operated the businesses of some gas companies under agreement. By the early 1950s, UGI Utilities divested all of its utility operations other than certain gas and electric operations. Beginning in 2006 and 2008, UGI Utilities also owned and operatedtwo acquired subsidiaries, with similar histories of owning, and in some cases operating, MGPs in Pennsylvania.

UGI Utilities is subject to a COA with the PADEP to address the remediation of specified former MGP sites in Pennsylvania, which is scheduled to terminate at the end of 2035. In accordance with the COA, UGI Utilities is required to either obtain a certain number of points per calendar year based on defined eligible environmental investigatory and/or remedial activities at the MGPs, or make expenditures for such activities in an amount equal to an annual environmental minimum expenditure threshold. The annual minimum expenditure threshold of the COA is $5. At June 30, 2026, September 30, 2025 and June 30, 2025, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the COA totaled $66, $63 and $53, respectively.

We do not expect the costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to UGI Utilities’ results of operations because UGI Utilities receives ratemaking recovery of actual environmental investigation and remediation costs associated with the sites covered by the COA. This ratemaking recognition reconciles the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. As such, UGI Utilities has recorded an associated regulatory asset for these costs because recovery of these costs from customers is probable (see Note 7).

From time to time, UGI Utilities is notified of sites outside Pennsylvania on which private parties allege MGPs were formerly owned or operated by UGI Utilities or owned or operated by a former subsidiary. Such parties generally investigate the extent of environmental contamination or perform environmental remediation. Management believes that under applicable law, UGI

Utilities should not be liable in those instances in which a former subsidiary owned or operated an MGP. There could be, however, significant future costs of an uncertain amount associated with environmental damage caused by MGPs outside Pennsylvania that UGI Utilities directly operated, or that were owned or operated by a former subsidiary of UGI Utilities if a court were to conclude that (1) the subsidiary’s separate corporate form should be disregarded, or (2) UGI Utilities should be considered to have been an operator because of its conduct with respect to its subsidiary’s MGP. Neither the undiscounted nor the accrued liability for environmental investigation and cleanup costs for UGI Utilities’ MGP sites outside Pennsylvania were material for all periods presented.

AmeriGas OLP Saranac Lake. In 2008, the NYDEC notified AmeriGas OLP that the NYDEC had placed property purportedly owned by AmeriGas OLP in Saranac Lake, New York on the New York State Registry of Inactive Hazardous Waste Disposal Sites. A site characterization study performed by the NYDEC disclosed contamination related to a former MGP. AmeriGas OLP responded to the NYDEC in 2009 to dispute the contention it was a PRP as it did not operate the MGP and appeared to only own a portion of the site. In 2017, the NYDEC communicated to AmeriGas OLP that the NYDEC had previously issued three RODs related to remediation of the site totaling approximately $28 and requested additional information regarding AmeriGas OLP’s purported ownership. AmeriGas OLP renewed its challenge to designation as a PRP and identified potential defenses. The NYDEC subsequently identified a third party PRP with respect to the site.

The NYDEC commenced implementation of the remediation plan in the spring of 2018. In Fiscal 2024, the NYDEC informed AmeriGas OLP that the remediation plan had been completed at a total cost of approximately $19. The New York Office of the Attorney General, as counsel for the NYDEC, invited AmeriGas OLP to participate in settlement discussions. We have a settlement agreement in principle that is being finalized.

Other Matters

West Reading, Pennsylvania Explosion. On March 24, 2023, an explosion occurred in West Reading, Pennsylvania which resulted inseven fatalities, injuries to at leastten others, and extensive property damage to buildings owned by R.M. Palmer, a local chocolate manufacturer, and neighboring structures. The NTSB and PAPUC investigated the West Reading incident. The NTSB investigative team included representatives from the Company, the local fire department and the Pipeline and Hazardous Materials Safety Administration. The Company cooperated with the investigations. In September 2023, OSHA closed their investigation of this matter, without any finding pertaining to UGI Utilities.

On December 10, 2024, the NTSB staff presented its draft findings to the NTSB Board. On April 8, 2025, the NTSB released its final report concluding that a fracture in an R.M. Palmer steam pipe created elevated underground temperatures that caused thermal degradation of a UGI Utilities service tee, resulting in a natural gas leak, and recommended UGI Utilities inventory and address risks to plastic gas assets in high-temperature environments.

On March 18, 2026, the PAPUC filed a formal complaint against UGI Utilities. The complaint alleges various pipeline safety violations and seeks civil penalties. The Company is vigorously defending against the allegations in the complaint. The Company does not believe the resolution of this matter will have a material adverse effect on its financial condition, results of operations, or cash flows.

The Company also has received claims as a result of the explosion and is involved in lawsuits relative to the incident. With the issuance of the final NTSB report, discovery in the litigation has begun. The Company maintains liability insurance for personal injury, property and casualty damages and believes that third-party claims associated with the explosion, in excess of the Company’s deductible, are recoverable through the Company’s insurance. The Company cannot predict the result of these pending or future claims and legal actions at this time.

Regarding these pending claims and legal actions, other than as disclosed above, the Company does not believe, at this early stage, that there is sufficient information available to reasonably estimate a range of loss, if any, or conclude that the final outcome of all of these matters will or will not have a material adverse effect on our financial statements.

In addition to the matters described above, there are other pending claims and legal actions arising in the normal course of our businesses. Although we cannot predict the final results of these pending claims and legal actions, including those described above, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our financial statements.

Note 10 — Fair Value Measurements

Recurring Fair Value Measurements

The following table presents, on a gross basis, our financial assets and liabilities, including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy:

(a)Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans.

The fair values of our Level 1 exchange-traded commodity futures and option contracts and non-exchange-traded commodity futures and forward contracts are based upon actively quoted market prices for identical assets and liabilities. Substantially all of the remaining derivative instruments are designated as Level 2. The fair values of certain non-exchange-traded commodity derivatives designated as Level 2 are based upon indicative price quotations available through brokers, industry price publications or recent market transactions and related market indicators. The fair values of our Level 2 interest rate contracts and foreign currency contracts are based upon third-party quotes or indicative values based on recent market transactions. The fair values of investments held in grantor trusts are derived from quoted market prices as substantially all of the investments in these trusts have active markets.

Nonrecurring Fair Value Measurements

During the quarter ended March 31, 2026, in connection with the disposition of the LPG distribution businesses in Czech Republic, Hungary, Poland and Slovakia, we recognized a non-cash, pre-tax impairment charge of $64, to reduce the carrying amount of the long-lived assets included in the disposal groups to their estimated fair values. The Company determined the estimated fair value of such assets fell within Level 2 of the fair value hierarchy and was based upon the estimated sales price. See Note 5 for additional information on these transactions.

Other Financial Instruments

The carrying amounts of other financial instruments included in current assets and current liabilities (except for current maturities of long-term debt) approximate their fair values because of their short-term nature. We estimate the fair value of long-term debt by using current market rates and by discounting future cash flows using rates available for similar type debt (Level 2). The carrying amounts and estimated fair values of our long-term debt (including current maturities but excluding unamortized debt issuance costs) were as follows:

Financial instruments other than derivative instruments, such as short-term investments and trade accounts receivable, could expose us to concentrations of credit risk. We limit credit risk from short-term investments by investing only in investment-grade commercial paper, money market mutual funds, securities guaranteed by the U.S. Government or its agencies and FDIC insured bank deposits. The credit risk arising from concentrations of trade accounts receivable is limited because we have a large customer base that extends across many different U.S. markets and a number of foreign countries. See Note 11 for information regarding concentrations of credit risk associated with our derivative instruments.

Note 11 — Derivative Instruments and Hedging Activities

We are exposed to certain market risks related to our ongoing business operations. Management uses derivative financial and commodity instruments, among other things, to manage: (1) commodity price risk; (2) interest rate risk; and (3) foreign currency exchange rate risk. Although we use derivative financial and commodity instruments to reduce market risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes. The use of derivative instruments is controlled by our risk management and credit policies, which govern, among other things, the derivative instruments we can use, counterparty credit limits and contract authorization limits. Although our commodity derivative instruments extend over a number of years, a significant portion of our commodity derivative instruments economically hedge commodity price risk during the next twelve months. See Note 2 for information on the accounting for our derivative instruments.

The following sections summarize the types of derivative instruments used by the Company to manage these market risks.

Commodity Price Risk

Regulated Utility Operations

Natural Gas

PA Gas Utility’s tariffs contain clauses that permit recovery of all prudently incurred costs of natural gas it sells to retail core-market customers, including the cost of financial instruments used to hedge purchased gas costs. As permitted and agreed to by the PAPUC pursuant to PA Gas Utility’s annual PGC filings, PA Gas Utility currently uses NYMEX natural gas futures and option contracts to reduce commodity price volatility associated with a portion of the natural gas it purchases for its retail core-market customers. See Note 7 for further information on the regulatory accounting treatment for these derivative instruments.

Non-utility Operations

LPG

In order to manage market price risk associated with the Partnership’s fixed-price programs and to reduce the effects of short-term commodity price volatility, the Partnership uses over-the-counter derivative commodity instruments, principally price swap contracts. In addition, the Partnership and our UGI International operations also use over-the-counter price swap and option contracts to reduce commodity price volatility associated with a portion of their forecasted LPG purchases.

Natural Gas

In order to manage market price risk relating to fixed-price sales contracts for physical natural gas, Midstream & Marketing enters into NYMEX and over-the-counter natural gas futures and over-the-counter and ICE natural gas basis swap contracts. In addition, Midstream & Marketing uses NYMEX and over-the-counter futures and options contracts to economically hedge price volatility associated with the gross margin derived from the purchase and anticipated later near-term sale of natural gas storage inventories. Outside of the financial market, Midstream & Marketing also uses ICE and over-the-counter forward physical contracts.

Electricity

In order to manage market price risk relating to fixed-price sales contracts for electricity, Midstream & Marketing enters into electricity futures and forward contracts.

Interest Rate Risk

Certain of our long-term debt agreements have interest rates that are generally indexed to short-term market interest rates. In order to fix the underlying short-term market interest rates, we may enter into pay-fixed, receive-variable interest rate swap agreements and designate such swaps as cash flow hedges.

The remainder of our long-term debt is typically issued at fixed rates of interest. As this long-term debt matures, we typically refinance such debt with new debt having interest rates reflecting then-current market conditions. In order to reduce market rate risk on the underlying benchmark rate of interest associated with near- to medium-term forecasted issuances of fixed-rate debt, from time to time we enter into IRPAs. We account for IRPAs as cash flow hedges. There wereno unsettled IRPAs during any of the periods presented. At June 30, 2026, the amount of pre-tax net (gains) losses associated with interest rate hedges expected to be reclassified into earnings during the next twelve months is not material.

Foreign Currency Exchange Rate Risk

Forward Foreign Currency Exchange Contracts

In order to reduce the volatility in net income associated with our foreign operations, principally as a result of changes in the USD exchange rate to the euro and British pound sterling, we enter into forward foreign currency exchange contracts. We layer in these foreign currency exchange contracts over multi-year periods to eventually equal approximately 90% of anticipated UGI International foreign currency earnings before income taxes. Because these contracts are not designated as hedging instruments, realized and unrealized gains and losses on these contracts are recorded in “Other non-operating income (expense), net” on the Condensed Consolidated Statements of Income.

Net Investment Hedges

From time to time, we also enter into certain forward foreign currency exchange contracts to reduce the volatility of the USD value of a portion of our UGI International euro-denominated net investments, including anticipated foreign currency denominated dividends. We account for these foreign currency exchange contracts as net investment hedges and all changes in the fair value of these contracts are reported in the cumulative translation adjustment component in AOCI. We use the spot rate method to measure ineffectiveness of our net investment hedges.

Our euro-denominated long-term debt has also been designated as net investment hedges, representing a portion of our UGI International euro-denominated net investment. We recognized pre-tax gains (losses) associated with these net investment hedges in the cumulative translation adjustment component in AOCI of $13 and $(68) during the three months ended June 30, 2026 and 2025, respectively, and $26 and $(46) during the nine months ended June 30, 2026 and 2025, respectively.

Quantitative Disclosures Related to Derivative Instruments

The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at June 30, 2026, September 30, 2025 and June 30, 2025, and the final settlement dates of the Company's open derivative contracts as of June 30, 2026, but excluding those derivatives that qualified for the NPNS exception:

Derivative Instrument Credit Risk

We are exposed to risk of loss in the event of nonperformance by our derivative instrument counterparties. Our derivative instrument counterparties principally comprise large energy companies and major U.S. and international financial institutions. We maintain credit policies with regard to our counterparties that we believe reduce overall credit risk. These policies include evaluating and monitoring our counterparties’ financial condition, including their credit ratings, and entering into agreements with counterparties that govern credit limits or entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate.

We have concentrations of credit risk associated with derivative instruments and we evaluate the creditworthiness of our derivative counterparties on an ongoing basis. At June 30, 2026, the maximum amount of loss, based upon the gross fair values of the derivative instruments, we would incur if these counterparties failed to perform according to the terms of their contracts was $112. In general, many of our over-the-counter derivative instruments and all exchange contracts call for the posting of collateral by the counterparty or by the Company in the forms of letters of credit, parental guarantees or cash. At June 30, 2026, we had received cash collateral from derivative instrument counterparties totaling $1. In addition, we may have offsetting derivative liabilities and certain accounts payable balances with certain of these counterparties, which further mitigates the previously mentioned maximum amount of losses. Certain of the Partnership’s derivative contracts have credit-risk-related contingent features that may require the posting of additional collateral in the event of a downgrade of the Partnership’s debt rating. At June 30, 2026, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material.

Offsetting Derivative Assets and Liabilities

Derivative assets and liabilities are presented net by counterparty on the Condensed Consolidated Balance Sheets if the right of offset exists. We offset amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against amounts recognized for derivative instruments executed with the same counterparty. Our derivative instruments include both those that are executed on an exchange through brokers and centrally cleared and over-the-counter transactions. Exchange contracts utilize a financial intermediary, exchange or clearinghouse to enter, execute or clear the transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Certain over-the-counter and exchange contracts contain contractual rights of offset through master netting arrangements, derivative clearing agreements and contract default provisions. In addition, the contracts are subject to conditional rights of offset through counterparty nonperformance, insolvency or other conditions.

In general, many of our over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral generally include cash or letters of credit. Cash collateral paid by us to our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative liabilities. Cash collateral received by us from our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative assets. Certain other accounts receivable and accounts payable balances recognized on the Condensed Consolidated Balance Sheets with our derivative counterparties are not included in the table below but could reduce our net exposure to such counterparties because such balances are subject to master netting or similar arrangements.

Fair Value of Derivative Instruments

The following table presents the Company’s derivative assets and liabilities by type, as well as the effects of offsetting:

Effects of Derivative Instruments

The following tables provide information on the effects of derivative instruments on the Condensed Consolidated Statements of Income and changes in AOCI:

We are also a party to a number of other contracts that have elements of a derivative instrument. However, these contracts qualify for NPNS exception accounting because they provide for the delivery of products or services in quantities that are expected to be used in the normal course of operating our business and the price in these contracts are based on an underlying that is directly associated with the price of the product or service being purchased or sold. These contracts include, among others, binding purchase orders, contracts that provide for the purchase and delivery, or sale, of energy products, and service contracts that require the counterparty to provide commodity storage, transportation or capacity service to meet our normal sales commitments.

Note 12 — Accumulated Other Comprehensive Income (Loss)

The tables below present changes in AOCI, net of tax:

Note 13 — Segment Information

Our operations comprise four reportable segments generally based upon products or services sold, geographic location and regulatory environment: (1) Utilities; (2) Midstream & Marketing; (3) UGI International; and (4) AmeriGas Propane.

Corporate & Other includes UGI’s certain corporate and general expenses as well as interest expense that is not allocated to its reportable segments. Corporate & Other also includes certain items that are excluded from our CODM’s assessment of segment performance (see below for further details on these items).

The accounting policies of our reportable segments are the same as those described in Note 2, “Summary of Significant Accounting Policies,” in the Company’s 2025 Annual Report. Our Chief Executive Officer, who serves as the CODM, measures segment profitability based on “earnings before interest expense and income taxes.” The CODM uses this financial metric by comparing current period results to budgeted and prior year results at the reportable segment level to assess the segment performance and to allocate resources between the segments.

The following tables provide information about the Company’s reportable segments and the reconciliation to corresponding consolidated amounts:

(a)Represents the elimination of intersegment transactions principally among Midstream & Marketing, Utilities and AmeriGas Propane.

(b)For the Utilities reportable segment, operating and administrative expenses less revenue-related taxes (i.e., gross receipts and business occupation taxes) is considered a significant segment expense and was $96 and $96 for the three months ended June 30, 2026 and 2025, respectively, and $307 and $290 for the nine months ended June 30, 2026 and 2025, respectively.

(c)Excluding Corporate & Other, other segment items principally represent other operating and non-operating income and expenses.

(d)Corporate & Other includes specific items attributable to our reportable segments that are not included in the segment profit measures used by our CODM. The following table presents such pre-tax gains (losses) which have been included in Corporate & Other, and the reportable segments to which they relate, for the three and nine months ended June 30, 2026 and 2025: