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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
☒QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2024
OR
☐TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ________ to ________  
Commission file number 1-11071
UGI CORPORATION
(Exact name of registrant as specified in its charter)
Pennsylvania 23-2668356
(State or other jurisdiction of
incorporation or organization)		 (I.R.S. Employer
Identification No.)
500 North Gulph Road, King of Prussia, PA 19406
(Address of Principal Executive Offices) (Zip Code)
(610) 337-1000
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class:
Trading Symbol(s):
Name of each exchange on which registered:
Common Stock, without par value
UGI
New York Stock Exchange
Corporate UnitsUGICNew York Stock Exchange
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  Yes  ý  No  ¨
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ý  No  ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filerýAccelerated filer☐Non-accelerated filer☐
Smaller reporting company☐Emerging growth company☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes  ☐ No  ý
At April 30, 2024, there were 209,622,441 shares of UGI Corporation Common Stock, without par value, outstanding.

UGI CORPORATION AND SUBSIDIARIES
TABLE OF CONTENTS
 
 Page
Item 1. Legal Proceedings
i
GLOSSARY OF TERMS AND ABBREVIATIONS

Terms and abbreviations used in this Form 10-Q are defined below:

UGI Corporation and Related Entities

AmeriGas OLP - AmeriGas Propane, L.P., the principal operating subsidiary of AmeriGas Partners
AmeriGas Partners - AmeriGas Partners, L.P., an indirect wholly owned subsidiary of UGI; also referred to, together with its consolidated subsidiaries, as the “Partnership”
AmeriGas Propane - Reportable segment comprising AmeriGas Propane, Inc. and its subsidiaries, including AmeriGas Partners and AmeriGas OLP
AmeriGas Propane, Inc. - A wholly owned second-tier subsidiary of UGI and the general partner of AmeriGas Partners
AvantiGas - AvantiGas Limited, an indirect wholly owned subsidiary of UGI International, LLC
Company - UGI and its consolidated subsidiaries collectively
DVEP - DVEP Investeringen B.V., an indirect wholly owned subsidiary of UGI International, LLC
Electric Utility - UGI Utilities’ regulated electric distribution utility
Energy Services - UGI Energy Services, LLC, a wholly owned subsidiary of Enterprises
Enterprises - UGI Enterprises, LLC, a wholly owned subsidiary of UGI
ESFC - Energy Services Funding Corporation, a wholly owned subsidiary of Energy Services
Flaga - Flaga GmbH, an indirect wholly owned subsidiary of UGI International, LLC
Gas Utility - UGI’s regulated natural gas businesses, inclusive of PA Gas Utility and WV Gas Utility
MBL Bioenergy - MBL Bioenergy, LLC
Midstream & Marketing - Reportable segment comprising Energy Services and subsidiaries including UGID
Mountaineer - Mountaineer Gas Company, a natural gas distribution company in West Virginia and a wholly owned subsidiary of Mountaintop Energy Holdings, LLC
Mountaintop Energy Holdings, LLC - Parent company of Mountaineer and wholly owned subsidiary of UGI
PA Gas Utility - UGI Utilities’ regulated natural gas distribution business, primarily located in Pennsylvania
Partnership - AmeriGas Partners and its consolidated subsidiaries, including AmeriGas OLP; also referred to as “AmeriGas Partners”
Pine Run - Pine Run Gathering, LLC
UGI - UGI Corporation or, collectively, UGI Corporation and its consolidated subsidiaries
UGI France - UGI France SAS (a Société par actions simplifiée), an indirect wholly owned subsidiary of UGI International, LLC
UGI International - Reportable segment principally comprising UGI’s foreign operations
UGI International, LLC - UGI International, LLC, a wholly owned subsidiary of Enterprises
UGI Utilities - UGI Utilities, Inc., a wholly owned subsidiary of UGI comprising PA Gas Utility and Electric Utility
UGID - UGI Development Company, a wholly owned subsidiary of Energy Services
1
UniverGas - UniverGas Italia S.r.l, an indirect wholly owned subsidiary of UGI International, LLC
Utilities - Reportable segment comprising UGI Utilities and Mountaintop Energy Holdings, LLC
WV Gas Utility - Mountaineer’s regulated natural gas distribution business, located in West Virginia
Other Terms and Abbreviations
2023 Annual Report - UGI Annual Report on Form 10-K for the fiscal year ended September 30, 2023
2023 six-month period - Six months ended March 31, 2023
2023 three-month period - Three months ended March 31, 2023
2024 six-month period - Six months ended March 31, 2024
2024 three-month period - Three months ended March 31, 2024
2024 Purchase Contract - A forward stock purchase contract issued by the Company as a part of the issuance of Equity Units which obligates holders to purchase a number of shares of UGI Common Stock from the Company on June 1, 2024
2022 AmeriGas OLP Credit Agreement - Revolving credit agreement entered into by AmeriGas OLP on September 28, 2022 and scheduled to expire in September 2026
5.50% Senior Notes - An underwritten private offering of $700 million aggregate principal amount of notes due May 2025, co-issued by AmeriGas Partners and AmeriGas Finance Corp.
5.875% Senior Notes - An underwritten private offering of $675 million aggregate principal amount of notes due August 2026, co-issued by AmeriGas Partners and AmeriGas Finance Corp.
5.75% Senior Notes - An underwritten private offering of $525 million aggregate principal amount of notes due May 2027, co-issued by AmeriGas Partners and AmeriGas Finance Corp.
9.375% Senior Notes - An underwritten private offering of $500 million aggregate principal amount of notes due May 2028, co-issued by AmeriGas Partners and AmeriGas Finance Corp.
AOCI - Accumulated Other Comprehensive Income (Loss)
ASC - Accounting Standards Codification
ASC 606 - ASC 606, “Revenue from Contracts with Customers”
ASU - Accounting Standards Update
Bcf - Billions of cubic feet
COA - Consent Order and Agreement
CODM - Chief Operating Decision Maker as defined in ASC 280, “Segment Reporting”
Common Stock - Shares of UGI common stock
Convertible Preferred Stock - Preferred stock of UGI titled 0.125% series A cumulative perpetual convertible preferred stock without par value and having a liquidation preference of $1,000 per share
DS - Default service
DSIC - Distribution System Improvement Charge
Equity Unit - A corporate unit consisting of a 2024 Purchase Contract and 1/10th or 10% undivided interest in one share of Convertible Preferred Stock
Exchange Act - Securities Exchange Act of 1934, as amended
2
FASB - Financial Accounting Standards Board
FDIC - Federal Deposit Insurance Corporation
FERC - Federal Energy Regulatory Commission
Fiscal 2021 - The fiscal year ended September 30, 2021
Fiscal 2022 - The fiscal year ended September 30, 2022
Fiscal 2023 - The fiscal year ended September 30, 2023
Fiscal 2024 - The fiscal year ending September 30, 2024
Fiscal 2025 - The fiscal year ending September 30, 2025
Fiscal 2026 - The fiscal year ending September 30, 2026
GAAP - U.S. generally accepted accounting principles
Gwh - Millions of kilowatt hours
ICE - Intercontinental Exchange
IREP - Infrastructure Replacement and Expansion Plan
IRPA - Interest rate protection agreement
LNG - Liquefied natural gas
LPG - Liquefied petroleum gas
MDPSC - Maryland Public Service Commission
MGP - Manufactured gas plant
Mountaineer Credit Agreement - Revolving credit agreement entered into by Mountaineer on November 26, 2019, as amended, scheduled to expire in December 2025
NOAA - National Oceanic and Atmospheric Administration
NPNS - Normal purchase and normal sale
NTSB - National Transportation Safety Board
NYDEC - New York State Department of Environmental Conservation
NYMEX - New York Mercantile Exchange
OSHA - Occupational Safety and Health Administration
PADEP - Pennsylvania Department of Environmental Protection
PAPUC - Pennsylvania Public Utility Commission
PGA - Purchased gas adjustment
PGC - Purchased gas costs
PRP - Potentially responsible party
Purchase Contracts - Forward stock purchase contracts issued by UGI Corporation in May 2021, which obligate holders to purchase a number of shares of UGI common stock from the Company on June 1, 2024
3
Receivables Facility - A receivables purchase facility of Energy Services with an issuer of receivables-backed commercial paper
Retail core-market - Comprises firm residential, commercial and industrial customers to whom Utilities has a statutory obligation to provide service that purchase their natural gas from Utilities
RNG - Renewable natural gas
ROD - Record of Decision
SEC - U.S. Securities and Exchange Commission
U.K. - United Kingdom
U.S. - United States of America
UGI Utilities 2023 Credit Agreement - Revolving credit agreement entered into by UGI Utilities on November 9, 2023, as amended, scheduled to expire in November 2028
UGI Utilities Credit Agreement - Revolving credit agreement entered into by UGI Utilities on June 27, 2019, as amended, repaid in full and terminated concurrently with the execution of the UGI Utilities 2023 Credit Agreement
USD - U.S. dollar
VDP - Voluntary Departure Plan
WVPSC - Public Service Commission of West Virginia

4
UGI CORPORATION AND SUBSIDIARIES
PART I FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
CONDENSED CONSOLIDATED BALANCE SHEETS
(unaudited)
(Millions of dollars)
March 31,
2024		September 30,
2023		March 31,
2023
ASSETS
Current assets:
Cash and cash equivalents$263 $241 $321 
Restricted cash45 99 82 
Accounts receivable (less allowances for doubtful accounts of $83, $71 and $80, respectively)
1,192 878 1,487 
Accrued utility revenues98 33 94 
Inventories375 433 433 
Derivative instruments38 75 110 
Prepaid expenses and other current assets203 286 233 
Total current assets2,214 2,045 2,760 
Property, plant and equipment, (less accumulated depreciation of $4,781, $4,581 and $4,427, respectively)
8,608 8,547 8,255 
Goodwill3,048 3,027 3,709 
Intangible assets, net415 443 472 
Utility regulatory assets301 302 314 
Derivative instruments18 49 67 
Other assets1,020 988 852 
Total assets$15,624 $15,401 $16,429 
LIABILITIES AND EQUITY
Current liabilities:
Current maturities of long-term debt$54 $57 $62 
Short-term borrowings333 649 453 
Accounts payable579 613 757 
Derivative instruments33 60 117 
Other current liabilities824 895 884 
Total current liabilities1,823 2,274 2,273 
Long-term debt6,730 6,543 6,702 
Deferred income taxes1,030 928 958 
Derivative instruments26 27 48 
Other noncurrent liabilities1,184 1,235 1,234 
Total liabilities10,793 11,007 11,215 
Commitments and contingencies (Note 9)
Equity:
UGI Corporation stockholders’ equity:
Preferred stock, without par value (authorized – 5,000,000 shares; issued – 220,000, 220,000 and 220,000 Series A shares, respectively)
167 167 167 
UGI Common Stock, without par value (authorized — 450,000,000 shares; issued — 211,052,608, 210,906,052 and 210,730,077 shares, respectively)
1,505 1,503 1,492 
Retained earnings3,460 3,027 3,842 
Accumulated other comprehensive loss(254)(256)(241)
Treasury stock, at cost(56)(55)(55)
Total UGI Corporation stockholders’ equity4,822 4,386 5,205 
Noncontrolling interests9 8 9 
Total equity4,831 4,394 5,214 
Total liabilities and equity$15,624 $15,401 $16,429 
See accompanying notes to condensed consolidated financial statements.
5
UGI CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(unaudited)
(Millions of dollars, except per share amounts)
Three Months Ended
March 31,		Six Months Ended
March 31,
 2024202320242023
Revenues$2,467 $3,106 $4,588 $5,865 
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)1,030 2,148 2,232 5,254 
Operating and administrative expenses591 587 1,121 1,116 
Depreciation and amortization138 132 275 263 
Loss on disposal of UGI International energy marketing business
— — 28 215 
Other operating income, net(9)(16)(17)(34)
1,750 2,851 3,639 6,814 
Operating income (loss)
717 255 949 (949)
Income from equity investees
1 — 2 1 
Other non-operating income (expense), net11 2 (2)(26)
Interest expense(100)(93)(200)(185)
Income (loss) before income taxes
629 164 749 (1,159)
Income tax (expense) benefit
(133)(54)(159)315 
Net income (loss) attributable to UGI Corporation
$496 $110 $590 $(844)
Earnings (loss) per common share attributable to UGI Corporation stockholders:
Basic$2.36 $0.52 $2.81 $(4.02)
Diluted$2.30 $0.51 $2.74 $(4.02)
Weighted-average common shares outstanding (thousands):
Basic209,826 209,857 209,789 209,902 
Diluted215,245 216,120 215,393 209,902 
See accompanying notes to condensed consolidated financial statements.

6
UGI CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(unaudited)
(Millions of dollars)
Three Months Ended
March 31,		Six Months Ended
March 31,
 2024202320242023
Net income (loss) including noncontrolling interests
$496 $110 $590 $(844)
Other comprehensive income (loss):
Net gains (losses) on derivative instruments (net of tax of $(5), $6, $2 and $5, respectively)
12 (15)(3)(12)
Reclassifications of net gains on derivative instruments (net of tax of $5, $2, $8 and $4, respectively)
(9)(5)(19)(10)
Foreign currency adjustments (net of tax of $(7), $(1), $5 and $29, respectively)
(24)10 25 161 
Benefit plans (net of tax of $0, $0, $0 and $0, respectively)
(1)— (1)— 
Other comprehensive (loss) income(22)(10)2 139 
Comprehensive income (loss) attributable to UGI Corporation
$474 $100 $592 $(705)

See accompanying notes to condensed consolidated financial statements.

7
UGI CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited)
(Millions of dollars)
Six Months Ended
March 31,
 20242023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss) including noncontrolling interests
$590 $(844)
Adjustments to reconcile net income (loss) including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization275 263 
Deferred income tax expense (benefit), net95 (346)
Provision for uncollectible accounts35 36 
Changes in unrealized gains and losses on derivative instruments54 1,713 
Loss on disposal of UGI International energy marketing business28 215 
Settlement of Energy Services interest rate swap— 32 
Amortization of Energy Services interest rate swap settlement
(11)— 
Other, net(11)20 
Net change in:
Accounts receivable and accrued utility revenues(404)(450)
Income taxes receivable— 91 
Inventories63 254 
Utility deferred fuel and power costs, net of changes in unsettled derivatives3 40 
Accounts payable(20)(148)
Derivative instruments collateral deposits paid
(38)(453)
Other current assets19 21 
Other current liabilities(37)(20)
Net cash provided by operating activities641 424 
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment(325)(414)
Acquisitions of businesses and assets, net of cash acquired— (9)
Investments in equity method investees(47)(63)
Settlements of net investment hedges— 22 
Other, net19 (9)
Net cash used by investing activities(353)(473)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock(157)(151)
Issuances of long-term debt, net of discount and issuance costs
409 1,277 
Repayments of long-term debt and finance leases, including redemption premiums
(245)(1,219)
(Decrease) increase in short-term borrowings
(310)53 
Receivables Facility net (repayments) borrowings(10)15 
Payments on Purchase Contracts(8)(8)
Issuances of UGI Common Stock— 9 
Repurchases of UGI Common Stock— (22)
Net cash used by financing activities(321)(46)
Effect of exchange rate changes on cash, cash equivalents and restricted cash1 29 
Cash, cash equivalents and restricted cash decrease$(32)$(66)
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of period$308 $403 
Cash, cash equivalents and restricted cash at beginning of period340 469 
Cash, cash equivalents and restricted cash decrease$(32)$(66)
See accompanying notes to condensed consolidated financial statements.
8
UGI CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(unaudited)
(Millions of dollars, except per share amounts)
 Three Months Ended
March 31,		Six Months Ended
March 31,
 2024202320242023
Preferred stock, without par value
Balance, beginning of period$167 $167 $167 $162 
Cumulative effect of change in accounting
— — — 5 
Balance, end of period $167 $167 $167 $167 
Common stock, without par value  
Balance, beginning of period$1,501 $1,482 $1,503 $1,483 
Common Stock issued in connection with employee and director plans, net of tax withheld— 4 — 6 
Equity-based compensation expense4 6 2 9 
Cumulative effect of change in accounting
— — — (6)
Balance, end of period$1,505 $1,492 $1,505 $1,492 
Retained earnings  
Balance, beginning of period$3,042 $3,808 $3,027 $4,841 
Cumulative effect of change in accounting
— — — 1 
Losses on common stock transactions in connection with employee and director plans— (1)— (5)
Net income (loss) attributable to UGI Corporation496 110 590 (844)
Cash dividends on UGI Common Stock ($0.375, $0.36, $0.75 and $0.72, respectively)
(78)(75)(157)(151)
Balance, end of period$3,460 $3,842 $3,460 $3,842 
Accumulated other comprehensive income (loss)  
Balance, beginning of period$(232)$(231)$(256)$(380)
Net gains (losses) on derivative instruments12 (15)(3)(12)
Reclassification of net gains on derivative instruments(9)(5)(19)(10)
Benefit plans(1)— (1)— 
Foreign currency adjustments(24)10 25 161 
Balance, end of period$(254)$(241)$(254)$(241)
Treasury stock  
Balance, beginning of period$(55)$(46)$(55)$(40)
Common Stock issued in connection with employee and director plans, net of tax withheld— 1 — 7 
Repurchases of UGI Common Stock— (10)— (22)
Reacquired UGI Common Stock - employee and director plans(1)— (1)— 
Balance, end of period$(56)$(55)$(56)$(55)
Total UGI stockholders’ equity$4,822 $5,205 $4,822 $5,205 
Noncontrolling interests  
Balance, beginning of period$9 $8 $8 $8 
Other— 1 1 1 
Balance, end of period$9 $9 $9 $9 
Total equity$4,831 $5,214 $4,831 $5,214 
See accompanying notes to condensed consolidated financial statements.
9
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)

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, electricity generation 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 Mountaineer 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. Mountaineer is subject to regulation by the WVPSC and FERC. Electric Utility is subject to regulation by the PAPUC and FERC.

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, electricity generation and energy services businesses primarily in the eastern region of the U.S., eastern Ohio, the panhandle of West Virginia and California. UGID owns electricity generation facilities principally located in Pennsylvania. 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, Flaga, AvantiGas, and UniverGas. As of the end of the first quarter of Fiscal 2024, UGI International had exited substantially all of its European energy marketing business which primarily marketed natural gas and electricity to customers through third-party distribution systems in France, Belgium, the Netherlands, and the United Kingdom. See Note 5 for additional information regarding the UGI International energy marketing business.

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, 2023, 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 2023 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.
March 31,
2024		March 31,
2023
Cash and cash equivalents$263 $321 
Restricted cash45 82 
Cash, cash equivalents and restricted cash$308 $403 

10
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Earnings Per Common Share. Basic earnings per share attributable to UGI stockholders reflect the weighted-average number of common shares outstanding. Diluted earnings per share attributable to UGI stockholders include the effects of dilutive stock options, common stock awards and Equity Units. Shares used in computing basic and diluted earnings per share are as follows: 
Three Months Ended
March 31,		Six Months Ended
March 31,
 2024202320242023
Denominator (thousands of shares):
Weighted-average common shares outstanding — basic209,826 209,857 209,789 209,902 
Incremental shares issuable for stock options, common stock awards and Equity Units (a)5,419 6,263 5,604 — 
Weighted-average common shares outstanding — diluted215,245 216,120 215,393 209,902 
(a)For the three months ended March 31, 2024 and 2023, 8,659 and 5,980 shares, respectively, associated with outstanding stock option awards were excluded from the computation of diluted earnings per share above because their effect was antidilutive. For the six months ended March 31, 2024, 8,468 shares associated with outstanding stock option awards were excluded from the computation of diluted earnings per share above because their effect was antidilutive. For the six months ended March 31, 2023, 6,348 of such shares have been excluded as such incremental shares would be antidilutive due to the net loss for the period.

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 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.

For a more detailed description of the derivative instruments we use, our accounting for derivatives, our objectives for using them and other information, see Note 12.

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.
11
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
As previously disclosed in Note 12 in the Company’s 2023 Annual Report, a non-cash pre-tax goodwill impairment charge of $656 was recognized in Fiscal 2023 to reduce the carrying value of the AmeriGas Propane reporting unit to its fair value. The Company continues to monitor the AmeriGas Propane reporting unit for any changes in facts and circumstances that would indicate it is more likely than not that the fair value of the AmeriGas Propane reporting unit is less than its carrying amount. No such indicators were identified at March 31, 2024, however 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 further impairment. There is approximately $1.4 billion of goodwill in this reporting unit as of March 31, 2024.
With respect to UGI International's Fiscal 2023 goodwill impairment test, we determined that UGI International’s fair value exceeded its carrying value by approximately 10%. While the Company believes that its judgments used in the quantitative assessment of UGI International’s fair value are reasonable based upon currently available facts and circumstances, if UGI International 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 were no changes in facts and circumstances that would indicate that it is more likely than not that the fair value of the UGI International reporting unit may not be in excess of its book value at March 31, 2024. There is approximately $931 of goodwill in this reporting unit as of March 31, 2024. 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.

Segment Reporting. In November 2023, the FASB issued ASU 2023-07, “Improvements to Reportable Segment Disclosures (Topic 280)” which requires enhanced disclosure of (1) significant segment expenses that are regularly provided to the CODM and included within each reported measure of segment profit or loss, (2) the amount and description of the composition of other segment items which reconcile to segment profit or loss, and (3) the title and position of the entity’s CODM and an explanation of how the CODM uses the reported measure(s) of segment profit or loss in assessing segment performance and allocating resources. The amendments also expand the interim segment disclosure requirements. This new guidance is effective for the Company for annual periods beginning October 1, 2024 (Fiscal 2025) and interim periods beginning October 1, 2025 (Fiscal 2026). Early adoption is permitted. The amendments in this ASU apply retrospectively to all prior periods presented in the financial statements. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance 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 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.

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 2023 Annual Report for additional information on our revenues from contracts with customers.


12
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Revenue Disaggregation

The following tables present our disaggregated revenues by reportable segment:
Three Months Ended March 31, 2024 Total  Eliminations
(a) 		 Utilities Midstream & Marketing UGI International  AmeriGas Propane  Corporate & Other
Revenues from contracts with customers:
Utility:
Core Market:
Residential$353 $— $353 $— $— $— $— 
Commercial & Industrial144 — 144 — — — — 
Large delivery service54 — 54 — — — — 
Off-system sales and capacity releases32 (24)56 — — — — 
Other11 — 11 — — — — 
Total Utility594 (24)618 — — — — 
Non-Utility:
LPG:
Retail1,267 — — — 570 697 — 
Wholesale89 — — — 60 29 — 
Energy Marketing311 (38)— 332 17 — — 
Midstream:
Pipeline65 — — 65 — — — 
Peaking8 (69)— 77 — — — 
Other4 — — 4 — — — 
Electricity Generation6 — — 6 — — — 
Other67 — — — 16 51 — 
Total Non-Utility1,817 (107)— 484 663 777 — 
Total revenues from contracts with customers2,411 (131)618 484 663 777 — 
Other revenues (c)56 — 28 (1)10 18 1 
Total revenues $2,467 $(131)$646 $483 $673 $795 $1 
13
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Three Months Ended March 31, 2023 Total Eliminations
(a) 		 Utilities Midstream & Marketing UGI International  AmeriGas Propane  Corporate & Other
Revenues from contracts with customers:
Utility:
Core Market:
Residential$424 $— $424 $— $— $— $— 
Commercial & Industrial177 — 177 — — — — 
Large delivery service53 — 53 — — — — 
Off-system sales and capacity releases45 (28)73 — — — — 
Other 16 (1)17 — — — — 
Total Utility715 (29)744 — — — — 
Non-Utility:
LPG:
Retail1,328 — — — 573 755 — 
Wholesale109 — — — 64 45 — 
Energy Marketing740 (39)— 498 281 — — 
Midstream:
Pipeline66 — — 66 — — — 
Peaking10 (58)— 68 — — — 
Other4 — — 4 — — — 
Electricity Generation2 — — 2 — — — 
Other67 — — — 20 47 — 
Total Non-Utility2,326 (97)— 638 938 847 — 
Total revenues from contracts with customers3,041 (126)744 638 938 847 — 
Other revenues (c)65 (2)30 — 10 20 7 
Total revenues$3,106 $(128)$774 $638 $948 $867 $7 
14
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Six Months Ended March 31, 2024 Total Eliminations
(a) 		 Utilities Midstream & Marketing UGI International  AmeriGas Propane  Corporate & Other
Revenues from contracts with customers:
Utility:
Core Market:
Residential$635 $— $635 $— $— $— $— 
Commercial & Industrial252 — 252 — — — — 
Large delivery service103 — 103 — — — — 
Off-system sales and capacity releases53 (36)89 — — — — 
Other20 — 20 — — — — 
Total Utility1,063 (36)1,099 — — — — 
Non-Utility:
LPG:
Retail2,324 — — — 1,094 1,230 — 
Wholesale160 — — — 109 51 — 
Energy Marketing (b)
638 (64)— 604 140 — (42)
Midstream:
Pipeline130 — — 130 — — — 
Peaking11 (111)— 122 — — — 
Other7 — — 7 — — — 
Electricity Generation14 — — 14 — — — 
Other138 — — — 35 103 — 
Total Non-Utility3,422 (175)— 877 1,378 1,384 (42)
Total revenues from contracts with customers4,485 (211)1,099 877 1,378 1,384 (42)
Other revenues (c)
103 — 40 — 20 40 3 
Total revenues$4,588 $(211)$1,139 $877 $1,398 $1,424 $(39)


15
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Six Months Ended March 31, 2023 Total Eliminations
(a) 		 Utilities Midstream & Marketing UGI International  AmeriGas Propane  Corporate & Other
Revenues from contracts with customers:
Utility:
Core Market:
Residential$760 $— $760 $— $— $— $— 
Commercial & Industrial309 — 309 — — — — 
Large delivery service100 — 100 — — — — 
Off-system sales and capacity releases77 (61)138 — — — — 
Other26 (1)27 — — — — 
Total Utility1,272 (62)1,334 — — — — 
Non-Utility:
LPG:
Retail2,444 — — — 1,055 1,389 — 
Wholesale211 — — — 115 96 — 
Energy Marketing1,518 (116)— 1,035 599 — — 
Midstream:
Pipeline131 — — 131 — — — 
Peaking27 (97)— 124 — — — 
Other7 — — 7 — — — 
Electricity Generation10 — — 10 — — — 
Other142 — — — 38 104 — 
Total Non-Utility4,490 (213)— 1,307 1,807 1,589 — 
Total revenues from contracts with customers5,762 (275)1,334 1,307 1,807 1,589 — 
Other revenues (c)
103 (2)32 — 18 44 11 
Total revenues$5,865 $(277)$1,366 $1,307 $1,825 $1,633 $11 

(a)Includes intersegment revenues principally among Midstream & Marketing, and Utilities.
(b)Corporate & Other includes reduction of revenues of $42 associated with the early termination of certain DVEP customer contracts. See Note 5 for additional information.
(c)Primarily represents (1) revenues from tank rentals at AmeriGas Propane and UGI International; (2) revenues from certain gathering assets at Midstream & Marketing; (3) revenues from alternative revenue programs at Utilities, including the weather normalization adjustment rider beginning on November 1, 2022 for PA Gas Utility; and (4) 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 $126, $158 and $126 at March 31, 2024, September 30, 2023 and March 31, 2023, respectively, and are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated
16
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Balance Sheets. Revenues recognized for the six months ended March 31, 2024 and 2023, from the amounts included in contract liabilities at September 30, 2023 and 2022, were $114 and $119, 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 March 31, 2024, Midstream & Marketing and Utilities expect to record approximately $2.3 billion and $0.2 billion of revenues, respectively, related to the minimum future performance obligations over the remaining terms of the related contracts.

Note 5 — Dispositions

UGI International Energy Marketing Transactions

As of the end of the first quarter of Fiscal 2024, pursuant to its previously announced decision, the Company had exited substantially all of its European energy marketing business which primarily marketed natural gas and electricity to customers through third-party distribution systems in France, Belgium, the Netherlands, and the United Kingdom.

France. In October 2023, UGI International, through a wholly-owned subsidiary, sold substantially all of its energy marketing business located in France for a net cash payment to the buyer of $28. In conjunction with the sale, during the first quarter of Fiscal 2024, the Company recorded a pre-tax loss of $28, which amount principally represents the net payment to the buyer. The loss is reflected in “Loss on disposal of UGI International energy marketing business” on the Condensed Consolidated Statements of Income. The carrying values of the assets and liabilities associated with this business, principally comprising certain commodity derivative instruments, energy certificates and certain working capital, were not material.

Belgium. In September 2023, UGI International, through a wholly-owned subsidiary, sold its energy marketing business located in Belgium for a net cash payment to the buyer of $3. Pursuant to the sale agreement, the Company transferred to the buyer certain assets, principally comprising customer and energy broker contracts. In conjunction with the sale, during the fourth quarter of Fiscal 2023, the Company recorded a pre-tax loss of $6 which amount includes the net payment to the buyer, the write-off of certain prepaid energy broker payments and associated transaction costs and fees.

United Kingdom. In October 2022, UGI International, through a wholly-owned subsidiary, sold its natural gas marketing business located in the U.K. for a net cash payment to the buyer of $19 which includes certain working capital adjustments. In conjunction with the sale, during the first quarter of Fiscal 2023, the Company recorded a pre-tax loss of $215 substantially all of which was due to the non-cash transfer of commodity derivative instruments associated with the business. The loss is reflected in “Loss on disposal of UGI International energy marketing business” on the Condensed Consolidated Statements of Income. At the date of closing of the sale, these commodity derivative instruments had a net carrying value of $206 which is attributable to net unrealized gains on such instruments.

Netherlands. In September 2023, a substantial number of DVEP’s customers agreed to modify their energy marketing contracts whereby the Company would continue to provide the delivery of electricity and natural gas at fixed prices through December 31, 2023, with the Company’s obligations to provide future services terminated effective January 1, 2024. As consideration for the early termination of such contracts, the Company has agreed to make cash payments to the customers equal to the fair values of specific commodity derivative instruments associated with periods after December 31, 2023. The early termination agreements with DVEP customers are considered contract modifications and the cash consideration paid to these customers has been reflected as a reduction in revenues, on a pro-rata basis, over the remaining performance period of such agreements through December 31, 2023. During the first quarter of Fiscal 2024, the Company settled the commodity derivative instruments for a gain of $46, which represents the fair value of the specific commodity derivative instruments associated with periods after December 31, 2023; and reduced its revenues from these customers by $42, which represents the pro-rated performance obligation from October 1, 2023 through December 31, 2023.

17
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
In conjunction with the wind-down of its European energy marketing business, in December 2023, DVEP completed a sale of a substantial portion of its power purchase agreements to a third party for a total consideration to the buyer of $5. In conjunction with the sale, the Company recorded a loss of $5, which is reflected in “Other operating income, net” on the Condensed Consolidated Statements of Income.

During the first quarter of Fiscal 2023, the Company recorded a $19 pre-tax impairment charge to reduce the carrying values of certain assets associated with its energy marketing business in the Netherlands, comprising property, plant and equipment and intangible assets. The impairment charge is reflected in “Operating and administrative expenses” on the Condensed Consolidated Statements of Income and included in the UGI International reportable segment.

Note 6 — Inventories

Inventories comprise the following: 
March 31,
2024		September 30,
2023		March 31,
2023
Non-utility LPG and natural gas$196 $212 $230 
Gas Utility natural gas8 55 20 
Energy certificates63 64 76 
Materials, supplies and other108 102 107 
Total inventories$375 $433 $433 

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 2023 Annual Report. Other than removal costs, Utilities currently does not recover a rate of return on its regulatory assets listed below. The following regulatory assets and liabilities associated with Utilities are included on the Condensed Consolidated Balance Sheets:
March 31,
2024		September 30,
2023		March 31,
2023
Regulatory assets (a):
Income taxes recoverable$93 $94 $94 
Underfunded pension plans109 111 118 
Environmental costs32 28 34 
Deferred fuel and power costs— 27 38 
Removal costs, net23 23 22 
Other55 64 53 
Total regulatory assets$312 $347 $359 
Regulatory liabilities (a):
Postretirement benefit overcollections$11 $12 $10 
Deferred fuel and power refunds34 55 28 
State tax benefits — distribution system repairs44 43 39 
Excess federal deferred income taxes250 254 262 
Other8 2 6 
Total regulatory liabilities$347 $366 $345 
(a)Current regulatory assets are included in “Prepaid expenses and other current assets” and regulatory liabilities are included 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
18
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
generation supply costs collected from customers and recoverable costs incurred. Net undercollected costs are classified as a regulatory asset and net overcollections 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 losses on such contracts at March 31, 2024, September 30, 2023 and March 31, 2023 were $7, $2 and $17, respectively.

Other Regulatory Matters

UGI Utilities. On January 27, 2023, Electric Utility filed a request with the PAPUC to increase its annual base distribution revenues by $11. On September 21, 2023, the PAPUC issued a final order approving a settlement providing for a $9 annual base distribution rate increase for Electric Utility, effective October 1, 2023.
On January 28, 2022, PA Gas Utility filed a request with the PAPUC to increase its base operating revenues for residential, commercial and industrial customers by $83 annually. On September 15, 2022, the PAPUC issued a final order approving a settlement providing for a $49 annual base distribution rate increase for PA Gas Utility, through a phased approach, with $38 beginning October 29, 2022 and an additional $11 beginning October 1, 2023. In accordance with the terms of the final order, PA Gas Utility was not permitted to file a rate case prior to January 1, 2024. Also in accordance with the terms of the final order, PA Gas Utility was authorized to implement a weather normalization adjustment rider as a five-year pilot program beginning on November 1, 2022. Under this rider, when weather deviates from normal by more than 3%, for bills rendered during the period of October 1 through May 31, residential and small commercial customer billings for distribution services are adjusted monthly for weather related impacts exceeding the 3% threshold. Additionally, under the terms of the final order, PA Gas Utility was authorized to implement a DSIC once its total property, plant and equipment less accumulated depreciation reached $3,368 (which threshold was achieved in September 2022).
Mountaineer. On July 31, 2023, Mountaineer submitted its 2023 IREP filing to the WVPSC requesting recovery of $10 for costs associated with capital investments after December 31, 2022, that total $131, including $67 in calendar year 2024. The filing included capital investments totaling $383 over the 2024 - 2028 period. On December 20, 2023, the WVPSC issued a final order approving a settlement effective January 1, 2024.
On March 6, 2023, Mountaineer submitted a base rate case filing with the WVPSC seeking a net revenue increase of $20, which consists of an increase in base rates of $38 and a decrease in the IREP rates of $18 annually. On October 6, 2023, Mountaineer filed a joint stipulation and agreement for settlement of the base rate case, which included a $14 net revenue increase, effective January 1, 2024. On December 21, 2023, the WVPSC issued a final order approving the joint stipulation and agreement, except the WVPSC authorized Mountaineer to implement a weather normalization adjustment rider as a five-year pilot program beginning on October 1, 2024. On April 11, 2024 the WVPSC approved the calculation methodology submitted by Mountaineer on March 28, 2024. Under this rider, when weather deviates from normal by more than 2%, for service rendered during the period October 1 through May 31, residential and small commercial customer billings for distribution services are adjusted for weather related impacts exceeding the 2% threshold.
On July 29, 2022, Mountaineer submitted its 2022 IREP filing to the WVPSC requesting recovery of costs associated with capital investments totaling $354 over the 2023 - 2027 period, including $64 in calendar year 2023. On December 21, 2022, the WVPSC issued a final order approving a settlement for $22 in cumulative revenue, effective January 1, 2023.

Note 8 — Debt

Significant Financing Activities

The following significant financing activities occurred during Fiscal 2024.

UGI Corporation Credit Facility Agreement. On April 30, 2024, UGI entered into the fourth amendment to the UGI Corporation Credit Facility Agreement which extended the maturity date of a substantial portion of the (1) $215 delayed draw term loan facility, (2) $300 term loan facility, (3) $250 term loan facility, and (4) $300 revolving credit facility to August 2025. In addition, the fourth amendment to the UGI Corporation Credit Facility Agreement increased the applicable rate (as defined in
19
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
the amended UGI Corporation Credit Facility Agreement) of the $215 delayed draw term loan facility, and the $300 term loan facility by 0.375%.

Mountaineer Credit Agreement. On April 26, 2024, Mountaineer entered into the fourth amendment to the Mountaineer Credit Agreement, which extends the maturity date of the agreement from November 2024 to December 2025. The applicable margin remains unchanged from the original credit agreement.

AmeriGas Partners Senior Notes. In March 2024, AmeriGas Partners and AmeriGas Finance Corp entered into separate, privately negotiated repurchase agreements with a limited number of holders of the outstanding senior notes to repurchase $38 aggregate principal amount of the senior notes. AmeriGas Partners and AmeriGas Finance Corp repurchased $7, $11, $13, and $7 par value of its issued and outstanding 5.50% Senior Notes, 5.875% Senior Notes, 5.75% Senior Notes, and 9.375% Senior Notes, respectively. Following these repurchases, $2,362 aggregate principal amount of these senior notes remain outstanding at March 31, 2024.
UGI Utilities Senior Notes. On November 30, 2023, UGI Utilities entered into a Note Purchase Agreement with a consortium of lenders. Pursuant to the Note Purchase Agreement, UGI Utilities issued (1) $25 aggregate principal amount of 6.02% Senior Notes due November 30, 2030; (2) $150 aggregate principal amount of 6.10% Senior Notes due November 30, 2033; and (3) $75 aggregate principal amount of 6.40% Senior Notes due November 30, 2053. 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. These senior notes are unsecured and rank equally with UGI Utilities’ existing outstanding senior debt. The net proceeds from these issuances were used to reduce short-term borrowings and for general corporate purposes.
2022 AmeriGas OLP Credit Agreement. Under the 2022 AmeriGas OLP Credit Agreement, AmeriGas OLP, as borrower, is required to comply with financial covenants related to leverage and interest coverage measured at the Partnership and at AmeriGas OLP. The 2022 AmeriGas OLP Credit Agreement contains an equity cure provision, which allows AmeriGas OLP’s direct or indirect parent, including UGI and its other subsidiaries, to fund capital contributions to eliminate any EBITDA (as defined in the 2022 AmeriGas OLP Credit Agreement) shortfalls that would otherwise result in non-compliance with these financial covenants. Each equity cure is eligible to eliminate such EBITDA shortfalls up to four quarters after contribution. We are permitted to use the equity cure provision five times over the course of the Credit Agreement, twice during any rolling four-quarter period, and not in consecutive quarters.

UGI made capital contributions to AmeriGas OLP during Fiscal 2023, a portion of which represented one equity cure that was eligible to eliminate any EBITDA shortfalls through December 31, 2023, in accordance with the 2022 AmeriGas OLP Credit Agreement. As a result of such capital contributions, AmeriGas OLP and the Partnership were in compliance with all financial covenants after consideration of the equity cure provision as of December 31, 2023. As of March 31, 2024, the Partnership was in compliance with all debt covenants as set forth in the 2022 AmeriGas OLP Credit Agreement without the consideration of the equity cure provision. The financial covenant leverage ratio under the 2022 AmeriGas OLP Credit Agreement as of March 31, 2024 must be no greater than 5.75, with a decrease to 5.50 beginning in September 2024. The actual leverage ratio as of March 31, 2024 was 5.74.
UGI provided an irrevocable letter of support whereby UGI has committed to fund any such EBITDA shortfalls and debt service, if any. Based on the support and the projected EBITDA, AmeriGas OLP is expected to remain in compliance with its financial debt covenants for the succeeding twelve-month period.

On November 15, 2023, the Partnership entered into an amendment to the 2022 AmeriGas OLP Credit Agreement, which amends certain provisions of the credit agreement to, among other things, (i) reduce the maximum revolver amount from $600 to $400, (ii) reduce the minimum interest coverage ratio, effective for the fourth quarter of Fiscal 2023 through the end of Fiscal 2024 and (iii) provided that, beginning for the first quarter of Fiscal 2025, the minimum interest coverage ratio will remain reduced if the net leverage ratio is below a certain threshold as defined by the agreement; if the net leverage ratio exceeds such threshold, the minimum interest coverage ratio will revert to the original ratio as defined by the agreement.
UGI Utilities 2023 Credit Agreement. On November 9, 2023, UGI Utilities entered into the UGI Utilities 2023 Credit Agreement providing for borrowings up to $375 (including a $50 sublimit for letters of credit and a $38 sublimit for swingline loans). UGI Utilities may request an increase in the amount of loan commitments under the credit agreement to a maximum
20
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
aggregate amount of $125. The interest rates applicable to borrowings under the UGI Utilities 2023 Credit Agreement remain unchanged from its predecessor agreement, the UGI Utilities Credit Agreement. The UGI Utilities 2023 Credit Agreement contains customary covenants and default provisions and requires compliance with certain financial covenants including a maximum debt to capitalization ratio as defined in the agreement. The credit agreement is scheduled to expire November 2028. Borrowings under the credit agreement may be used to refinance UGI Utilities existing indebtedness and for general corporate purposes and ongoing working capital needs of UGI Utilities.

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 operated two 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 2031. 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 March 31, 2024, September 30, 2023 and March 31, 2023, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the COA totaled $56, $52 and $52, 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 Propane

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
21
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
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. Based on our evaluation of the available information as of March 31, 2024, the Partnership has an undiscounted environmental remediation liability of $8 related to the site. Our share of the actual remediation costs could be significantly more or less than the accrued amount.

Other Matters

West Reading, Pennsylvania Explosion. On March 24, 2023, an explosion occurred in West Reading, Pennsylvania which resulted in seven fatalities, significant injuries to eleven others, and extensive property damage to buildings owned by R.M. Palmer, a local chocolate manufacturer, and other neighboring structures. The NTSB and the PAPUC are investigating the West Reading incident. On July 18, 2023, the NTSB issued an Investigative Update in its ongoing investigation and on February 22, 2024 it released its investigation docket including factual reports and detailed incident documentation. The NTSB report identified a fracture in a retired UGI Utilities gas service tee and a fracture in a nearby steam system, but it does not address causation of the fractures or the explosion. The NTSB investigative team includes representatives from the Company, the PAPUC, the local fire department and the Pipeline and Hazardous Materials Safety Administration. The Company is cooperating with the investigation. The NTSB may invite other parties to participate. In September 2023, OSHA closed their investigation of this matter, without any finding pertaining to UGI Utilities.

While the investigation into this incident is still underway and the cause of the explosion has not been determined, the Company has received claims as a result of the explosion and is involved in lawsuits relative to the incident. 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, 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 these matters will or will not have a material 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.

UGI International

In the first quarter of Fiscal 2024, UGI France initiated VDPs in consultation with the French Works Councils, pursuant to which employees are incentivized to voluntarily terminate employment or may be subject to involuntary termination to achieve certain workforce reductions. As of March 31, 2024, likelihood of termination benefits under VDPs was probable and the amount of such benefits was reasonably estimable. As a result, in the second quarter of Fiscal 2024, UGI International recorded pre-tax severance and other related expenses of $34, which are reflected in “Operating and administrative expenses” on the Condensed Consolidated Statements of Income.

Note 10 — Defined Benefit Pension and Other Postretirement Plans

The Company maintains defined benefit pension plans and other postretirement plans for certain current and former employees. The service cost component of our pension and other postretirement plans, net of amounts capitalized, is reflected in “Operating and administrative expenses” on the Condensed Consolidated Statements of Income. The non-service cost components, net of amounts capitalized by Utilities as a regulatory asset, are reflected in “Other non-operating income (expense), net” on the Condensed Consolidated Statements of Income. Other postretirement benefit cost was not material for all periods presented.

22
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Net periodic pension benefit cost (income) includes the following components:
 Pension Benefits
Three Months Ended March 31,20242023
Service cost$2 $3 
Interest cost9 8 
Expected return on assets(11)(12)
Amortization of:
Actuarial loss1 — 
Net benefit cost (income)$1 $(1)
   
Six Months Ended March 31,20242023
Service cost$4 $5 
Interest cost18 17 
Expected return on plan assets(22)(23)
Amortization of:
Actuarial loss (gain)1 (1)
Net benefit cost (income)$1 $(2)

23
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Note 11 — 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:
 Asset (Liability)
Level 1Level 2Level 3Total
March 31, 2024:
Derivative instruments:
Assets:
Commodity contracts
$107 $39 $— $146 
Foreign currency contracts$— $16 $— $16 
Interest rate contracts$— $11 $— $11 
Liabilities:
Commodity contracts
$(184)$(38)$— $(222)
Foreign currency contracts$— $(1)$— $(1)
Interest rate contracts$— $(3)$— $(3)
Non-qualified supplemental postretirement grantor trust investments (a)$41 $— $— $41 
September 30, 2023:
Derivative instruments:
Assets:
Commodity contracts (b)$117 $115 $— $232 
Foreign currency contracts$— $38 $— $38 
Interest rate contracts$— $28 $— $28 
Liabilities:
Commodity contracts (b)$(193)$(81)$— $(274)
Foreign currency contracts$— $(2)$— $(2)
Non-qualified supplemental postretirement grantor trust investments (a)$39 $— $— $39 
March 31, 2023:
Derivative instruments:
Assets:
Commodity contracts$229 $145 $— $374 
Foreign currency contracts$— $23 $— $23 
Interest rate contracts$— $25 $— $25 
Liabilities:
Commodity contracts$(294)$(138)$— $(432)
Foreign currency contracts$— $(4)$— $(4)
Interest rate contracts$— $(21)$— $(21)
Non-qualified supplemental postretirement grantor trust investments (a)$31 $— $— $31 
(a)Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans.
(b)Includes derivative assets and liabilities associated with certain UGI International energy marketing business transactions (see Note 5).
 
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
24
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
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.

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:
March 31, 2024September 30, 2023March 31, 2023
Carrying amount$6,826 $6,647 $6,805 
Estimated fair value$6,647 $6,238 $6,480 

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. For information regarding concentrations of credit risk associated with our derivative instruments, see Note 12.

Note 12 — 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. For information on the accounting for our derivative instruments, see Note 2.

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.

25
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
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. UGI International also uses natural gas futures and forward contracts to economically hedge market price risk associated with a substantial portion of anticipated volumes under fixed-price sales contracts with its customers. See Note 5 for information on the exit of substantially all of the Company’s European energy marketing business.

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. Midstream & Marketing also uses NYMEX and over-the-counter electricity futures contracts to economically hedge the price of a portion of its anticipated future sales of electricity from its electric generation facilities. UGI International also uses electricity futures and forward contracts to economically hedge market price risk associated with fixed-price sales and purchase contracts for electricity. See Note 5 for information on the exit of substantially all of the Company’s European energy marketing business.

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 were no unsettled IRPAs during any of the periods presented. At March 31, 2024, the amount of pre-tax net gains associated with interest rate hedges expected to be reclassified into earnings during the next twelve months is $19.

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.

26
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
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 $17 and $(9) during the three months ended March 31, 2024 and 2023, respectively, and $(15) and $(73) during the six months ended March 31, 2024 and 2023, respectively.

Quantitative Disclosures Related to Derivative Instruments

The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at March 31, 2024, September 30, 2023 and March 31, 2023, and the final settlement dates of the Company's open derivative contracts as of March 31, 2024, but excluding those derivatives that qualified for the NPNS exception:
Notional Amounts
(in millions)
TypeUnitsSettlements Extending ThroughMarch 31, 2024September 30, 2023March 31, 2023
Commodity Price Risk:
Regulated Utility Operations
PA Gas Utility NYMEX natural gas futures and option contractsDekathermsFebruary 202513 38 12 
Non-utility Operations
LPG swapsGallonsSeptember 2026425 727 691 
Natural gas futures, forward, basis swap, options and pipeline contracts (a)DekathermsMarch 2028339 338 366 
Electricity forward and futures contractsKilowatt hoursDecember 2027544 1,260 1,890 
Interest Rate Risk:
Interest rate swapsEuroMarch 2026€300 €300 €300 
Interest rate swapsUSDSeptember 2026$1,263 $1,270 $1,277 
Foreign Currency Exchange Rate Risk:
Forward foreign currency exchange contractsUSDSeptember 2026$240 $425 $285 
Net investment hedge forward foreign exchange contractsEuroDecember 2026€256 €256 €331 
(a)Amounts at September 30, 2023 include contracts associated with certain UGI International energy marketing business transactions (see Note 5).

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
27
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
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. As of March 31, 2024, 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 $173. 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 March 31, 2024, we had received cash collateral from derivative instrument counterparties totaling $6. 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 March 31, 2024, 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.

28
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
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:
March 31,
2024		September 30,
2023		March 31,
2023
Derivative assets:
Derivatives designated as hedging instruments:  
Foreign currency contracts$11 $14 $9 
Interest rate contracts11 28 25 
22 42 34 
Derivatives subject to PGC and DS mechanisms:
Commodity contracts8 6 19 
Derivatives not designated as hedging instruments:  
Commodity contracts (a)138 226 355 
Foreign currency contracts5 24 14 
143 250 369 
Total derivative assets — gross173 298 422 
Gross amounts offset in the balance sheet(111)(124)(190)
Cash collateral received(6)(40)(55)
Total derivative assets — net$56 $134 $177 
Derivative liabilities:
Derivatives designated as hedging instruments:
Interest rate contracts$(3)$— $(21)
Derivatives subject to PGC and DS mechanisms:
Commodity contracts(14)(8)(36)
Derivatives not designated as hedging instruments:
Commodity contracts (a)(208)(266)(396)
Foreign currency contracts(1)(2)(4)
(209)(268)(400)
Total derivative liabilities — gross(226)(276)(457)
Gross amounts offset in the balance sheet111 124 190 
Cash collateral pledged56 53 102 
Total derivative liabilities — net$(59)$(99)$(165)

(a)Includes certain derivative contracts associated with UGI International energy marketing business transactions (see Note 5). At September 30, 2023 there were $10 of derivative assets and $12 of derivative liabilities classified as held for sale, which are reflected in “Prepaid expenses and other current assets” and “Other current liabilities,” respectively, on the Condensed Consolidated Balance Sheets at September 30, 2023.

29
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
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:
Three Months Ended March 31,:
Gain (Loss)
Recognized in
AOCI		Gain
Reclassified from
AOCI into Income		Location of Gain Reclassified from
AOCI into Income
Cash Flow Hedges:2024202320242023
Interest rate contracts$17 $(21)$14 $7 Interest expense
Net Investment Hedges:
Foreign currency contracts$8 $(1)
Gain (Loss)
Recognized in Income
Derivatives Not Designated as Hedging Instruments:20242023Location of Gain (Loss) Recognized in Income
Commodity contracts$(1)$6 Revenues
Commodity contracts26 (343)Cost of sales
Commodity contracts(1)2 Other operating income, net
Foreign currency contracts8 (2)Other non-operating income (expense), net
Total$32 $(337)
Six Months Ended March 31,:
Loss
Recognized in
AOCI
Gain
Reclassified from
AOCI into Income
Location of Gain Reclassified from
AOCI into Income
Cash Flow Hedges:2024202320242023
Interest rate contracts$(5)$(17)$27 $14 Interest expense
Net Investment Hedges:
Foreign currency contracts$(2)$(24)
Gain (Loss)
Recognized in Income
Derivatives Not Designated as Hedging Instruments:20242023Location of Gain (Loss) Recognized in Income
Commodity contracts$1 $10 Revenues
Commodity contracts(129)(1,669)Cost of sales
Commodity contracts2 5 Other operating income, net
Foreign currency contracts(8)(34)Other non-operating income (expense), net
Total$(134)$(1,688)

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.

30
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Note 13 — Accumulated Other Comprehensive Income (Loss)

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

Three Months Ended March 31, 2024Postretirement Benefit PlansDerivative InstrumentsForeign CurrencyTotal
AOCI — December 31, 2023$17 $1 $(250)$(232)
Other comprehensive income (loss) before reclassification adjustments— 12 (24)(12)
Amounts reclassified from AOCI(1)(9)— (10)
Other comprehensive (loss) income attributable to UGI (1)3 (24)(22)
AOCI — March 31, 2024$16 $4 $(274)$(254)
Three Months Ended March 31, 2023Postretirement Benefit PlansDerivative InstrumentsForeign CurrencyTotal
AOCI — December 31, 2022$14 $35 $(280)$(231)
Other comprehensive (loss) income before reclassification adjustments— (15)10 (5)
Amounts reclassified from AOCI— (5)— (5)
Other comprehensive (loss) income attributable to UGI — (20)10 (10)
AOCI — March 31, 2023$14 $15 $(270)$(241)
Six Months Ended March 31, 2024Postretirement Benefit PlansDerivative InstrumentsForeign CurrencyTotal
AOCI — September 30, 2023$17 $26 $(299)$(256)
Other comprehensive (loss) income before reclassification adjustments
— (3)25 22 
Amounts reclassified from AOCI(1)(19)— (20)
Other comprehensive (loss) income attributable to UGI (1)(22)25 2 
AOCI — March 31, 2024$16 $4 $(274)$(254)
Six Months Ended March 31, 2023Postretirement Benefit PlansDerivative InstrumentsForeign CurrencyTotal
AOCI — September 30, 2022$14 $37 $(431)$(380)
Other comprehensive (loss) income before reclassification adjustments— (12)161 149 
Amounts reclassified from AOCI— (10)— (10)
Other comprehensive (loss) income attributable to UGI
— (22)161 139 
AOCI — March 31, 2023$14 $15 $(270)$(241)

31
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Note 14 — Equity Method Investments

We account for privately held equity securities of entities without readily determinable fair values in which we do not have control, but have significant influence over operating and financial policies, under the equity method. Our equity method investments principally comprise a number of investments in biomass and other renewable energy projects at Midstream & Marketing and a renewable energy joint venture at UGI International. Equity method investments are included in "Other assets" on the Condensed Consolidated Balance Sheets and equity method earnings are included in "Income from equity investees" on the Condensed Consolidated Statements of Income.

Equity method investments comprise the following:
Carrying ValueOwnership Interest
InvesteesMarch 31, 2024September 30,
2023		March 31,
2023		March 31,
2024		September 30,
2023		March 31,
2023
Midstream & Marketing:
Aurum Renewables$46 $45 $19 40%40%40%
Pine Run81 77 72 49%49%49%
MBL Bioenergy157 122 78 99.99%99.99%99.99%
Other21 20 20 variousvariousvarious
Total Midstream & Marketing305 264 189 
UGI International35 35 30 variousvariousvarious
Total investments in equity method investees$340 $299 $219 

See the Company’s 2023 Annual Report for additional information on our equity method investments.

Note 15 — 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 certain items that are excluded from our CODM’s assessment of segment performance (see below for further details on these items). Corporate & Other also includes the net expenses of UGI’s captive general liability insurance company, UGI’s corporate headquarters facility and UGI’s unallocated corporate and general expenses as well as interest expense on UGI debt that is not allocated. Corporate & Other assets principally comprise cash and cash equivalents of UGI and its captive insurance company, and UGI corporate headquarters’ assets. 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 2023 Annual Report.
32
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)

Three Months Ended March 31, 2024TotalEliminationsUtilitiesMidstream & MarketingUGI InternationalAmeriGas
Propane		Corporate
& Other (a)
Revenues from external customers$2,467 $— $623 $375 $673 $795 $1 
Intersegment revenues$— $(131)(b)$23 $108 $— $— $— 
Cost of sales$1,030 $(131)(b)$274 $283 $368 $362 $(126)
Operating income$717 $1 $225 $151 $124 $138 $78 
Income (loss) from equity investees1 — — 2 (1)— — 
Other non-operating income, net11 — 1 — 8 — 2 
Earnings before interest expense and income taxes729 1 226 153 131 138 80 
Interest expense(100)— (24)(9)(11)(40)(16)
Income before income taxes$629 $1  $202 $144 $120 $98 $64 
Depreciation and amortization$138 $— $41 $22 $29 $44 $2 
Capital expenditures (including the effects of accruals)$167 $— $91 $33 $19 $24 $— 
Three Months Ended March 31, 2023TotalEliminationsUtilitiesMidstream & MarketingUGI InternationalAmeriGas
Propane		Corporate
& Other (a)
Revenues from external customers$3,106 $— $746 $540 $948 $867 $5 
Intersegment revenues$— $(128)(b)$28 $98 $— $— $2 
Cost of sales$2,148 $(126)(b)$426 $479 $633 $430 $306 
Operating income (loss)$255 $(1)$203 $103 $120 $138 $(308)
Income (loss) income from equity investees— — — 2 (2)— — 
Other non-operating income (expense), net2 — 2 — 10 — (10)
Earnings (loss) before interest expense and income taxes257 (1)205 105 128 138 (318)
Interest expense(93)— (21)(11)(9)(39)(13)
Income (loss) before income taxes$164 $(1) $184 $94 $119 $99 $(331)
Depreciation and amortization$132 $— $37 $22 $28 $45 $— 
Capital expenditures (including the effects of accruals)$214 $— $133 $23 $30 $28 $— 
Six Months Ended March 31, 2024TotalEliminationsUtilitiesMidstream & MarketingUGI InternationalAmeriGas
Propane		Corporate
& Other (a)
Revenues from external customers$4,588 $— $1,103 $702 $1,398 $1,424 $(39)
Intersegment revenues$— $(211)(b)$36 $175 $— $— $— 
Cost of sales$2,232 $(211)(b)$495 $522 $814 $645 $(33)
Operating income (loss)
$949 $—  $359 $250 $237 $209 $(106)
Income (loss) from equity investees2 —  — 5 (3)— — 
Other non-operating (expense) income, net(2)— 2 — 14 — (18)
Earnings (loss) before interest expense and income taxes
949 — 361 255 248 209 (124)
Interest expense(200)—  (47)(20)(22)(81)(30)
Income (loss) before income taxes
$749 $—  $314 $235 $226 $128 $(154)
Depreciation and amortization$275 $—  $82 $44 $59 $88 $2 
Capital expenditures (including the effects of accruals)$300 $— $173 $52 $31 $44 $— 
As of March 31, 2024
Total assets$15,624 $(131)$5,850 $3,204 $3,030 $3,467 $204 
33
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Six Months Ended March 31, 2023TotalEliminationsUtilitiesMidstream & MarketingUGI InternationalAmeriGas
Propane		Corporate
& Other (a)
Revenues from external customers$5,865 $— $1,305 $1,094 $1,825 $1,633 $8 
Intersegment revenues$— $(277)(b)$61 $213 $— $— $3 
Cost of sales$5,254 $(275)(b)$755 $993 $1,295 $816 $1,670 
Operating (loss) income
$(949)$—  $329 $209 $176 $248 $(1,911)
Income (loss) from equity investees
1 —  — 3 (2)— — 
Other non-operating (expense) income, net(26)— 4 — 20 — (50)
(Loss) earnings before interest expense and income taxes
(974)— 333 212 194 248 (1,961)
Interest expense(185)—  (42)(22)(16)(82)(23)
(Loss) income before income taxes
$(1,159)$—  $291 $190 $178 $166 $(1,984)
Depreciation and amortization$263 $—  $74 $43 $56 $89 $1 
Capital expenditures (including the effects of accruals)$392 $— $250 $34 $57 $51 $— 
As of March 31, 2023
Total assets$16,429 $(232)$5,643 $3,116 $3,490 $4,248 $164 
(a)Corporate & Other includes specific items attributable to our reportable segments that are not included in the segment profit measures used by our CODM in assessing our reportable segments’ performance or allocating resources. The following table presents such pre-tax gains (losses) which have been included in Corporate & Other, and the reportable segments to which they relate:
34
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Three Months Ended March 31, 2024Location on Income StatementMidstream & MarketingUGI InternationalAmeriGas Propane
Net gains on commodity derivative instruments not associated with current-period transactionsCost of sales $41 $53 $34 
Net gains on commodity derivative instruments not associated with current-period transactionsOther operating income, net$— $1 $— 
Restructuring costsOperating and administrative expenses$— $(34)$— 
AmeriGas operations enhancement for growth projectOperating and administrative expenses$— $— $(6)
Unrealized gains on foreign currency derivative instrumentsOther non-operating income (expense), net$— $1 $— 
Costs associated with exit of the UGI International energy marketing businessOperating and administrative expenses/Other operating income, net$— $(2)$— 
Impairment of assetsOther operating income, net$— $(7)$— 
Three Months Ended March 31, 2023Location on Income StatementMidstream & MarketingUGI InternationalAmeriGas Propane
Net gains on commodity derivative instruments not associated with current-period transactionsRevenues$4 $1 $— 
Net (losses) gains on commodity derivative instruments not associated with current-period transactionsCost of sales $(78)$(235)$8 
Net losses on commodity derivative instruments not associated with current-period transactionsOther operating income, net$— $(1)$— 
AmeriGas operations enhancement for growth projectOperating and administrative expenses$— $— $(6)
Unrealized losses on foreign currency derivative instrumentsOther non-operating income (expense), net$— $(10)$— 
35
UGI CORPORATION AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(unaudited)
(Currency in millions, except per share amounts and where indicated otherwise)
Six Months Ended March 31, 2024Location on Income StatementMidstream & MarketingUGI InternationalAmeriGas Propane
Net gains on commodity derivative instruments not associated with current-period transactionsRevenues$1 $1 $— 
Net (gains) losses on commodity derivative instruments not associated with current-period transactionsCost of sales $(6)$12 $28 
Net losses on commodity derivative instruments not associated with current-period transactionsOther operating income, net$— $(2)$— 
Restructuring costsOperating and administrative expenses$— $(34)$— 
Unrealized losses on foreign currency derivative instrumentsOther non-operating income (expense), net$— $(19)$— 
AmeriGas operations enhancement for growth projectOperating and administrative expenses$— $— $(13)
Costs associated with exit of the UGI International energy marketing businessRevenues$— $(42)$— 
Costs associated with exit of the UGI International energy marketing business
Operating and administrative expenses/Other operating income, net
$— $(10)$— 
Costs associated with exit of the UGI International energy marketing businessLoss on disposal of UGI International energy marketing business$— $(28)$— 
Impairment of assetsOther operating income, net$— $(7)$— 
Six Months Ended March 31, 2023Location on Income StatementMidstream & MarketingUGI InternationalAmeriGas Propane
Net gains on commodity derivative instruments not associated with current-period transactions
Revenues$6 $3 $— 
Net losses on commodity derivative instruments not associated with current-period transactions
Cost of sales $(261)$(1,404)$(4)
Net losses on commodity derivative instruments not associated with current-period transactionsOther operating income, net$— $(3)$— 
Unrealized losses on foreign currency derivative instruments
Other non-operating income (expense), net$— $(50)$— 
AmeriGas operations enhancement for growth projectOperating and administrative expenses$— $— $(13)
Costs associated with exit of the UGI International energy marketing businessLoss on disposal of UGI International energy marketing business$— $(215)$— 
Costs associated with exit of the UGI International energy marketing businessOperating and administrative expenses$— $(19)$— 
(b)Represents the elimination of intersegment transactions principally among Utilities, Midstream & Marketing and AmeriGas Propane.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Forward-Looking Statements

Information contained in this Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Such statements use forward-looking words such as “believe,” “plan,” “anticipate,” “continue,” “estimate,” “expect,” “may,” or other similar words and terms of similar meaning, although not all forward-looking statements contain such words. These statements discuss plans, strategies, events or developments that we expect or anticipate will or may occur in the future. All forward-looking statements made in this Quarterly Report on Form 10-Q rely upon the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995.

A forward-looking statement may include a statement of the assumptions or bases underlying the forward-looking statement. We believe that we have chosen these assumptions or bases in good faith and that they are reasonable. However, we caution you against relying on any forward-looking statement as these statements are subject to risks and uncertainties that may cause actual results to vary from assumed facts or bases, and the differences between actual results and assumed facts or bases can be material, depending on the circumstances. When considering forward-looking statements, you should keep in mind those factors set forth in Item 1A. Risk Factors in the Company’s 2023 Annual Report and the following important factors that could affect our future results and could cause those results to differ materially from those expressed in our forward-looking statements: (1) weather conditions, including increasingly uncertain weather patterns due to climate change, resulting in reduced demand, the seasonal nature of our business, and disruptions in our operations and supply chain; (2) cost volatility and availability of energy products, including propane and other LPG, electricity, and natural gas, as well as the availability of LPG cylinders, and the capacity to transport product to our customers; (3) changes in domestic and foreign laws and regulations, including safety, health, tax, transportation, consumer protection, data privacy, accounting, and environmental matters, such as regulatory responses to climate change; (4) inability to timely recover costs through utility rate proceedings; (5) the impact of pending and future legal or regulatory proceedings, inquiries or investigations; (6) competitive pressures from the same and alternative energy sources; (7) failure to acquire new customers or retain current customers thereby reducing or limiting any increase in revenues; (8) liability for environmental claims; (9) increased customer conservation measures due to high energy prices and improvements in energy efficiency and technology resulting in reduced demand; (10) adverse labor relations and our ability to address existing or potential workforce shortages; (11) customer, counterparty, supplier, or vendor defaults; (12) liability for uninsured claims and for claims in excess of insurance coverage, including those for personal injury and property damage arising from explosions, acts of war, terrorism, natural disasters, pandemics, and other catastrophic events that may result from operating hazards and risks incidental to generating and distributing electricity and transporting, storing and distributing natural gas and LPG in all forms; (13) transmission or distribution system service interruptions; (14) political, regulatory and economic conditions in the United States, Europe and other foreign countries, including uncertainties related to the war between Russia and Ukraine, the European energy crisis, and foreign currency exchange rate fluctuations, particularly the euro; (15) credit and capital market conditions, including reduced access to capital markets and interest rate fluctuations; (16) changes in commodity market prices resulting in significantly higher cash collateral requirements; (17) impacts of our indebtedness and the restrictive covenants in our debt agreements; (18) reduced distributions from subsidiaries impacting the ability to pay dividends or service debt; (19) changes in Marcellus and Utica Shale gas production; (20) the availability, timing and success of our acquisitions, commercial initiatives and investments to grow our businesses; (21) our ability to successfully integrate acquired businesses and achieve anticipated synergies; (22) the interruption, disruption, failure, malfunction, or breach of our information technology systems, and those of our third-party vendors or service providers, including due to cyber attack; (23) the inability to complete pending or future energy infrastructure projects; (24) our ability to achieve the operational benefits and cost efficiencies expected from the completion of pending and future business transformation initiatives, including the impact of customer service disruptions resulting in potential customer loss due to the transformation activities; (25) our ability to attract, develop, retain and engage key employees; (26) uncertainties related to global pandemics; (27) the impact of proposed or future tax legislation; (28) the impact of declines in the stock market or bond market, and a low interest rate environment, on our pension liability; (29) our ability to protect our intellectual property; and (30) our ability to overcome supply chain issues that may result in delays or shortages in, as well as increased costs of, equipment, materials or other resources that are critical to our business operations.

These factors, and those factors set forth in Item 1A. Risk Factors in the Company’s 2023 Annual Report, are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other unknown or unpredictable factors could also have material adverse effects on future results. Any forward-looking statement speaks only as of the date on which such statement is made. We undertake no obligation (and expressly disclaim any obligation) to update publicly any forward-looking statement, whether as a result of new information or future events, except as required by the federal securities laws.

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ANALYSIS OF RESULTS OF OPERATIONS

The following analyses compare the Company’s results of operations for the 2024 three-month period with the 2023 three-month period and the 2024 six-month period with the 2023 six-month period. Our analysis of results of operations should be read in conjunction with the segment information included in Note 15 to Condensed Consolidated Financial Statements.

Because most of our businesses sell or distribute energy products used in large part for heating purposes, our results are significantly influenced by temperatures in our service territories, particularly during the heating-season months of October through March. As a result, our results of operations, after adjusting for the effects of gains and losses on derivative instruments not associated with current-period transactions as further discussed below, are significantly higher in our first and second fiscal quarters.

EXECUTIVE OVERVIEW

Recent Developments

Review of Strategic Alternatives

In August 2023, the Company announced the commencement of a strategic review of the LPG businesses, primarily focused on AmeriGas Propane, with the intent to unlock and maximize shareholder value. The Company explored a full range of options with the goal of reducing UGI’s earnings volatility and strengthening its balance sheet. During the review, the Company and its financial advisors evaluated several value creation opportunities including a potential sale, spin, and joint venture of AmeriGas. While the Company conducted due diligence with multiple strategic and financial parties, the Board of Directors decided that in the current market, the Company should focus on a restructuring and operational improvement plan for AmeriGas. The review concluded that disciplined execution of a revised operational strategy and optimization of UGI’s diverse mix of strategically located assets best positions the Company to create long-term shareholder value.

UGI International Energy Marketing Transactions

As of the end of the first quarter of Fiscal 2024, pursuant to its previously announced decision, the Company had exited substantially all of its European energy marketing business which primarily marketed natural gas and electricity to customers through third-party distribution systems in France, Belgium, the Netherlands, and the United Kingdom.

France. In October 2023, UGI International, through a wholly-owned subsidiary, sold substantially all of its energy marketing business located in France for a net cash payment to the buyer of $28 million. In conjunction with the sale, during the first quarter of Fiscal 2024, the Company recorded a pre-tax loss of $28 million, which amount principally represents the net payment to the buyer. The carrying values of the assets and liabilities associated with this business, principally comprising certain commodity derivative instruments, energy certificates and certain working capital, were not material.

Belgium. In September 2023, UGI International, through a wholly-owned subsidiary, sold its energy marketing business located in Belgium for a net cash payment to the buyer of $3 million. Pursuant to the sale agreement, the Company transferred to the buyer certain assets, principally comprising customer and energy broker contracts. In conjunction with the sale, during the fourth quarter of Fiscal 2023, the Company recorded a pre-tax loss of $6 million which includes the net payment to the buyer, the write-off of certain prepaid energy broker payments and associated transaction costs and fees.

United Kingdom. In October 2022, UGI International, through a wholly-owned subsidiary, sold its natural gas marketing business located in the U.K. for a net cash payment to the buyer of $19 million which includes certain working capital adjustments. In conjunction with the sale, during the first quarter of Fiscal 2023, the Company recorded a pre-tax loss of $215 million substantially all of which was due to the non-cash transfer of commodity derivative instruments associated with the business.

Netherlands. In September 2023, a substantial number of DVEP’s customers agreed to modify their energy marketing contracts whereby the Company would continue to provide the delivery of electricity and natural gas at fixed prices through December 31, 2023, with the Company’s obligations to provide future services terminated effective January 1, 2024. As consideration for the early termination of such contracts, the Company agreed to make cash payments to the customers equal to the fair values of specific commodity derivative instruments associated with periods after December 31, 2023. During the first quarter of Fiscal 2024, the Company settled the commodity derivative instruments for a gain of $46 million, which represented the fair value of the specific commodity derivative instruments associated with periods after December 31, 2023; and reduced its revenues from
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these customers by $42 million, which represented the pro-rated performance obligation from October 1, 2023 through December 31, 2023.

In conjunction with the wind-down of its European energy marketing business, in December 2023, DVEP completed a sale of a substantial portion of its power purchase agreements to a third party for a total consideration to the buyer of $5 million. In conjunction with the sale, the Company recorded a pre-tax loss of $5 million.

During the first quarter of Fiscal 2023, the Company recorded a $19 million pre-tax impairment charge to reduce the carrying values of certain assets associated with its energy marketing business in the Netherlands, comprising property, plant and equipment and intangible assets.

See Note 5 to Condensed Consolidated Financial Statements for additional information.

Global Macroeconomic Conditions
Beginning in Fiscal 2021 and continuing through March 31, 2024, global commodity and labor markets have experienced significant inflationary pressures attributable to various economic and geopolitical factors, including but not limited to: supply chain disruptions including those associated with labor shortages; significant volatility in energy commodity prices; changes in consumer behavior; and geopolitical and regulatory conditions resulting from the war between Russia and Ukraine. These adverse macroeconomic factors continue to contribute to inflationary pressures as evidenced by increases in various consumer price indices. In an effort to curb these inflationary pressures, central banks in the U.S. and Europe began raising interest rates in Fiscal 2022. In addition, during the last several years, we have experienced significant volatility in energy commodity prices, particularly in LPG, natural gas and electricity prices, which have resulted in substantial fluctuations in the fair values of our commodity derivative instruments. Although these inflationary pressures and commodity price volatility have moderated more recently, they continue to result in, among other things, fluctuations in the cost of our inventory and associated cost of sales, increases in certain operating and distribution expenses and higher interest expense across all of our businesses. We cannot predict the duration or ultimate magnitude of these conditions and the effects such conditions may have on our future business, financial results, financial position, liquidity and cash flows. However, we believe that the Company is well positioned to address the challenges resulting from these global economic and geopolitical conditions as they continue to evolve.
Non-GAAP Financial Measures
UGI management uses “adjusted net income attributable to UGI Corporation” and “adjusted diluted earnings per share,” both of which are non-GAAP financial measures, when evaluating UGI’s overall performance. Management believes that these non-GAAP measures provide meaningful information to investors about UGI’s performance because they eliminate gains and losses on commodity and certain foreign currency derivative instruments not associated with current-period transactions and other significant discrete items that can affect the comparison of period-over-period results.
UGI does not designate its commodity and certain foreign currency derivative instruments as hedges under GAAP. Volatility in net income (loss) attributable to UGI Corporation can occur as a result of gains and losses on such derivative instruments not associated with current-period transactions. These gains and losses result principally from recording changes in unrealized gains and losses on unsettled commodity and certain foreign currency derivative instruments and, to a much lesser extent, certain realized gains and losses on settled commodity derivative instruments that are not associated with current-period transactions. However, because these derivative instruments economically hedge anticipated future purchases or sales of energy commodities, or in the case of certain foreign currency derivatives reduce volatility in anticipated future earnings associated with our foreign operations, we expect that such gains or losses will be largely offset by gains or losses on anticipated future energy commodity transactions or mitigate volatility in anticipated future earnings. 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 measures.

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The following tables reflect the adjustments referred to above and reconcile net income (loss) attributable to UGI Corporation, the most directly comparable GAAP measure, to adjusted net income attributable to UGI Corporation, and reconcile diluted earnings per share, the most directly comparable GAAP measure, to adjusted diluted earnings per share:
Adjusted net income attributable to UGI Corporation
Three Months Ended
March 31,		Six Months Ended
March 31,
(Dollars in millions)2024202320242023
Utilities$155 $143 $241 $224 
Midstream & Marketing120 66 212 143 
UGI International91 92 174 137 
AmeriGas Propane37 73 53 122 
Corporate & Other (a)93 (264)(90)(1,470)
Net income (loss) attributable to UGI Corporation
496 110 590 (844)
Net (gains) losses on commodity derivative instruments not associated with current-period transactions (net of tax of $19, $(66), $1 and $(429), respectively)
(110)235 (33)1,234 
Unrealized (gains) losses on foreign currency derivative instruments (net of tax of $0, $(3), $(6) and $(14), respectively)(1)7 13 36 
Business transformation expenses (net of tax of $0, $0, $0 and $(1), respectively)
— 2 — 3 
AmeriGas operations enhancement for growth project (net of tax of $(1), $(1), $(3) and $(3), respectively)
5 5 10 10 
Restructuring costs (net of tax of $(9), $0, $(10) and $0, respectively)
27 — 30 — 
Costs associated with exit of UGI International energy marketing business (net of tax of $(1), $4, $(14) and $(64), respectively)
1 4 66 170 
Impairment of assets (net of tax of $(2), $0, $(2), and $0, respectively)5 — 5 — 
Total adjustments (a) (b)(73)253 91 1,453 
Adjusted net income attributable to UGI Corporation
$423 $363 $681 $609 
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UGI CORPORATION AND SUBSIDIARIES
Three Months Ended
March 31,		Six Months Ended
March 31,
Adjusted diluted earnings per share2024202320242023
Utilities$0.72 $0.66 $1.12 $1.04 
Midstream & Marketing0.56 0.31 0.98 0.66 
UGI International0.42 0.43 0.81 0.64 
AmeriGas Propane0.17 0.34 0.25 0.56 
Corporate & Other (a)0.43 (1.23)(0.42)(6.92)
Diluted earnings (loss) per share (c)
2.30 0.51 2.74 (4.02)
Net (gains) losses on commodity derivative instruments not associated with current-period transactions (c)(0.50)1.09 (0.16)5.80 
Unrealized losses on foreign currency derivative instruments
— 0.03 0.06 0.17 
Business transformation expenses— 0.01 — 0.01 
AmeriGas operations enhancement for growth project0.02 0.02 0.05 0.05 
Restructuring costs0.13 — 0.14 — 
Costs associated with exit of UGI International energy marketing business
— 0.02 0.31 0.81 
Impairment of assets0.02 — 0.02 — 
Total adjustments (a)(0.33)1.17 0.42 6.84 
Adjusted diluted earnings per share (c)
$1.97 $1.68 $3.16 $2.82 

(a)Corporate & Other includes certain adjustments made to our reporting segments in arriving at net income (loss) attributable to UGI Corporation. These adjustments have been excluded from the segment results to align with the measure used by our CODM in assessing segment performance and allocating resources. See Note 15 to Condensed Consolidated Financial Statements for additional information related to these adjustments, as well as other items included within Corporate & Other.
(b)Income taxes associated with pre-tax adjustments determined using statutory business unit tax rates.
(c)The loss per share for the six months ended March 31, 2023, was determined excluding the effect of 6.35 million dilutive shares as the impact of such shares would have been antidilutive due to the net loss for the period. Adjusted earnings per share for the six months ended March 31, 2023, was determined based upon fully diluted shares of 216.25 million.

2024 three-month period compared with 2023 three-month period

Discussion. Net income attributable to UGI Corporation for the 2024 three-month period was $496 million (equal to $2.30 per diluted share) compared to $110 million (equal to $0.51 per diluted share) for the 2023 three-month period. These results include net gains (losses) from changes in unrealized commodity derivative instruments and certain foreign currency derivative instruments of $111 million and $(242) million during the 2024 and 2023 three-month periods, respectively. The higher gains from changes in commodity derivative instruments during the 2024 three-month period principally reflects significantly less volatility in commodity energy prices following unprecedented volatility in such prices during the 2023 three-month period and the effects of significantly lower energy marketing activities in Europe resulting from the exit of substantially all of UGI International’s energy marketing business.

Net income attributable to UGI Corporation during the 2024 three-month period also includes (1) restructuring costs of $27 million, largely attributable to a reduction in workforce and related costs primarily at UGI International; (2) an impairment of assets of $5 million at UGI International; (3) external advisory fees of $5 million associated with AmeriGas operations enhancement for growth project; and (4) $1 million of costs associated with the exit of our UGI International energy marketing business in Europe.

Net income attributable to UGI Corporation during the 2023 three-month period also includes (1) external advisory fees of $5 million associated with AmeriGas operations enhancement for growth project; (2) $4 million of costs associated with the exit of our UGI International energy marketing business in Europe; and (3) business transformation expenses of $2 million associated with corporate support functions.
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UGI CORPORATION AND SUBSIDIARIES

Adjusted net income attributable to UGI Corporation for the 2024 three-month period was $423 million (equal to $1.97 per diluted share) compared to adjusted net income of $363 million (equal to $1.68 per diluted share) for the 2023 three-month period. The increase in adjusted net income attributable to UGI Corporation during the 2024 three-month period reflects higher earnings contributions from the Utilities and Midstream & Marketing segments, partially offset by lower earnings contributions from the AmeriGas Propane segment. The earnings contribution from the UGI International segment was comparable to the prior-year period. During the 2024 three-month period, temperatures in the Utilities and Midstream & Marketing segments were colder than the prior-year period while temperatures in the UGI International and AmeriGas Propane segments were warmer than the prior-year period.

Utilities’ adjusted net income attributable to UGI Corporation increased $12 million in the 2024 three-month period compared to the prior-year period. The increase was largely attributable to higher total margin due in large part to increases in base rates for both PA Gas Utility and Mountaineer during Fiscal 2024.

Midstream & Marketing’s adjusted net income attributable to UGI Corporation increased $54 million in the 2024 three-month period, primarily attributable to higher total margin mainly from natural gas marketing activities and lower income taxes reflecting higher investment tax credits in the 2024 three-month period.
UGI International’s adjusted net income attributable to UGI Corporation decreased $1 million in the 2024 three-month period, principally reflecting lower total margin from our energy marketing business, substantially offset by the benefit from higher average unit margin from our LPG business attributable to strong margin management efforts and lower operating and administrative expenses, primarily reflecting lower personnel and maintenance expenses.
AmeriGas Propane’s adjusted net income attributable to UGI Corporation decreased $36 million in the 2024 three-month period. This decrease is primarily attributable to higher income taxes reflecting valuation allowance on disallowed interest expense following its goodwill impairment charge in the third quarter of Fiscal 2023. Total margin was lower in the 2024 three-month period, primarily resulting from lower retail propane volumes sold, partially offset by the benefit of higher average retail propane unit margin. The decrease in total margin was largely offset by lower operating and administrative expenses, primarily reflecting lower advertising and compensation expenses.
2024 six-month period compared with 2023 six-month period

Discussion. Net income attributable to UGI Corporation for the 2024 six-month period was $590 million (equal to $2.74 per diluted share) compared to net loss attributable to UGI Corporation of $844 million (equal to $4.02 loss per diluted share) for the 2023 six-month period. These results include net gains (losses) from changes in unrealized commodity derivative instruments and certain foreign currency derivative instruments of $20 million and $(1,270) million during the 2024 and 2023 six-month periods, respectively. The higher gains from changes in commodity derivative instruments during the 2024 six-month period, principally reflects significantly less volatility in commodity energy prices in Europe following unprecedented volatility in such prices during the 2023 six-month period and the effects of significantly lower energy marketing activities in Europe resulting from the exit of substantially all of UGI International’s energy marketing business.

Net income attributable to UGI Corporation during the 2024 six-month period also includes (1) $66 million of costs associated with the exit of our UGI International energy marketing business in Europe, principally reflecting wind-down activities in the Netherlands and the loss on the sale of the energy marketing business located in France; (2) restructuring costs of $30 million largely attributable to a reduction in workforce and related costs; (3) external advisory fees of $10 million associated with AmeriGas operations enhancement for growth project; and (4) an impairment of assets of $5 million at UGI International.

Net loss attributable to UGI Corporation during the 2023 six-month period also includes (1) $170 million costs associated with the exit of our UGI International energy marketing business in Europe, principally reflecting the loss on the sale of the energy marketing business located in the U.K. and an impairment of assets; (2) external advisory fees of $10 million associated with AmeriGas operations enhancement for growth project; and (3) business transformation expenses of $3 million associated with corporate support functions.

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Adjusted net income attributable to UGI Corporation for the 2024 six-month period was $681 million (equal to $3.16 per diluted share) compared to $609 million (equal to $2.82 per diluted share) for the 2023 six-month period. The increase in adjusted net income attributable to UGI Corporation for the 2024 six-month period reflects higher earnings contributions from the Utilities, Midstream & Marketing and UGI International segments, partially offset by lower earnings contributions from the AmeriGas Propane segment. During the 2024 six-month period, temperatures in all of our segments were warmer than the prior-year period.

Utilities’ adjusted net income attributable to UGI Corporation increased $17 million in the 2024 six-month period. The increase was largely attributable to higher total margin due in large part to increases in base rates for both PA Gas Utility and Mountaineer during Fiscal 2024 and the implementation of the weather normalization adjustments for PA Gas Utility (effective November 2022).

Midstream & Marketing’s adjusted net income attributable to UGI Corporation increased $69 million in the 2024 six-month period. The increase is primarily attributable to higher total margin from natural gas marketing activities and lower income taxes reflecting higher investment tax credits in the 2024 six-month period.

UGI International’s adjusted net income attributable to UGI Corporation increased $37 million in the 2024 six-month period. The increase is mainly attributable to higher margin contributions from our LPG business, principally reflecting the benefit from higher average unit margins attributable to strong margin management efforts and the effects of higher LPG retail volumes sold. The increase also reflects lower operating and administrative expenses resulting from lower personnel and maintenance expenses, partially offset by the effects of inflationary increases.

AmeriGas Propane’s adjusted net income attributable to UGI Corporation decreased $69 million in the 2024 six-month period. The decrease principally reflects lower total margin largely attributable to lower retail propane volumes sold, partially offset by the benefit of higher average retail propane unit margins in the 2024 six-month period. This decrease is also attributable to higher income taxes reflecting valuation allowance on disallowed interest expense following its goodwill impairment charge in the third quarter of Fiscal 2023.

SEGMENT RESULTS OF OPERATIONS

2024 Three-Month Period Compared with the 2023 Three-Month Period
Utilities
For the three months ended March 31,20242023Increase (Decrease)
(Dollars in millions)    
Revenues$646 $774 $(128)(17)%
Total margin (a)$363 $338 $25 7 %
Operating and administrative expenses (a)$97 $97 $— — %
Operating income$225 $203 $22 11 %
Earnings before interest expense and income taxes$226 $205 $21 10 %
Gas Utility system throughput—bcf
Core market45 44 1 2 %
Total121 125 (4)(3)%
Electric Utility distribution sales - gwh266 257 9 4 %
Gas Utility heating degree days—% (warmer) than normal (b)(16.4)%(19.7)%— — 
(a)Total margin represents revenues less cost of sales and revenue-related taxes (i.e., gross receipts and business and occupation taxes) of $9 million and $10 million during the 2024 and 2023 three-month periods, respectively. For financial statement purposes, revenue-related taxes are included in “Operating and administrative expenses” on the Condensed Consolidated Statements of Income (but are excluded from operating and administrative expenses presented above).
(b)Deviation from average heating degree days is determined on a 10-year period utilizing volume-weighted weather data based on weather statistics provided by NOAA for airports located within Gas Utility’s service territories.

Temperatures in Gas Utility’s service territories during the 2024 three-month period were 16.4% warmer than normal and 4.7% colder than the prior-year period. The slight increase in Gas Utility core market volumes during the 2024 three-month period is
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UGI CORPORATION AND SUBSIDIARIES
largely related to growth in the core market customers and colder weather than the prior-year period. Total Gas Utility volume decreased 3% during the 2024 three-month period, notwithstanding the slight increase in core market volumes, primarily reflecting lower interruptible delivery service volumes. The increase in Electric Utility distribution sales volumes is primarily attributable to the weather that was colder than the prior-year period.
Utilities revenues decreased $128 million in the 2024 three-month period substantially due to lower Gas Utility revenues. The decrease in Gas Utility revenues was largely attributable to lower PGC and PGA rates reflecting lower natural gas costs and lower off-system sales. These decreases were partially offset by the effects of increases in base rates for PA Gas Utility (effective October 1, 2023) and Mountaineer (effective January 1, 2024), increase in DSIC revenues and slightly higher core market volumes. Electric Utility revenues were comparable to the prior-year period.

Utilities cost of sales decreased $152 million in the 2024 three-month period primarily attributable to Gas Utility ($148 million) mainly reflecting lower PGC and PGA rates and lower cost of sales associated with off-system sales. Electric Utility cost of sales decreased $4 million during the 2024 three-month period largely reflecting the lower DS rates.

Utilities total margin increased $25 million during the 2024 three-month period primarily attributable to higher Gas Utility total margin ($21 million), mainly reflecting the effects of increases in base rates for PA Gas Utility (effective October 1, 2023) and Mountaineer (effective January 1, 2024), increases in DSIC revenue and the impacts from growth in the core market customers. Electric Utility margin increased by $4 million during the 2024 three-month period mainly reflecting the increase in base rates effective October 1, 2023.

Utilities operating income and earnings before interest expense and income taxes increased $22 million and $21 million, respectively, during the 2024 three-month period. These increases largely reflect the previously mentioned increase in total margin, partially offset by higher depreciation expense ($4 million). Operating and administrative expenses were comparable to the prior-year period, reflecting lower uncollectible accounts expenses and contract labor costs, largely offset by higher employee benefits expense. The higher depreciation expense compared to the prior-year period reflects the effects of continued distribution system capital expenditure activity.

Midstream & Marketing
For the three months ended March 31,20242023Increase (Decrease)
(Dollars in millions)    
Revenues $483 $638 $(155)(24)%
Total margin (a)$200 $159 $41 26 %
Operating and administrative expenses$29 $35 $(6)(17)%
Operating income$151 $103 $48 47 %
Earnings before interest expense and income taxes$153 $105 $48 46 %
(a)Total margin represents revenues less cost of sales.

Average temperatures across Midstream & Marketing’s energy marketing territory during the 2024 three-month period were 13.4% warmer than normal and 3.4% colder than the prior-year period.

Midstream & Marketing revenues decreased $155 million compared to the prior-year period, primarily reflecting lower revenues from natural gas marketing activities ($154 million), including the effects of peaking and capacity management activities, that were primarily impacted by lower natural gas prices.

Midstream & Marketing cost of sales decreased $196 million compared to the prior-year period, primarily reflecting lower natural gas costs ($190 million) related to the previously mentioned natural gas marketing activities and, to a much lesser extent, lower cost of sales related to retail power marketing activities.

Midstream & Marketing total margin increased $41 million compared to the prior-year period, primarily reflecting higher margins from natural gas marketing activities ($46 million), primarily reflecting the effects of higher capacity management and peaking activities, partially offset by lower total margin from renewable energy ($2 million).

Midstream & Marketing operating income and earnings before interest expense and income taxes during the 2024 three-month period each increased $48 million compared to the prior-year period, largely attributable to the higher total margin and lower
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operating and administrative expenses ($6 million). The lower operating and administrative expenses during the 2024 three-month period primarily reflects lower salary and benefits expenses and maintenance expenses.

UGI International
For the three months ended March 31,20242023Increase (Decrease)
(Dollars in millions)    
Revenues$673 $948 $(275)(29)%
Total margin (a)$305 $315 $(10)(3)%
Operating and administrative expenses$155 $171 $(16)(9)%
Operating income $124 $120 $4 3 %
Earnings before interest expense and income taxes$131 $128 $3 2 %
LPG retail gallons sold (millions)221 222 (1)— %
Heating degree days—% (warmer) than normal (b)(13.2)%(7.0)%— — 
(a)Total margin represents revenues less cost of sales.
(b)Deviation from average heating degree days is determined on a rolling 10-year period utilizing volume-weighted weather data at locations in our UGI International service territories.

Average temperatures during the 2024 three-month period were 13.2% warmer than normal and 8.4% warmer than the prior-year period. Notwithstanding the significantly warmer weather, total LPG retail gallons sold during the 2024 three-month period were comparable to the prior-year period as the effects of the warmer weather and lower cylinder volumes were largely offset by growth from natural gas conversions to LPG and higher auto gas volumes sold.

UGI International base-currency results are translated into USD based upon exchange rates experienced during the reporting periods. The functional currency of a significant portion of our UGI International results is the euro and, to a much lesser extent, the British pound sterling. During the 2024 and 2023 three-month periods, the average unweighted euro-to-USD translation rates were approximately $1.09 and $1.07, respectively, and the average unweighted British pound sterling-to-USD translation rates were approximately $1.27 and $1.22, respectively. Fluctuations in these foreign currency exchange rates can have a significant impact on the individual financial statement components discussed below. The Company uses forward foreign currency exchange contracts entered into over multi-year periods to reduce the volatility in earnings that may result from such changes in foreign currency exchange rates. These forward foreign currency exchange contracts resulted in net realized gains of $6 million and $8 million in the 2024 and 2023 three-month periods, respectively.

Average wholesale prices for propane and butane during the 2024 three-month period in northwest Europe were approximately 14% and 15% lower, respectively, compared with the prior-year period. UGI International revenues and cost of sales decreased $275 million and $265 million, respectively, during the 2024 three-month period compared to the prior-year period. The decrease in revenues and cost of sales principally reflects significantly lower energy marketing activities during the 2024 three-month period resulting from the exit of substantially all of UGI International’s energy marketing business in Belgium, France and the Netherlands. The decrease in revenues from the energy marketing business was partially offset by the translation effects of the stronger foreign currencies (approximately $12 million) and LPG price increases across Europe. The decrease in cost of sales was also attributable to lower LPG product costs, partially offset by the translation effects of the stronger foreign currencies (approximately $7 million).

UGI International total margin decreased $10 million during the 2024 three-month period primarily reflecting lower margin contributions from our energy marketing activities resulting from the impact of the aforementioned exit of substantially all of UGI International’s energy marketing business. The decrease in UGI International total margin was partially offset by higher margin contributions from our LPG business, largely reflecting the effects of higher average unit margins attributable to strong margin management efforts and the translation effects of the stronger foreign currencies (approximately $5 million).

UGI International operating income and earnings before interest expense and income taxes increased $4 million and $3 million, respectively, during the 2024 three-month period. The increase in operating income principally reflects lower operating and administrative expenses ($16 million), partially offset by the previously mentioned $10 million decrease in total margin and lower foreign currency transaction gains ($4 million). The lower operating and administrative expenses in the 2024 three-month period primarily reflects lower personnel and maintenance expenses, partially offset by the effects of inflationary increases and the translation effects of the stronger foreign currencies (approximately $3 million). The increase in earnings before interest expense and income taxes in the 2024 three-month period largely reflects the $4 million increase in operating
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income partially offset by lower realized gains on foreign currency exchange contracts entered into in order to reduce volatility in UGI International earnings resulting from the effects of changes in foreign currency exchange rates ($2 million).
AmeriGas Propane
For the three months ended March 31,20242023Increase (Decrease)
(Dollars in millions)    
Revenues$795 $867 $(72)(8)%
Total margin (a)$433 $437 $(4)(1)%
Operating and administrative expenses$258 $263 $(5)(2)%
Operating income/earnings before interest expense and income taxes$138 $138 $— — %
Retail gallons sold (millions)261 279 (18)(6)%
Heating degree days—% (warmer) than normal (b)(8.6)%(4.8)%— — 
(a)Total margin represents total revenues less total cost of sales.
(b)Deviation from average heating degree days is determined on a rolling 10-year period utilizing volume-weighted weather data based on weather statistics provided by NOAA for 344 regions in the U.S., excluding Alaska and Hawaii.

Average temperatures during the 2024 three-month period were 8.6% warmer than normal and 3.0% warmer than the prior-year period. Total retail gallons sold decreased 6% during the 2024 three-month period primarily due to continuing customer attrition and the effects of the warmer weather.

Average daily wholesale propane commodity prices during the 2024 three-month period at Mont Belvieu, Texas, one of the major supply points in the U.S., were approximately 3% higher than such prices during the 2023 three-month period. Total revenues decreased $72 million during the 2024 three-month period largely reflecting the lower retail volumes sold ($49 million), lower wholesale revenues ($16 million) and the effects of lower average retail propane selling prices ($8 million).

Total cost of sales decreased $68 million during the 2024 three-month period largely reflecting the lower retail propane volumes sold ($24 million), the lower retail propane product costs ($27 million) and the lower wholesale cost of sales ($15 million).

Total margin decreased $4 million in the 2024 three-month period largely attributable to the lower retail propane volumes sold ($25 million), partially offset by higher average retail propane unit margins ($19 million).

Operating income and earnings before interest expense and income taxes each were comparable to the 2024 three-month period primarily as lower operating and administrative expenses ($5 million) was largely offset by the previously mentioned decrease in total margin ($4 million). The decrease in operating and administrative expenses reflects, among other things, lower advertising expenses and lower compensation expenses, partially offset by higher vehicle expenses.

Interest Expense and Income Taxes

Our consolidated interest expense during the 2024 three-month period was $100 million compared to $93 million during the 2023 three-month period. This increase largely reflects slightly higher credit agreement interest rates and higher long-term debt outstanding principally at Utilities and Midstream & Marketing, partially offset by lower average debt outstanding at AmeriGas Propane.

The decrease in the Company’s income tax rate for the 2024 three-month period reflects an increase in investment tax credits mainly at our Midstream & Marketing segment.

The Company continues to evaluate the elections available under current regulations and pending legislation. Accordingly, the impacts on the Company’s income tax provisions and taxes payable or refundable related to these items are subject to change.

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UGI CORPORATION AND SUBSIDIARIES
2024 Six-Month Period Compared with the 2023 Six-Month Period

Utilities
For the six months ended March 31,20242023Increase (Decrease)
(Dollars in millions)    
Revenues$1,139 $1,366 $(227)(17)%
Total margin (a)$628 $594 $34 6 %
Operating and administrative expenses (a)$185 $188 $(3)(2)%
Operating income$359 $329 $30 9 %
Earnings before interest expense and income taxes$361 $333 $28 8 %
Gas Utility system throughput—bcf
Core market75 78 (3)(4)%
Total225 219 6 3 %
Electric Utility distribution sales - gwh507 503 4 1 %
Gas Utility heating degree days—% (warmer) than normal (b)(14.2)%(11.6)%— — 
(a)Total margin represents revenues less cost of sales and revenue-related taxes (i.e., gross receipts and business and occupation taxes) of $16 million and $17 million during the 2024 and 2023 six-month periods, respectively. For financial statement purposes, revenue-related taxes are included in “Operating and administrative expenses” on the Condensed Consolidated Statements of Income (but are excluded from operating and administrative expenses presented above).
(b)Deviation from average heating degree days is determined on a 10-year period utilizing volume-weighted weather data based on weather statistics provided by NOAA for airports located within Gas Utility’s service territories.

Temperatures in Gas Utility’s service territories during the 2024 six-month period were 14.2% warmer than normal and 2.6% warmer than the prior-year period. The decrease in Gas Utility core market volumes during the 2024 six-month period is largely related to the warmer weather partially offset by growth in the core market customers. Total Gas Utility volume increased 3% during the 2024 six-month period, notwithstanding the decrease in core market volumes, reflecting higher large firm delivery service volumes and higher interruptible delivery service volumes. The increase in Electric Utility distribution sales volumes is primarily attributable to customer growth during the 2024 six-month period.
Utilities revenues decreased $227 million in the 2024 six-month period substantially due to lower Gas Utility revenues. The decrease in Gas Utility revenues was largely attributable to lower PGC and PGA rates reflecting lower natural gas costs and, to a lesser extent, the lower core market volumes and lower off-system sales. These decreases were partially offset by the effects of increases in base rates for PA Gas Utility (effective October 1, 2023) and Mountaineer (effective January 1, 2024) and the effects of the weather normalization adjustments for PA Gas Utility (effective November 1, 2022). Electric Utility revenues were comparable to the prior-year period as higher base rates and sales volumes were offset by lower DS rates.

Utilities cost of sales decreased $261 million in the 2024 six-month period primarily attributable to Gas Utility ($254 million) mainly reflecting lower PGC and PGA rates, the lower core market volumes and lower cost of sales associated with off-system sales. Electric Utility cost of sales decreased $7 million during the 2024 six-month period largely reflecting the lower DS rates.

Utilities total margin increased $34 million during the 2024 six-month period primarily attributable to higher Gas Utility total margin ($28 million), notwithstanding the warmer weather, mainly reflecting the effects of increases in base rates for PA Gas Utility (effective October 1, 2023) and Mountaineer (effective January 1, 2024) and the effects of the weather normalization adjustments for PA Gas Utility (effective November 1, 2022), increases in DSIC revenues and the impacts from growth in the core market customers. Electric Utility margin increased by $6 million during the 2024 six-month period mainly reflecting the increase in base rates effective October 1, 2023.

Utilities operating income and earnings before interest expense and income taxes increased $30 million and $28 million, respectively, during the 2024 six-month period. These increases largely reflect the previously mentioned increase in total margin and lower operating and administrative expenses ($3 million), partially offset by higher depreciation expense ($8 million). The slightly lower operating and administrative expenses principally reflect lower uncollectible accounts expenses, contract labor costs and maintenance expenses. The higher depreciation expense compared to the prior-year period reflects the effects of continued distribution system capital expenditure activity.

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Midstream & Marketing
For the six months ended March 31,20242023Increase (Decrease)
(Dollars in millions)    
Revenues $877 $1,307 $(430)(33)%
Total margin (a)$355 $314 $41 13 %
Operating and administrative expenses$60 $64 $(4)(6)%
Operating income$250 $209 $41 20 %
Earnings before interest expense and income taxes$255 $212 $43 20 %
(a)Total margin represents revenues less cost of sales.

Average temperatures across Midstream & Marketing’s energy marketing territory during the 2024 six-month period were 11.8% warmer than normal and 2.8% warmer than the prior-year period.

Midstream & Marketing revenues decreased $430 million compared to the prior-year period, primarily reflecting lower revenues from natural gas marketing activities ($426 million), including the effects of peaking and capacity management activities, that were primarily impacted by lower natural gas prices and lower volumes resulting from the warmer weather.

Midstream & Marketing cost of sales decreased $471 million compared to the prior-year period, primarily reflecting lower natural gas costs ($461 million) related to the previously mentioned natural gas marketing activities and, to a much lesser extent, lower cost of sales related to retail power marketing activities.

Midstream & Marketing total margin increased $41 million compared to the prior-year period, primarily reflecting higher margins from natural gas marketing activities ($54 million), mainly resulting from the effects of higher capacity management and peaking activities, partially offset by lower total margin from renewable energy ($7 million).

Midstream & Marketing operating income and earnings before interest expense and income taxes during the 2024 six-month period increased $41 million and $43 million, respectively, compared to the prior-year period. The increase in operating income is largely attributable to the higher total margin and, to a lesser extent, lower operating and administrative expense ($4 million), partially offset by lower other operating income ($4 million). The increase in earnings before interest expense and income taxes principally reflects the increase in operating income and, to a much lesser extent, slightly higher income from equity investees.

UGI International
For the six months ended March 31,20242023Increase (Decrease)
(Dollars in millions)    
Revenues$1,398 $1,825 $(427)(23)%
Total margin (a)$584 $530 $54 10 %
Operating and administrative expenses$302 $314 $(12)(4)%
Operating income $237 $176 $61 35 %
Earnings before interest expense and income taxes$248 $194 $54 28 %
LPG retail gallons sold (millions)435 427 8 2 %
Heating degree days—% (warmer) than normal (b)(12.7)%(9.2)%— — 
(a)Total margin represents revenues less cost of sales.
(b)Deviation from average heating degree days is determined on a rolling 10-year period utilizing volume-weighted weather data at locations in our UGI International service territories.

Average temperatures during the 2024 six-month period were 12.7% warmer than normal and 4.3% warmer than the prior-year period. Notwithstanding the warmer weather, total LPG retail gallons sold during the 2024 six-month period were 2% higher than the prior-year period largely attributable to growth from natural gas conversions to LPG and higher crop drying volumes, partially offset by warmer weather and lower cylinder volumes.

UGI International base-currency results are translated into USD based upon exchange rates experienced during the reporting periods. The functional currency of a significant portion of our UGI International results is the euro and, to a much lesser
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extent, the British pound sterling. During the 2024 and 2023 six-month periods, the average unweighted euro-to-USD translation rates were approximately $1.08 and $1.05, respectively, and the average unweighted British pound sterling-to-USD translation rates were approximately $1.26 and $1.19, respectively. Fluctuations in these foreign currency exchange rates can have a significant impact on the individual financial statement components discussed below. The Company uses forward foreign currency exchange contracts entered into over multi-year periods to reduce the volatility in earnings that may result from such changes in foreign currency exchange rates. These forward foreign currency exchange contracts resulted in net realized gains of $10 million and $16 million in the 2024 and 2023 six-month periods, respectively.

Average wholesale prices for propane and butane during the 2024 six-month period in northwest Europe were approximately 14% and 15% lower, respectively, compared with the prior-year period. UGI International revenues and cost of sales decreased $427 million and $481 million, respectively, during the 2024 six-month period compared to the prior-year period. The decrease in revenues and cost of sales principally reflects significantly lower energy marketing activities during the 2024 six-month period resulting from the exit of substantially all of UGI International’s energy marketing business in Belgium, France and the Netherlands in Fiscal 2024. The decrease in revenues from the energy marketing business was partially offset by the translation effects of the stronger foreign currencies (approximately $50 million), LPG price increases across Europe and the higher LPG retail volumes sold. The decrease in cost of sales was also attributable to lower LPG product costs, partially offset by the translation effects of the stronger foreign currencies (approximately $31 million) and the higher LPG retail volumes sold.

UGI International total margin increased $54 million during the 2024 six-month period primarily reflecting higher margin contributions primarily from our LPG business, the translation effects of the stronger foreign currencies (approximately $20 million) and, to a much lesser extent, slightly higher margin contributions from our energy marketing activities. The higher margin from our LPG business reflects the effects of higher average unit margins attributable to strong margin management efforts and the effects of the higher LPG retail volumes sold. The slightly higher margin from our energy marketing activities primarily reflects the impact of the aforementioned exit of substantially all of UGI International’s energy marketing business.

UGI International operating income and earnings before interest expense and income taxes increased $61 million and $54 million, respectively, during the 2024 six-month period. The increase in operating income principally reflects the previously mentioned $54 million increase in total margin and lower operating and administrative expenses ($12 million), partially offset by lower foreign currency transaction gains ($8 million). The lower operating and administrative expenses in the 2024 six-month period primarily reflects lower personnel and maintenance expenses, partially offset by the effects of inflationary increases and the translation effects of the stronger foreign currencies (approximately $12 million). The increase in earnings before interest expense and income taxes in the 2024 six-month period largely reflects the $61 million increase in operating income, partially offset by lower realized gains on foreign currency exchange contracts entered into in order to reduce volatility in UGI International earnings resulting from the effects of changes in foreign currency exchange rates ($6 million).
AmeriGas Propane
For the six months ended March 31,20242023Increase (Decrease)
(Dollars in millions)    
Revenues$1,424 $1,633 $(209)(13)%
Total margin (a)$779 $817 $(38)(5)%
Operating and administrative expenses$501 $498 $3 1 %
Operating income/earnings before interest expense and income taxes$209 $248 $(39)(16)%
Retail gallons sold (millions)467 515 (48)(9)%
Heating degree days—% (warmer) than normal (b)(7.7)%(0.4)%— — 
(a)Total margin represents total revenues less total cost of sales.
(b)Deviation from average heating degree days is determined on a rolling 10-year period utilizing volume-weighted weather data based on weather statistics provided by NOAA for 344 regions in the U.S., excluding Alaska and Hawaii.

Average temperatures during the 2024 six-month period were 7.7% warmer than normal and 6.8% warmer than the prior-year period. Total retail gallons sold decreased 9% during the 2024 six-month period primarily due to continuing customer attrition and the effects of the significantly warmer weather.

Average daily wholesale propane commodity prices during the 2024 six-month period at Mont Belvieu, Texas, one of the major supply points in the U.S., were approximately 7% lower than such prices during the 2023 six-month period. Total revenues
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UGI CORPORATION AND SUBSIDIARIES
decreased $209 million during the 2024 six-month period largely reflecting the lower retail volumes sold ($130 million), lower wholesale revenues ($45 million) and the effects of lower average retail propane selling prices ($30 million).

Total cost of sales decreased $171 million during the 2024 six-month period largely reflecting the lower retail propane volumes sold ($63 million), the lower retail propane product costs ($54 million) and lower wholesale cost of sales ($44 million).

Total margin decreased $38 million in the 2024 six-month period largely attributable to the lower retail propane volumes sold ($66 million), partially offset by higher average retail propane unit margins ($24 million).

Operating income and earnings before interest expense and income taxes each decreased $39 million during the 2024 six-month period primarily reflecting the decrease in total margin ($38 million) and, to a much lesser extent, slightly higher operating and administrative expenses ($3 million). The increase in operating and administrative expenses reflects, among other things, higher vehicle expenses and salaries and benefits expenses, partially offset by lower advertising expenses.

Interest Expense and Income Taxes

Our consolidated interest expense during the 2024 six-month period was $200 million compared to $185 million during the 2023 six-month period. This increase largely reflects slightly higher credit agreement interest rates and higher long-term debt outstanding principally at Utilities and Midstream & Marketing, partially offset by lower average debt outstanding at AmeriGas Propane.

The decrease in the Company’s income tax rate for the 2024 six-month period reflects an increase in investment tax credits mainly at our Midstream & Marketing segment.

The Company continues to evaluate the elections available under current regulations and pending legislation. Accordingly, the impacts on the Company’s income tax provisions and taxes payable or refundable related to these items are subject to change.


FINANCIAL CONDITION AND LIQUIDITY

The Company expects to have sufficient liquidity including cash on hand and available borrowing capacity, to continue to support long-term commitments and ongoing operations despite uncertainties associated with ongoing global macroeconomic conditions including, among others, changes in consumer behavior, the inflationary cost environment and ongoing energy commodity price volatility. Our total available liquidity balance, comprising cash and cash equivalents and available borrowing capacity on our revolving credit facilities, totaled approximately $1.7 billion and $1.6 billion at March 31, 2024 and September 30, 2023, respectively. The Company does not have any senior notes or term loans maturing in the next twelve months. The Company cannot predict the duration or total magnitude of the uncertain economic factors mentioned above and the total effects they will have on its liquidity, debt covenants, financial condition or the timing of capital expenditures. UGI and its subsidiaries were in compliance with its debt covenants as of March 31, 2024.
We depend on both internal and external sources of liquidity to provide funds for working capital and to fund capital requirements. Our short-term cash requirements not met by cash from operations are generally satisfied with borrowings under credit facilities and, in the case of Midstream & Marketing, also from a Receivables Facility. Long-term cash requirements are generally met through the issuance of long-term debt or equity securities. We believe that each of our business units has sufficient liquidity in the forms of cash and cash equivalents on hand; cash expected to be generated from operations; credit facility and Receivables Facility borrowing capacity; and the ability to obtain long-term financing to meet anticipated contractual and projected cash commitments. Issuances of debt and equity securities in the capital markets and additional credit facilities may not, however, be available to us on acceptable terms.

The primary sources of UGI’s cash and cash equivalents are the dividends and other cash payments made to UGI or its corporate subsidiaries by its principal business units. Our cash and cash equivalents totaled $263 million at March 31, 2024, compared with $241 million at September 30, 2023. Excluding cash and cash equivalents that reside at UGI’s operating subsidiaries, at March 31, 2024 and September 30, 2023, UGI had $49 million and $51 million of cash and cash equivalents, respectively. Such cash is available to pay dividends and interest on long-term debt and for investment purposes.

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UGI CORPORATION AND SUBSIDIARIES
Long-term Debt and Credit Facilities

Long-term Debt

The Company’s debt outstanding at March 31, 2024 and September 30, 2023, comprises the following:
March 31, 2024September 30, 2023
(Millions of dollars)UtilitiesMidstream & MarketingUGI InternationalAmeriGas PropaneCorp & OtherTotalTotal
Short-term borrowings$151 $36 $146 $— $— $333 $649 
Long-term debt (including current maturities):
Senior notes$1,755 $— $432 $2,362 $— $4,549 $4,329 
Term loans126 790 324 — 709 1,949 1,967 
Other long-term debt19 41 8 — 260 328 351 
Unamortized debt issuance costs(7)(14)(7)(12)(2)(42)(47)
Total long-term debt$1,893 $817 $757 $2,350 $967 $6,784 $6,600 
Total debt$2,044 $853 $903 $2,350 $967 $7,117 $7,249 

Credit Facilities

Additional information related to the Company’s credit agreements can be found in Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and Note 6 to Consolidated Financial Statements in the Company’s 2023 Annual Report.

Information about the Company’s principal credit agreements (excluding the Receivables Facility discussed below) as of March 31, 2024 and 2023, is presented in the table below.
(Currency in millions)Total CapacityBorrowings OutstandingLetters of Credit and Guarantees OutstandingAvailable Borrowing Capacity
As of March 31, 2024
AmeriGas OLP$400 $— $2 $398 
UGI International, LLC (a)€500 €135 €— €365 
Energy Services$260 $— $— $260 
UGI Utilities$375 $87 $— $288 
Mountaineer$150 $64 $— $86 
UGI Corporation (b)$300 $260 $— $40 
As of March 31, 2023
AmeriGas OLP$600 $30 $2 $568 
UGI International, LLC (a)€500 €150 €— €350 
Energy Services$260 $— $— $260 
UGI Utilities$425 $183 $— $242 
Mountaineer$150 $59 $— $91 
UGI Corporation (b)$300 $218 $— $82 
(a)Permits UGI International, LLC to borrow in euros or USD. At March 31, 2024 and 2023, the amount borrowed consisted of euro-denominated borrowings equivalent to $146 million and $163 million, respectively.
(b)Borrowings outstanding have been classified as “Long-term debt” on the Condensed Consolidated Balance Sheets.

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UGI CORPORATION AND SUBSIDIARIES
The average daily and peak short-term borrowings under the Company’s principal credit agreements are as follows:
For the six months ended For the six months ended
March 31, 2024March 31, 2023
(Millions of dollars or euros)AveragePeakAveragePeak
AmeriGas OLP$— $25 $153 $242 
UGI International, LLC€179 €229 €188 €300 
Energy Services$30 $62 $13 $82 
UGI Utilities$192 $316 $248 $340 
Mountaineer$88 $104 $85 $101 
UGI Corporation$238 $289 $236 $292 

Receivables Facility. Energy Services has a Receivables Facility with an issuer of receivables-backed commercial paper currently scheduled to expire on October 18, 2024. The Receivables Facility provides Energy Services with the ability to borrow up to $200 million of eligible receivables during the period October 20, 2023 to April 30, 2024, and up to $100 million of eligible receivables during the period May 1, 2024 to October 18, 2024. Energy Services uses the Receivables Facility to fund working capital, margin calls under commodity futures contracts, capital expenditures, dividends and for general corporate purposes.

Under the Receivables Facility, Energy Services transfers, on an ongoing basis and without recourse, its trade accounts receivable to its wholly owned, special purpose subsidiary, ESFC, which is consolidated for financial statement purposes. ESFC, in turn, has sold and, subject to certain conditions, may from time to time sell, an undivided interest in some or all of the receivables to a major bank. Amounts sold to the bank are reflected as “Short-term borrowings” on the Condensed Consolidated Balance Sheets. ESFC was created and has been structured to isolate its assets from creditors of Energy Services and its affiliates, including UGI. Trade receivables sold to the bank remain on the Company’s balance sheet and the Company reflects a liability equal to the amount advanced by the bank. The Company records interest expense on amounts owed to the bank. Energy Services continues to service, administer and collect trade receivables on behalf of the bank, as applicable.

At March 31, 2024, the outstanding balance of ESFC trade receivables was $87 million, $36 million of which were sold to the bank. At March 31, 2023, the outstanding balance of ESFC trade receivables was $115 million, $15 million of which was sold to the bank. During the six months ended March 31, 2024 and 2023, peak sales of receivables were $97 million and $150 million, respectively, and average daily amounts sold were $42 million and $56 million, respectively.

Significant Financing Activities

The following significant financing activities occurred during Fiscal 2024. See Note 8 to Condensed Consolidated Financial Statements for additional information on these transactions.
UGI Corporation Credit Facility Agreement. On April 30, 2024, UGI entered into the fourth amendment to the UGI Corporation Credit Facility Agreement which extended the maturity date of a substantial portion of the (1) $215 million delayed draw term loan facility, (2) $300 million term loan facility, (3) $250 million term loan facility, and (4) $300 million revolving credit facility to August 2025. In addition, the fourth amendment to the UGI Corporation Credit Facility Agreement increased the applicable rate (as defined in the amended UGI Corporation Credit Facility Agreement) of the $215 million delayed draw term loan facility, and the $300 million term loan facility by 0.375%
Mountaineer Credit Agreement. On April 26, 2024, Mountaineer entered into the fourth amendment to the Mountaineer Credit Agreement, which extends the maturity date of the agreement from November 2024 to December 2025. The applicable margin remains unchanged from the original credit agreement.

AmeriGas Partners Senior Notes. In March 2024, AmeriGas Partners and AmeriGas Finance Corp entered into separate, privately negotiated repurchase agreements with a limited number of holders of the outstanding senior notes to repurchase $38 million aggregate principal amount of the senior notes. AmeriGas Partners and AmeriGas Finance Corp repurchased $7 million, $11 million, $13 million, and $7 million par value of its issued and outstanding 5.50% Senior Notes, 5.875% Senior Notes, 5.75% Senior Notes, and 9.375% Senior Notes, respectively. Following these repurchases, $2,362 million aggregate principal amount of these senior notes remain outstanding at March 31, 2024.
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UGI Utilities Senior Notes. On November 30, 2023, UGI Utilities entered into a Note Purchase Agreement with a consortium of lenders. Pursuant to the Note Purchase Agreement, UGI Utilities issued (1) $25 million aggregate principal amount of 6.02% Senior Notes due November 30, 2030; (2) $150 million aggregate principal amount of 6.10% Senior Notes due November 30, 2033; and (3) $75 million aggregate principal amount of 6.40% Senior Notes due November 30, 2053. These senior notes are unsecured and rank equally with UGI Utilities’ existing outstanding senior debt. The net proceeds from these issuances were used to reduce short-term borrowings and for general corporate purposes.
2022 AmeriGas OLP Credit Agreement. Under the 2022 AmeriGas OLP Credit Agreement, AmeriGas OLP, as borrower, is required to comply with financial covenants related to leverage and interest coverage measured at the Partnership and at AmeriGas OLP. The 2022 AmeriGas OLP Credit Agreement contains an equity cure provision, which allows AmeriGas OLP’s direct or indirect parent, including UGI and its other subsidiaries, to fund capital contributions to eliminate any EBITDA (as defined in the 2022 AmeriGas OLP Credit Agreement) shortfalls that would otherwise result in non-compliance with these financial covenants. Each equity cure is eligible to eliminate such EBITDA shortfalls up to four quarters after contribution. We are permitted to use the equity cure provision five times over the course of the Credit Agreement, twice during any rolling four-quarter period, and not in consecutive quarters.

UGI made capital contributions to AmeriGas OLP during Fiscal 2023, a portion of which represented one equity cure that was eligible to eliminate any EBITDA shortfalls through December 31, 2023, in accordance with the 2022 AmeriGas OLP Credit Agreement. As a result of such capital contributions, AmeriGas OLP and the Partnership were in compliance with all financial covenants after consideration of the equity cure provision as of December 31, 2023. As of March 31, 2024, the Partnership was in compliance with all debt covenants as set forth in the 2022 AmeriGas OLP Credit Agreement without the consideration of the equity cure provision. The financial covenant leverage ratio under the 2022 AmeriGas OLP Credit Agreement as of March 31, 2024 must be no greater than 5.75, with a decrease to 5.50 beginning in September 2024. The actual leverage ratio as of March 31, 2024 was 5.74.
UGI provided an irrevocable letter of support whereby UGI has committed to fund any such EBITDA shortfalls and debt service, if any. Based on the support and the projected EBITDA, AmeriGas OLP is expected to remain in compliance with its financial debt covenants for the succeeding twelve-month period.
On November 15, 2023, the Partnership entered into an amendment to the 2022 AmeriGas OLP Credit Agreement, which amends certain provisions of the credit agreement to, among other things, (i) reduce the maximum revolver amount from $600 million to $400 million, (ii) reduce the minimum interest coverage ratio, effective for the fourth quarter of Fiscal 2023 through the end of Fiscal 2024 and (iii) provided that, beginning for the first quarter of Fiscal 2025, the minimum interest coverage ratio will remain reduced if the net leverage ratio is below a certain threshold as defined by the agreement; if the net leverage ratio exceeds such threshold, the minimum interest coverage ratio will revert to the original ratio as defined by the agreement.

UGI Utilities 2023 Credit Agreement. On November 9, 2023, UGI Utilities entered into the UGI Utilities 2023 Credit Agreement providing for borrowings up to $375 million (including a $50 million sublimit for letters of credit and a $38 million sublimit for swingline loans). UGI Utilities may request an increase in the amount of loan commitments under the credit agreement to a maximum aggregate amount of $125 million. The interest rates applicable to borrowings under the UGI Utilities 2023 Credit Agreement remain unchanged from its predecessor agreement, the UGI Utilities Credit Agreement. The credit agreement is scheduled to expire November 2028. Borrowings under the credit agreement may be used to refinance UGI Utilities existing indebtedness and for general corporate purposes and ongoing working capital needs of UGI Utilities.

Dividends

On November 16, 2023, UGI’s Board of Directors declared a quarterly dividend equal to $0.375 per common share. The dividend was paid on January 1, 2024, to shareholders of record on December 15, 2023. On January 31, 2024, UGI’s Board of Directors declared a quarterly dividend of $0.375 per common share. The dividend was paid on April 1, 2024, to shareholders of record on March 15, 2024. On April 29, 2024, UGI’s Board of Directors declared a quarterly dividend of $0.375 per common share. The dividend is payable July 1, 2024, to shareholders of record on June 14, 2024.

Cash Flows

Due to the seasonal nature of the Company’s businesses, cash flows from operating activities are generally strongest during the second and third fiscal quarters when customers pay for natural gas, LPG, electricity and other energy products and services consumed during the peak heating season months. Conversely, operating cash flows are generally at their lowest levels during the fourth and first fiscal quarters when the Company’s investment in working capital, principally inventories and accounts receivable, is generally greatest.
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Operating Activities. Year-to-year variations in our cash flows from operating activities can be significantly affected by changes in operating working capital, especially during periods with significant changes in energy commodity prices. Cash flow provided by operating activities was $641 million in the 2024 six-month period compared to cash provided by operating activities of $424 million in the 2023 six-month period. Cash flow provided by operating activities before changes in operating working capital was $1,055 million in the 2024 six-month period compared to $1,089 million in the 2023 six-month period. Cash used to fund changes in operating working capital totaled $414 million in the 2024 six-month period, a significant decrease compared to the $665 million of cash used to fund changes in operating working capital in the 2023 six-month period. The prior-year period includes $343 million of derivative instrument collateral deposit repayments principally at our UGI International and Midstream & Marketing segments compared to $38 million of such repayments in the 2024 six-month period. The unusually high prior-year collateral deposit repayments were the result of significant declines in commodity energy prices during that period. The decrease in cash flow required to fund changes in operating working capital in the 2023 six-month period also reflects, among other things, significantly lower cash from changes in inventories and to a lesser extent, accounts receivable largely offset by lower cash required to fund changes in accounts payable.

Investing Activities. Investing activity cash flow is principally affected by cash expenditures for property, plant and equipment; cash paid for acquisitions of businesses and assets; investments in equity method investees; and cash proceeds from sales and retirements of property, plant and equipment. Cash flow used by investing activities was $353 million in the 2024 six-month period compared to $473 million in the 2023 six-month period. Cash expenditures for property, plant and equipment were $325 million in the 2024 six-month period compared with $414 million in the 2023 six-month period principally reflecting lower cash capital expenditures at our Utilities segment. Investments in equity method investments during the 2024 six-month period principally reflects our continuing investments in renewable energy projects principally at Midstream & Marketing.

Financing Activities. Changes in cash flow from financing activities are primarily due to issuances and repayments of long-term debt; net short-term borrowings; dividends on UGI Common Stock; quarterly payments on outstanding Purchase Contracts; and issuances and repurchases of equity instruments.

Cash flow used by financing activities was $321 million in the 2024 six-month period compared to cash flow used of $46 million in the 2023 six-month period. The 2024 six-month period includes the issuance by UGI Utilities of $250 million principal amount of senior notes the proceeds of which were used by UGI Utilities to reduce short-term borrowings and for general corporate purposes. The 2023 six-month period includes the cash flow effects from entering into the UGI International 2023 Credit Facilities Agreement and the concurrent repayment of borrowings under the UGI International Credit Facilities Agreement (a predecessor agreement). The 2023 six-month period cash flows from financing activities also includes the cash proceeds from the Energy Services Amended Term Loan Agreement entered into in February 2023 and the concurrent repayment of amounts outstanding under the Energy Services variable rate term loan. Cash flow used by financing activities in the 2024 six-month period also reflects significant repayments of short-term borrowings.

UTILITY REGULATORY MATTERS

UGI Utilities. On January 27, 2023, Electric Utility filed a request with the PAPUC to increase its annual base distribution revenues by $11 million. On September 21, 2023, the PAPUC issued a final order approving a settlement providing for a $9 million annual base distribution rate increase for Electric Utility, effective October 1, 2023.

On January 28, 2022, PA Gas Utility filed a request with the PAPUC to increase its base operating revenues for residential, commercial and industrial customers by $83 million annually. On September 15, 2022, the PAPUC issued a final order approving a settlement providing for a $49 million annual base distribution rate increase for PA Gas Utility, through a phased approach, with $38 million beginning October 29, 2022 and an additional $11 million beginning October 1, 2023. In accordance with the terms of the final order, PA Gas Utility was not permitted to file a rate case prior to January 1, 2024. Also in accordance with the terms of the final order, PA Gas Utility was authorized to implement a weather normalization adjustment rider as a five-year pilot program beginning on November 1, 2022. Under this rider, when weather deviates from normal by more than 3%, for bills rendered during the period of October 1 through May 31, residential and small commercial customer billings for distribution services are adjusted monthly for weather related impacts exceeding the 3% threshold. Additionally, under the terms of the final order, PA Gas Utility was authorized to implement a DSIC once its total property, plant and equipment less accumulated depreciation reached $3,368 million (which threshold was achieved in September 2022).

Mountaineer. On July 31, 2023, Mountaineer submitted its 2023 IREP filing to the WVPSC requesting recovery of $10 million for costs associated with capital investments after December 31, 2022, that total $131 million, including $67 million in calendar
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year 2024. The filing included capital investments totaling $383 million over the 2024 - 2028 period. On December 20, 2023, the WVPSC issued a final order approving a settlement effective January 1, 2024.

On March 6, 2023, Mountaineer submitted a base rate case filing with the WVPSC seeking a net revenue increase of $20 million, which consists of an increase in base rates of $38 million and a decrease in the IREP rates of $18 million annually. On October 6, 2023, Mountaineer filed a joint stipulation and agreement for settlement of the base rate case, which included a $14 million net revenue increase, effective January 1, 2024. On December 21, 2023, the WVPSC issued a final order approving the joint stipulation and agreement, except the WVPSC authorized Mountaineer to implement a weather normalization adjustment rider as a five-year pilot program beginning on October 1, 2024. On April 11, 2024 the WVPSC approved the calculation methodology submitted by Mountaineer on March 28, 2024. Under this rider, when weather deviates from normal by more than 2%, for service rendered during the period of October 1 through May 31, residential and small commercial customer billings for distribution services are adjusted for weather related impacts exceeding the 2% threshold.

On July 29, 2022, Mountaineer submitted its 2022 IREP filing to the WVPSC requesting recovery of costs associated with capital investments totaling $354 million over the 2023 - 2027 period, including $64 million in calendar year 2023. On December 21, 2022, the WVPSC issued a final order approving a settlement for $22 million in cumulative revenue, effective January 1, 2023.

OTHER MATTERS
West Reading, Pennsylvania Explosion. On March 24, 2023, an explosion occurred in West Reading, Pennsylvania which resulted in seven fatalities, significant injuries to eleven others, and extensive property damage to buildings owned by R.M. Palmer, a local chocolate manufacturer, and other neighboring structures. The NTSB and the PAPUC are investigating the West Reading incident. On July 18, 2023, the NTSB issued an Investigative Update in its ongoing investigation and on February 22, 2024 it released its investigation docket including factual reports and detailed incident documentation. The NTSB report identified a fracture in a retired UGI Utilities gas service tee and a fracture in a nearby steam system, but it does not address causation of the fractures or the explosion. The NTSB investigative team includes representatives from the Company, the PAPUC, the local fire department and the Pipeline and Hazardous Materials Safety Administration. The Company is cooperating with the investigation. The NTSB may invite other parties to participate. In September 2023, OSHA closed their investigation of this matter, without any finding pertaining to UGI Utilities.
While the investigation into this incident is still underway and the cause of the explosion has not been determined, the Company has received claims as a result of the explosion and is involved in lawsuits relative to the incident. 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, 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 these matters will or will not have a material effect on our financial statements.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our primary market risk exposures are (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 price risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes.

Commodity Price Risk
The risk associated with fluctuations in the prices the Partnership and our UGI International operations pay for LPG is principally a result of market forces reflecting changes in supply and demand for LPG and other energy commodities. Their profitability is sensitive to changes in LPG supply costs. Increases in supply costs are generally passed on to customers. The Partnership and UGI International may not, however, always be able to pass through product cost increases fully or on a timely basis, particularly when product costs rise rapidly. In order to reduce the volatility of LPG market price risk, the Partnership uses contracts for the forward purchase or sale of propane, propane fixed-price supply agreements and over-the-counter derivative commodity instruments including price swap and option contracts. Our UGI International operations use over-the-counter derivative commodity instruments and may from time to time enter into other derivative contracts, similar to those used by the Partnership, to reduce market risk associated with a portion of their LPG purchases. Over-the-counter derivative commodity instruments used to economically hedge forecasted purchases of LPG are generally settled at expiration of the contract.

Utilities’ tariffs contain clauses that permit recovery of all prudently incurred costs of natural gas it sells to its retail core-market customers, including the cost of financial instruments used to hedge purchased gas costs. The recovery clauses provide for periodic adjustments for the difference between the total amounts actually billed to customers through PGC and PGA rates and the recoverable costs incurred. Because of this ratemaking mechanism, there is limited commodity price risk associated with our Utilities operations. PA Gas Utility uses derivative financial instruments, including natural gas futures and option contracts traded on the NYMEX, to reduce volatility in the cost of gas it purchases for its retail core-market customers. The cost of these derivative financial instruments, net of any associated gains or losses, is included in PA Gas Utility's PGC recovery mechanism.

In order to manage market price risk relating to substantially all of Midstream & Marketing’s fixed-price sale contracts for physical natural gas and electricity, Midstream & Marketing enters into NYMEX, ICE and over-the-counter natural gas and electricity futures and option contracts, and natural gas basis swap contracts or enters into fixed-price supply arrangements. Midstream & Marketing also uses NYMEX and over-the-counter electricity futures contracts to economically hedge a portion of its anticipated sales of electricity from its electricity generation facilities. Although Midstream & Marketing’s fixed-price supply arrangements mitigate most risks associated with its fixed-price sales contracts, should any of the suppliers under these arrangements fail to perform, increases, if any, in the cost of replacement natural gas or electricity would adversely impact Midstream & Marketing’s results. In order to reduce this risk of supplier nonperformance, Midstream & Marketing has diversified its purchases across a number of suppliers. UGI International’s natural gas and electricity marketing businesses also use natural gas and electricity futures and forward contracts to economically hedge market risk associated with a substantial portion of anticipated volumes under fixed-price sales and purchase contracts. See Note 5 to Condensed Consolidated Financial Statements for information on the exit of substantially all of the Company’s European energy marketing business.

Midstream & Marketing has entered into fixed-price sales agreements for a portion of the electricity expected to be generated by its electric generation assets. In the event that these generation assets would not be able to produce all of the electricity needed to supply electricity under these agreements, Midstream & Marketing would be required to purchase electricity on the spot market or under contract with other electricity suppliers. Accordingly, increases in the cost of replacement power could negatively impact Midstream & Marketing’s results.

Interest Rate Risk
We have both fixed-rate and variable-rate debt. Changes in interest rates impact the cash flows of variable-rate debt but generally do not impact their fair value. Conversely, changes in interest rates impact the fair value of fixed-rate debt but do not impact their cash flows.

Our variable-rate debt at March 31, 2024, includes revolving credit facility borrowings and variable-rate term loans at UGI International, Utilities, Energy Services and UGI Corporation. These debt agreements have interest rates that are generally indexed to short-term market interest rates. We have entered into pay-fixed, receive-variable interest rate swap agreements on a significant portion of the term loans’ principal balances and a significant portion of the term loans’ tenor. We have designated these interest rate swaps as cash flow hedges. At March 31, 2024, combined borrowings outstanding under variable-rate debt agreements, excluding the previously mentioned effectively fixed-rate debt, totaled $915 million.
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Long-term debt associated with our domestic businesses is typically issued at fixed rates of interest based upon market rates for debt with similar terms and credit ratings. As these long-term debt issues mature, we may refinance such debt with new debt having interest rates reflecting then-current market conditions. In order to reduce interest rate risk associated with near- to medium-term forecasted issuances of fixed rate debt, from time to time we enter into IRPAs.
Foreign Currency Exchange Rate Risk
Our primary currency exchange rate risk is associated with the USD versus the euro and, to a lesser extent, the USD versus the British pound sterling. The USD value of our foreign currency denominated assets and liabilities will fluctuate with changes in the associated foreign currency exchange rates. From time to time, we use derivative instruments to hedge portions of our net investments in foreign subsidiaries, including anticipated foreign currency denominated dividends. Gains or losses on these net investment hedges remain in AOCI until such foreign operations are sold or liquidated. With respect to our net investments in our UGI International operations, a 10% decline in the value of the associated foreign currencies versus the USD would reduce their aggregate net book value at March 31, 2024, by approximately $75 million, which amount would be reflected in other comprehensive income. We have designated certain euro-denominated borrowings as net investment hedges.
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 between the euro and British pound sterling, we enter into forward foreign currency exchange contracts. We layer in these foreign currency exchange contracts over a multi-year period to eventually equal approximately 90% of anticipated UGI International foreign currency earnings before income taxes.
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. As of March 31, 2024, 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 $173 million. 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 March 31, 2024, we had received cash collateral from derivative instrument counterparties totaling $6 million. In addition, we may have offsetting derivative liabilities and certain accounts payable balances with certain of these counterparties, which further mitigates the previously mentioned maximum amount of losses. Certain of the Partnership’s derivative contracts have credit-risk-related contingent features that may require the posting of additional collateral in the event of a downgrade of the Partnership’s debt rating. At March 31, 2024, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material.
The following table summarizes the fair values of unsettled market risk sensitive derivative instrument assets (liabilities) held at March 31, 2024 and changes in their fair values due to market risks. Certain of UGI Utilities’ commodity derivative instruments are excluded from the table below because any associated net gains or losses are refundable to or recoverable from customers in accordance with UGI Utilities ratemaking.
Asset (Liability)
(Millions of dollars)Fair ValueChange in
Fair Value
March 31, 2024  
Commodity price risk (1)$(70)$(98)
Interest rate risk (2)$8 $(13)
Foreign currency exchange rate risk (3)$15 $(27)
(1) Change in fair value represents a 10% adverse change in the market prices of certain commodities.
(2) Change in fair value represents a 50 basis point adverse change in prevailing market interest rates.
(3) Change in fair value represents a 10% adverse change in the value of the Euro and the British pound sterling versus the USD.
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ITEM 4. CONTROLS AND PROCEDURES

(a)Evaluation of Disclosure Controls and Procedures
The Company's disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by the Company in reports filed or submitted under the Securities Exchange Act of 1934, as amended, is (i) recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms, and (ii) accumulated and communicated to our management, including the Interim Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure. The Company's management, with the participation of the Company’s Interim Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of the Company's disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, the Interim Chief Executive Officer and Chief Financial Officer concluded that the Company's disclosure controls and procedures, as of the end of the period covered by this report, were effective at the reasonable assurance level.

(b)Change in Internal Control over Financial Reporting
No change in the Company’s internal control over financial reporting occurred during the Company’s most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

 
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PART II OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The information set forth in Note 9, Commitments and Contingencies to our Condensed Consolidated Financial Statements included in Item 1 of Part I of this report, is incorporated herein by reference.

ITEM 1A. RISK FACTORS

In addition to the information presented in this report, you should carefully consider the factors discussed in Part I, “Item 1A. Risk Factors” in our 2023 Annual Report, which could materially affect our business, financial condition or future results. The risks described in our 2023 Annual Report are not the only risks facing the Company. Other unknown or unpredictable factors could also have material adverse effects on future results.


ITEM 6. EXHIBITS
The exhibits filed as part of this report are as follows (exhibits incorporated by reference are set forth with the name of the registrant, the type of report and last date of the period for which it was filed, and the exhibit number in such filing):
Incorporation by Reference
Exhibit
No.		ExhibitRegistrantFilingExhibit
10.1UGIForm 8-K/A (12/12/23)10.1
10.2UGIForm 8-K/A (12/12/23)10.2
31.1
31.2
32
101.INSInline XBRL Instance - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCHInline XBRL Taxonomy Extension Schema
101.CALInline XBRL Taxonomy Extension Calculation Linkbase
101.DEFInline XBRL Taxonomy Extension Definition Linkbase
101.LABInline XBRL Taxonomy Extension Label Linkbase
101.PREInline XBRL Taxonomy Extension Presentation Linkbase
104Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

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EXHIBIT INDEX
 
31.1
31.2
32
101.INSInline XBRL Instance - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCHInline XBRL Taxonomy Extension Schema
101.CALInline XBRL Taxonomy Extension Calculation Linkbase
101.DEFInline XBRL Taxonomy Extension Definition Linkbase
101.LABInline XBRL Taxonomy Extension Label Linkbase
101.PREInline XBRL Taxonomy Extension Presentation Linkbase
104Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)


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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 
 UGI Corporation
 (Registrant)
Date:May 2, 2024By:/s/ Sean P. O’Brien
 Sean P. O’Brien
 Chief Financial Officer
Date:May 2, 2024By:/s/ Jean Felix Tematio Dontsop
Jean Felix Tematio Dontsop
Vice President, Chief Accounting Officer
and Corporate Controller
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