UGI (UGI) 10-Q 2 May 24 2024 Q2 Quarterly report Financial data

Cover

Cover - shares	6 Months Ended
	Mar. 31, 2024	Apr. 30, 2024
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2024
Document Transition Report	false
Entity File Number	1-11071
Entity Registrant Name	UGI CORPORATION
Entity Incorporation, State or Country Code	PA
Entity Tax Identification Number	23-2668356
Entity Address, Address Line One	500 North Gulph Road
Entity Address, City or Town	King of Prussia
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	19406
City Area Code	610
Local Phone Number	337-1000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		209,622,441
Entity Central Index Key	0000884614
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--09-30
Common Stock, without par value
Document Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	UGI
Security Exchange Name	NYSE
Corporate Units
Document Information [Line Items]
Title of 12(b) Security	Corporate Units
Trading Symbol	UGIC
Security Exchange Name	NYSE

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) - USD ($) $ in Millions	Mar. 31, 2024	Sep. 30, 2023	Mar. 31, 2023
Current assets:
Cash and cash equivalents	$ 263	$ 241	$ 321
Restricted cash	45	99	82
Accounts receivable (less allowances for doubtful accounts of $83, $71 and $80, respectively)	1,192	878	1,487
Accrued utility revenues	98	33	94
Inventories	375	433	433
Derivative instruments	38	75	110
Prepaid expenses and other current assets	203	286	233
Total current assets	2,214	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
Goodwill	3,048	3,027	3,709
Intangible assets, net	415	443	472
Utility regulatory assets	301	302	314
Derivative instruments	18	49	67
Other assets	1,020	988	852
Total assets	15,624	15,401	16,429
Current liabilities:
Current maturities of long-term debt	54	57	62
Short-term borrowings	333	649	453
Accounts payable	579	613	757
Derivative instruments	33	60	117
Other current liabilities	824	895	884
Total current liabilities	1,823	2,274	2,273
Long-term debt	6,730	6,543	6,702
Deferred income taxes	1,030	928	958
Derivative instruments	26	27	48
Other noncurrent liabilities	1,184	1,235	1,234
Total liabilities	10,793	11,007	11,215
Commitments and contingencies (Note 9)
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 earnings	3,460	3,027	3,842
Accumulated other comprehensive loss	(254)	(256)	(241)
Treasury stock, at cost	(56)	(55)	(55)
Total UGI Corporation stockholders’ equity	4,822	4,386	5,205
Noncontrolling interests	9	8	9
Total equity	4,831	4,394	5,214
Total liabilities and equity	$ 15,624	$ 15,401	$ 16,429

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2024	Sep. 30, 2023	Mar. 31, 2023
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 83	$ 71	$ 80
Accumulated depreciation	$ 4,781	$ 4,581	$ 4,427
Preferred Stock, shares authorized (in shares)	5,000,000	5,000,000	5,000,000
Preferred Stock, shares issued (in shares)	220,000	220,000	220,000
Common Stock, shares authorized (in shares)	450,000,000	450,000,000	450,000,000
Common Stock, shares issued (in shares)	211,052,608	210,906,052	210,730,077

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (unaudited) - USD ($) shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023
Income Statement [Abstract]
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 expenses	591	587	1,121	1,116
Depreciation and amortization	138	132	275	263
Loss on disposal of UGI International energy marketing business	0	0	28	215
Other operating income, net	(9)	(16)	(17)	(34)
Costs and expenses	1,750	2,851	3,639	6,814
Operating income (loss)	717	255	949	(949)
Income from equity investees	1	0	2	1
Other non-operating income (expense), net	11	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 (in USD per share)	$ 2.36	$ 0.52	$ 2.81	$ (4.02)
Diluted (in USD per share)	$ 2.30	$ 0.51	$ 2.74	$ (4.02)
Weighted-average common shares outstanding (thousands):
Basic (in shares)	209,826	209,857	209,789	209,902
Diluted (in shares)	215,245	216,120	215,393	209,902

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023
Statement of Comprehensive Income [Abstract]
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)	0	(1)	0
Other comprehensive (loss) income	(22)	(10)	2	139
Comprehensive income (loss) attributable to UGI Corporation	$ 474	$ 100	$ 592	$ (705)

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023
Statement of Comprehensive Income [Abstract]
Net gains (losses) on derivative instruments, tax	$ (5)	$ 6	$ 2	$ 5
Reclassifications of net gain on derivative instruments, tax	5	2	8	4
Foreign currency adjustments, tax	(7)	(1)	5	29
Benefit plans, net of tax	$ 0	$ 0	$ 0	$ 0

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) - USD ($) $ in Millions	6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
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 amortization	275	263
Deferred income tax expense (benefit), net	95	(346)
Provision for uncollectible accounts	35	36
Changes in unrealized gains and losses on derivative instruments	54	1,713
Loss on disposal of UGI International energy marketing business	28	215
Settlement of Energy Services interest rate swap	0	32
Amortization of Energy Services interest rate swap settlement	(11)	0
Other, net	(11)	20
Net change in:
Accounts receivable and accrued utility revenues	(404)	(450)
Income taxes receivable	0	91
Inventories	63	254
Utility deferred fuel and power costs, net of changes in unsettled derivatives	3	40
Accounts payable	(20)	(148)
Derivative instruments collateral deposits paid	(38)	(453)
Other current assets	19	21
Other current liabilities	(37)	(20)
Net cash provided by operating activities	641	424
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(325)	(414)
Acquisitions of businesses and assets, net of cash acquired	0	(9)
Investments in equity method investees	(47)	(63)
Settlements of net investment hedges	0	22
Other, net	19	(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	0	9
Repurchases of UGI Common Stock	0	(22)
Net cash used by financing activities	(321)	(46)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	1	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 period	340	469
Cash, cash equivalents and restricted cash decrease	$ (32)	$ (66)

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (unaudited) - USD ($) $ in Millions	Total	Total UGI stockholders’ equity	Preferred stock, without par value	Preferred stock, without par value Cumulative effect of change in accounting	Common stock, without par value	Common stock, without par value Cumulative effect of change in accounting	Retained earnings	Retained earnings Cumulative effect of change in accounting	Accumulated other comprehensive income (loss)	Treasury stock	Noncontrolling interests
Balance, beginning of period at Sep. 30, 2022			$ 162	$ 5	$ 1,483	$ (6)	$ 4,841	$ 1	$ (380)	$ (40)	$ 8
Increase (Decrease) in Stockholders' Equity
Common Stock issued in connection with employee and director plans, net of tax withheld					6
Equity-based compensation expense					9
Losses on common stock transactions in connection with employee and director plans							(5)
Net income (loss) attributable to UGI Corporation	$ (844)						(844)
Cash dividends on UGI Common Stock ($0.375, $0.36, $0.75 and $0.72, respectively)							(151)
Net gains (losses) on derivative instruments	(12)								(12)
Reclassification of net gains on derivative instruments	(10)								(10)
Benefit plans	0
Foreign currency adjustments	161								161
Common Stock issued in connection with employee and director plans, net of tax withheld										7
Repurchases of UGI Common Stock										(22)
Other											1
Balance, end of period at Mar. 31, 2023	5,214	$ 5,205	167		1,492		3,842		(241)	(55)	9
Balance, beginning of period at Dec. 31, 2022			167		1,482		3,808		(231)	(46)	8
Increase (Decrease) in Stockholders' Equity
Common Stock issued in connection with employee and director plans, net of tax withheld					4
Equity-based compensation expense					6
Losses on common stock transactions in connection with employee and director plans							(1)
Net income (loss) attributable to UGI Corporation	110						110
Cash dividends on UGI Common Stock ($0.375, $0.36, $0.75 and $0.72, respectively)							(75)
Net gains (losses) on derivative instruments	(15)								(15)
Reclassification of net gains on derivative instruments	(5)								(5)
Benefit plans	0
Foreign currency adjustments	10								10
Common Stock issued in connection with employee and director plans, net of tax withheld										1
Repurchases of UGI Common Stock										(10)
Other											1
Balance, end of period at Mar. 31, 2023	5,214	5,205	167		1,492		3,842		(241)	(55)	9
Balance, beginning of period at Sep. 30, 2023	4,394		167		1,503		3,027		(256)	(55)	8
Increase (Decrease) in Stockholders' Equity
Equity-based compensation expense					2
Net income (loss) attributable to UGI Corporation	590						590
Cash dividends on UGI Common Stock ($0.375, $0.36, $0.75 and $0.72, respectively)							(157)
Net gains (losses) on derivative instruments	(3)								(3)
Reclassification of net gains on derivative instruments	(19)								(19)
Benefit plans	(1)								(1)
Foreign currency adjustments	25								25
Reacquired UGI Common Stock - employee and director plans										(1)
Other											1
Balance, end of period at Mar. 31, 2024	4,831	4,822	167		1,505		3,460		(254)	(56)	9
Balance, beginning of period at Dec. 31, 2023			167		1,501		3,042		(232)	(55)	9
Increase (Decrease) in Stockholders' Equity
Equity-based compensation expense					4
Net income (loss) attributable to UGI Corporation	496						496
Cash dividends on UGI Common Stock ($0.375, $0.36, $0.75 and $0.72, respectively)							(78)
Net gains (losses) on derivative instruments	12								12
Reclassification of net gains on derivative instruments	(9)								(9)
Benefit plans	(1)								(1)
Foreign currency adjustments	(24)								(24)
Reacquired UGI Common Stock - employee and director plans										(1)
Balance, end of period at Mar. 31, 2024	$ 4,831	$ 4,822	$ 167		$ 1,505		$ 3,460		$ (254)	$ (56)	$ 9

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (unaudited) (Parenthetical) - $ / shares	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023
Statement of Stockholders' Equity [Abstract]
Cash dividends on common stock (in USD per share)	$ 0.375	$ 0.36	$ 0.75	$ 0.72

Nature of Operations

Nature of Operations	6 Months Ended
	Mar. 31, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations	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.

Summary of Significant Accounti

Summary of Significant Accounting Policies	6 Months Ended
	Mar. 31, 2024
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	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, March 31, Cash and cash equivalents $ 263 $ 321 Restricted cash 45 82 Cash, cash equivalents and restricted cash $ 308 $ 403 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 Six Months Ended 2024 2023 2024 2023 Denominator (thousands of shares): Weighted-average common shares outstanding — basic 209,826 209,857 209,789 209,902 Incremental shares issuable for stock options, common stock awards and Equity Units (a) 5,419 6,263 5,604 — Weighted-average common shares outstanding — diluted 215,245 216,120 215,393 209,902 (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. 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.

Accounting Changes

Accounting Changes	6 Months Ended
	Mar. 31, 2024
Accounting Changes and Error Corrections [Abstract]
Accounting Changes	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.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	6 Months Ended
	Mar. 31, 2024
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	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. Revenue Disaggregation The following tables present our disaggregated revenues by reportable segment: Three Months Ended March 31, 2024 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Propane Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 353 $ — $ 353 $ — $ — $ — $ — Commercial & Industrial 144 — 144 — — — — Large delivery service 54 — 54 — — — — Off-system sales and capacity releases 32 (24) 56 — — — — Other 11 — 11 — — — — Total Utility 594 (24) 618 — — — — Non-Utility: LPG: Retail 1,267 — — — 570 697 — Wholesale 89 — — — 60 29 — Energy Marketing 311 (38) — 332 17 — — Midstream: Pipeline 65 — — 65 — — — Peaking 8 (69) — 77 — — — Other 4 — — 4 — — — Electricity Generation 6 — — 6 — — — Other 67 — — — 16 51 — Total Non-Utility 1,817 (107) — 484 663 777 — Total revenues from contracts with customers 2,411 (131) 618 484 663 777 — Other revenues (c) 56 — 28 (1) 10 18 1 Total revenues $ 2,467 $ (131) $ 646 $ 483 $ 673 $ 795 $ 1 Three Months Ended March 31, 2023 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Propane Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 424 $ — $ 424 $ — $ — $ — $ — Commercial & Industrial 177 — 177 — — — — Large delivery service 53 — 53 — — — — Off-system sales and capacity releases 45 (28) 73 — — — — Other 16 (1) 17 — — — — Total Utility 715 (29) 744 — — — — Non-Utility: LPG: Retail 1,328 — — — 573 755 — Wholesale 109 — — — 64 45 — Energy Marketing 740 (39) — 498 281 — — Midstream: Pipeline 66 — — 66 — — — Peaking 10 (58) — 68 — — — Other 4 — — 4 — — — Electricity Generation 2 — — 2 — — — Other 67 — — — 20 47 — Total Non-Utility 2,326 (97) — 638 938 847 — Total revenues from contracts with customers 3,041 (126) 744 638 938 847 — Other revenues (c) 65 (2) 30 — 10 20 7 Total revenues $ 3,106 $ (128) $ 774 $ 638 $ 948 $ 867 $ 7 Six Months Ended March 31, 2024 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Propane Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 635 $ — $ 635 $ — $ — $ — $ — Commercial & Industrial 252 — 252 — — — — Large delivery service 103 — 103 — — — — Off-system sales and capacity releases 53 (36) 89 — — — — Other 20 — 20 — — — — Total Utility 1,063 (36) 1,099 — — — — Non-Utility: LPG: Retail 2,324 — — — 1,094 1,230 — Wholesale 160 — — — 109 51 — Energy Marketing (b) 638 (64) — 604 140 — (42) Midstream: Pipeline 130 — — 130 — — — Peaking 11 (111) — 122 — — — Other 7 — — 7 — — — Electricity Generation 14 — — 14 — — — Other 138 — — — 35 103 — Total Non-Utility 3,422 (175) — 877 1,378 1,384 (42) Total revenues from contracts with customers 4,485 (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) Six Months Ended March 31, 2023 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Propane Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 760 $ — $ 760 $ — $ — $ — $ — Commercial & Industrial 309 — 309 — — — — Large delivery service 100 — 100 — — — — Off-system sales and capacity releases 77 (61) 138 — — — — Other 26 (1) 27 — — — — Total Utility 1,272 (62) 1,334 — — — — Non-Utility: LPG: Retail 2,444 — — — 1,055 1,389 — Wholesale 211 — — — 115 96 — Energy Marketing 1,518 (116) — 1,035 599 — — Midstream: Pipeline 131 — — 131 — — — Peaking 27 (97) — 124 — — — Other 7 — — 7 — — — Electricity Generation 10 — — 10 — — — Other 142 — — — 38 104 — Total Non-Utility 4,490 (213) — 1,307 1,807 1,589 — Total revenues from contracts with customers 5,762 (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 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.

Dispositions

Dispositions	6 Months Ended
	Mar. 31, 2024
Discontinued Operations and Disposal Groups [Abstract]
Dispositions	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 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. 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.

Inventories

Inventories	6 Months Ended
	Mar. 31, 2024
Inventory Disclosure [Abstract]
Inventories	Note 6 — Inventories Inventories comprise the following: March 31, September 30, March 31, Non-utility LPG and natural gas $ 196 $ 212 $ 230 Gas Utility natural gas 8 55 20 Energy certificates 63 64 76 Materials, supplies and other 108 102 107 Total inventories $ 375 $ 433 $ 433

Utility Regulatory Assets and L

Utility Regulatory Assets and Liabilities and Regulatory Matters	6 Months Ended
	Mar. 31, 2024
Regulated Operations [Abstract]
Utility Regulatory Assets and Liabilities and Regulatory Matters	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, September 30, March 31, Regulatory assets (a): Income taxes recoverable $ 93 $ 94 $ 94 Underfunded pension plans 109 111 118 Environmental costs 32 28 34 Deferred fuel and power costs — 27 38 Removal costs, net 23 23 22 Other 55 64 53 Total regulatory assets $ 312 $ 347 $ 359 Regulatory liabilities (a): Postretirement benefit overcollections $ 11 $ 12 $ 10 Deferred fuel and power refunds 34 55 28 State tax benefits — distribution system repairs 44 43 39 Excess federal deferred income taxes 250 254 262 Other 8 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 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.

Debt

Debt	6 Months Ended
	Mar. 31, 2024
Debt Disclosure [Abstract]
Debt	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 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 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.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Mar. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	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 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.

Defined Benefit Pension and Oth

Defined Benefit Pension and Other Postretirement Plans	6 Months Ended
	Mar. 31, 2024
Retirement Benefits [Abstract]
Defined Benefit Pension and Other Postretirement Plans	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. Net periodic pension benefit cost (income) includes the following components: Pension Benefits Three Months Ended March 31, 2024 2023 Service cost $ 2 $ 3 Interest cost 9 8 Expected return on assets (11) (12) Amortization of: Actuarial loss 1 — Net benefit cost (income) $ 1 $ (1) Six Months Ended March 31, 2024 2023 Service cost $ 4 $ 5 Interest cost 18 17 Expected return on plan assets (22) (23) Amortization of: Actuarial loss (gain) 1 (1) Net benefit cost (income) $ 1 $ (2)

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Mar. 31, 2024
Fair Value Disclosures [Abstract]
Fair Value Measurements	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 1 Level 2 Level 3 Total 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 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, 2024 September 30, 2023 March 31, 2023 Carrying amount $ 6,826 $ 6,647 $ 6,805 Estimated fair value $ 6,647 $ 6,238 $ 6,480

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	6 Months Ended
	Mar. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	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. 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. 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 Type Units Settlements Extending Through March 31, 2024 September 30, 2023 March 31, 2023 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms February 2025 13 38 12 Non-utility Operations LPG swaps Gallons September 2026 425 727 691 Natural gas futures, forward, basis swap, options and pipeline contracts (a) Dekatherms March 2028 339 338 366 Electricity forward and futures contracts Kilowatt hours December 2027 544 1,260 1,890 Interest Rate Risk: Interest rate swaps Euro March 2026 € 300 € 300 € 300 Interest rate swaps USD September 2026 $ 1,263 $ 1,270 $ 1,277 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD September 2026 $ 240 $ 425 $ 285 Net investment hedge forward foreign exchange contracts Euro December 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 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. 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, September 30, March 31, Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 11 $ 14 $ 9 Interest rate contracts 11 28 25 22 42 34 Derivatives subject to PGC and DS mechanisms: Commodity contracts 8 6 19 Derivatives not designated as hedging instruments: Commodity contracts (a) 138 226 355 Foreign currency contracts 5 24 14 143 250 369 Total derivative assets — gross 173 298 422 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 sheet 111 124 190 Cash collateral pledged 56 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. 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) Gain Location of Gain Reclassified from Cash Flow Hedges: 2024 2023 2024 2023 Interest rate contracts $ 17 $ (21) $ 14 $ 7 Interest expense Net Investment Hedges: Foreign currency contracts $ 8 $ (1) Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2024 2023 Location of Gain (Loss) Recognized in Income Commodity contracts $ (1) $ 6 Revenues Commodity contracts 26 (343) Cost of sales Commodity contracts (1) 2 Other operating income, net Foreign currency contracts 8 (2) Other non-operating income (expense), net Total $ 32 $ (337) Six Months Ended March 31,: Loss Gain Reclassified from AOCI into Income Location of Gain Reclassified from AOCI into Income Cash Flow Hedges: 2024 2023 2024 2023 Interest rate contracts $ (5) $ (17) $ 27 $ 14 Interest expense Net Investment Hedges: Foreign currency contracts $ (2) $ (24) Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2024 2023 Location of Gain (Loss) Recognized in Income Commodity contracts $ 1 $ 10 Revenues Commodity contracts (129) (1,669) Cost of sales Commodity contracts 2 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.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	6 Months Ended
	Mar. 31, 2024
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	Note 13 — Accumulated Other Comprehensive Income (Loss) The tables below present changes in AOCI, net of tax: Three Months Ended March 31, 2024 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total 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, 2023 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total 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, 2024 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total 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, 2023 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total 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)

Equity Method Investments

Equity Method Investments	6 Months Ended
	Mar. 31, 2024
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	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 Value Ownership Interest Investees March 31, 2024 September 30, March 31, March 31, September 30, March 31, Midstream & Marketing: Aurum Renewables $ 46 $ 45 $ 19 40% 40% 40% Pine Run 81 77 72 49% 49% 49% MBL Bioenergy 157 122 78 99.99% 99.99% 99.99% Other 21 20 20 various various various Total Midstream & Marketing 305 264 189 UGI International 35 35 30 various various various Total investments in equity method investees $ 340 $ 299 $ 219

Segment Information

Segment Information	6 Months Ended
	Mar. 31, 2024
Segment Reporting [Abstract]
Segment Information	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. Three Months Ended March 31, 2024 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Corporate 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 investees 1 — — 2 (1) — — Other non-operating income, net 11 — 1 — 8 — 2 Earnings before interest expense and income taxes 729 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, 2023 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Corporate 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), net 2 — 2 — 10 — (10) Earnings (loss) before interest expense and income taxes 257 (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, 2024 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Corporate 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 investees 2 — — 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 Six Months Ended March 31, 2023 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Corporate 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: Three Months Ended March 31, 2024 Location on Income Statement Midstream & Marketing UGI International AmeriGas Propane Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 41 $ 53 $ 34 Net gains on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ 1 $ — Restructuring costs Operating and administrative expenses $ — $ (34) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ — $ — $ (6) Unrealized gains on foreign currency derivative instruments Other non-operating income (expense), net $ — $ 1 $ — Costs associated with exit of the UGI International energy marketing business Operating and administrative expenses/Other operating income, net $ — $ (2) $ — Impairment of assets Other operating income, net $ — $ (7) $ — Three Months Ended March 31, 2023 Location on Income Statement Midstream & Marketing UGI International AmeriGas Propane Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ 4 $ 1 $ — Net (losses) gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ (78) $ (235) $ 8 Net losses on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ (1) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ — $ — $ (6) Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (10) $ — Six Months Ended March 31, 2024 Location on Income Statement Midstream & Marketing UGI International AmeriGas Propane Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ 1 $ 1 $ — Net (gains) losses on commodity derivative instruments not associated with current-period transactions Cost of sales $ (6) $ 12 $ 28 Net losses on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ (2) $ — Restructuring costs Operating and administrative expenses $ — $ (34) $ — Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (19) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ — $ — $ (13) Costs associated with exit of the UGI International energy marketing business Revenues $ — $ (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 business Loss on disposal of UGI International energy marketing business $ — $ (28) $ — Impairment of assets Other operating income, net $ — $ (7) $ — Six Months Ended March 31, 2023 Location on Income Statement Midstream & Marketing UGI International AmeriGas 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 transactions Other operating income, net $ — $ (3) $ — Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (50) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ — $ — $ (13) Costs associated with exit of the UGI International energy marketing business Loss on disposal of UGI International energy marketing business $ — $ (215) $ — Costs associated with exit of the UGI International energy marketing business Operating and administrative expenses $ — $ (19) $ — (b) Represents the elimination of intersegment transactions principally among Utilities, Midstream & Marketing and AmeriGas Propane.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Mar. 31, 2024
Accounting Policies [Abstract]
Restricted Cash	Restricted Cash.
Earnings Per Common Share	Earnings Per Common Share.
Derivative Instruments	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.
Use of Estimates	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	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. 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.
Accounting Standards Not Yet Adopted	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.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	6 Months Ended
	Mar. 31, 2024
Accounting Policies [Abstract]
Schedule of Restrictions on Cash and Cash Equivalents	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, March 31, Cash and cash equivalents $ 263 $ 321 Restricted cash 45 82 Cash, cash equivalents and restricted cash $ 308 $ 403
Schedule of Cash and Cash Equivalents	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, March 31, Cash and cash equivalents $ 263 $ 321 Restricted cash 45 82 Cash, cash equivalents and restricted cash $ 308 $ 403
Schedule of Shares Used in Computing Basic and Diluted Earnings Per Share	Shares used in computing basic and diluted earnings per share are as follows: Three Months Ended Six Months Ended 2024 2023 2024 2023 Denominator (thousands of shares): Weighted-average common shares outstanding — basic 209,826 209,857 209,789 209,902 Incremental shares issuable for stock options, common stock awards and Equity Units (a) 5,419 6,263 5,604 — Weighted-average common shares outstanding — diluted 215,245 216,120 215,393 209,902 (a)

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	6 Months Ended
	Mar. 31, 2024
Revenue from Contract with Customer [Abstract]
Schedule of Disaggregated Revenues by Reportable Segment	The following tables present our disaggregated revenues by reportable segment: Three Months Ended March 31, 2024 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Propane Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 353 $ — $ 353 $ — $ — $ — $ — Commercial & Industrial 144 — 144 — — — — Large delivery service 54 — 54 — — — — Off-system sales and capacity releases 32 (24) 56 — — — — Other 11 — 11 — — — — Total Utility 594 (24) 618 — — — — Non-Utility: LPG: Retail 1,267 — — — 570 697 — Wholesale 89 — — — 60 29 — Energy Marketing 311 (38) — 332 17 — — Midstream: Pipeline 65 — — 65 — — — Peaking 8 (69) — 77 — — — Other 4 — — 4 — — — Electricity Generation 6 — — 6 — — — Other 67 — — — 16 51 — Total Non-Utility 1,817 (107) — 484 663 777 — Total revenues from contracts with customers 2,411 (131) 618 484 663 777 — Other revenues (c) 56 — 28 (1) 10 18 1 Total revenues $ 2,467 $ (131) $ 646 $ 483 $ 673 $ 795 $ 1 Three Months Ended March 31, 2023 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Propane Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 424 $ — $ 424 $ — $ — $ — $ — Commercial & Industrial 177 — 177 — — — — Large delivery service 53 — 53 — — — — Off-system sales and capacity releases 45 (28) 73 — — — — Other 16 (1) 17 — — — — Total Utility 715 (29) 744 — — — — Non-Utility: LPG: Retail 1,328 — — — 573 755 — Wholesale 109 — — — 64 45 — Energy Marketing 740 (39) — 498 281 — — Midstream: Pipeline 66 — — 66 — — — Peaking 10 (58) — 68 — — — Other 4 — — 4 — — — Electricity Generation 2 — — 2 — — — Other 67 — — — 20 47 — Total Non-Utility 2,326 (97) — 638 938 847 — Total revenues from contracts with customers 3,041 (126) 744 638 938 847 — Other revenues (c) 65 (2) 30 — 10 20 7 Total revenues $ 3,106 $ (128) $ 774 $ 638 $ 948 $ 867 $ 7 Six Months Ended March 31, 2024 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Propane Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 635 $ — $ 635 $ — $ — $ — $ — Commercial & Industrial 252 — 252 — — — — Large delivery service 103 — 103 — — — — Off-system sales and capacity releases 53 (36) 89 — — — — Other 20 — 20 — — — — Total Utility 1,063 (36) 1,099 — — — — Non-Utility: LPG: Retail 2,324 — — — 1,094 1,230 — Wholesale 160 — — — 109 51 — Energy Marketing (b) 638 (64) — 604 140 — (42) Midstream: Pipeline 130 — — 130 — — — Peaking 11 (111) — 122 — — — Other 7 — — 7 — — — Electricity Generation 14 — — 14 — — — Other 138 — — — 35 103 — Total Non-Utility 3,422 (175) — 877 1,378 1,384 (42) Total revenues from contracts with customers 4,485 (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) Six Months Ended March 31, 2023 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Propane Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 760 $ — $ 760 $ — $ — $ — $ — Commercial & Industrial 309 — 309 — — — — Large delivery service 100 — 100 — — — — Off-system sales and capacity releases 77 (61) 138 — — — — Other 26 (1) 27 — — — — Total Utility 1,272 (62) 1,334 — — — — Non-Utility: LPG: Retail 2,444 — — — 1,055 1,389 — Wholesale 211 — — — 115 96 — Energy Marketing 1,518 (116) — 1,035 599 — — Midstream: Pipeline 131 — — 131 — — — Peaking 27 (97) — 124 — — — Other 7 — — 7 — — — Electricity Generation 10 — — 10 — — — Other 142 — — — 38 104 — Total Non-Utility 4,490 (213) — 1,307 1,807 1,589 — Total revenues from contracts with customers 5,762 (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.

Inventories (Tables)

Inventories (Tables)	6 Months Ended
	Mar. 31, 2024
Inventory Disclosure [Abstract]
Schedule of Components of Inventories	Inventories comprise the following: March 31, September 30, March 31, Non-utility LPG and natural gas $ 196 $ 212 $ 230 Gas Utility natural gas 8 55 20 Energy certificates 63 64 76 Materials, supplies and other 108 102 107 Total inventories $ 375 $ 433 $ 433

Utility Regulatory Assets and_2

Utility Regulatory Assets and Liabilities and Regulatory Matters (Tables)	6 Months Ended
	Mar. 31, 2024
Regulated Operations [Abstract]
Schedule of Regulatory Assets	The following regulatory assets and liabilities associated with Utilities are included on the Condensed Consolidated Balance Sheets: March 31, September 30, March 31, Regulatory assets (a): Income taxes recoverable $ 93 $ 94 $ 94 Underfunded pension plans 109 111 118 Environmental costs 32 28 34 Deferred fuel and power costs — 27 38 Removal costs, net 23 23 22 Other 55 64 53 Total regulatory assets $ 312 $ 347 $ 359 Regulatory liabilities (a): Postretirement benefit overcollections $ 11 $ 12 $ 10 Deferred fuel and power refunds 34 55 28 State tax benefits — distribution system repairs 44 43 39 Excess federal deferred income taxes 250 254 262 Other 8 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.
Schedule of Regulatory Liabilities	The following regulatory assets and liabilities associated with Utilities are included on the Condensed Consolidated Balance Sheets: March 31, September 30, March 31, Regulatory assets (a): Income taxes recoverable $ 93 $ 94 $ 94 Underfunded pension plans 109 111 118 Environmental costs 32 28 34 Deferred fuel and power costs — 27 38 Removal costs, net 23 23 22 Other 55 64 53 Total regulatory assets $ 312 $ 347 $ 359 Regulatory liabilities (a): Postretirement benefit overcollections $ 11 $ 12 $ 10 Deferred fuel and power refunds 34 55 28 State tax benefits — distribution system repairs 44 43 39 Excess federal deferred income taxes 250 254 262 Other 8 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.

Defined Benefit Pension and O_2

Defined Benefit Pension and Other Postretirement Plans (Tables)	6 Months Ended
	Mar. 31, 2024
Retirement Benefits [Abstract]
Schedule of Components of Net Periodic Pension Benefit Cost (Income)	Net periodic pension benefit cost (income) includes the following components: Pension Benefits Three Months Ended March 31, 2024 2023 Service cost $ 2 $ 3 Interest cost 9 8 Expected return on assets (11) (12) Amortization of: Actuarial loss 1 — Net benefit cost (income) $ 1 $ (1) Six Months Ended March 31, 2024 2023 Service cost $ 4 $ 5 Interest cost 18 17 Expected return on plan assets (22) (23) Amortization of: Actuarial loss (gain) 1 (1) Net benefit cost (income) $ 1 $ (2)

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Mar. 31, 2024
Fair Value Disclosures [Abstract]
Schedule of Financial Assets and Liabilities Measured at Fair Value on a Recurring Basis	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 1 Level 2 Level 3 Total 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).
Schedule of Carrying Amount and Estimated Fair Value of Long-term Debt	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, 2024 September 30, 2023 March 31, 2023 Carrying amount $ 6,826 $ 6,647 $ 6,805 Estimated fair value $ 6,647 $ 6,238 $ 6,480

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	6 Months Ended
	Mar. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Notional Amounts Related to Open Derivative Contracts	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 Type Units Settlements Extending Through March 31, 2024 September 30, 2023 March 31, 2023 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms February 2025 13 38 12 Non-utility Operations LPG swaps Gallons September 2026 425 727 691 Natural gas futures, forward, basis swap, options and pipeline contracts (a) Dekatherms March 2028 339 338 366 Electricity forward and futures contracts Kilowatt hours December 2027 544 1,260 1,890 Interest Rate Risk: Interest rate swaps Euro March 2026 € 300 € 300 € 300 Interest rate swaps USD September 2026 $ 1,263 $ 1,270 $ 1,277 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD September 2026 $ 240 $ 425 $ 285 Net investment hedge forward foreign exchange contracts Euro December 2026 € 256 € 256 € 331 (a) Amounts at September 30, 2023 include contracts associated with certain UGI International energy marketing business transactions (see Note 5).
Schedule of Derivative Assets, Liabilities and Effects of Offsetting	The following table presents the Company’s derivative assets and liabilities by type, as well as the effects of offsetting: March 31, September 30, March 31, Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 11 $ 14 $ 9 Interest rate contracts 11 28 25 22 42 34 Derivatives subject to PGC and DS mechanisms: Commodity contracts 8 6 19 Derivatives not designated as hedging instruments: Commodity contracts (a) 138 226 355 Foreign currency contracts 5 24 14 143 250 369 Total derivative assets — gross 173 298 422 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 sheet 111 124 190 Cash collateral pledged 56 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.
Schedule of Effects of Derivative Instruments on Condensed Consolidated Statements of Income and Changes in AOCI	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) Gain Location of Gain Reclassified from Cash Flow Hedges: 2024 2023 2024 2023 Interest rate contracts $ 17 $ (21) $ 14 $ 7 Interest expense Net Investment Hedges: Foreign currency contracts $ 8 $ (1) Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2024 2023 Location of Gain (Loss) Recognized in Income Commodity contracts $ (1) $ 6 Revenues Commodity contracts 26 (343) Cost of sales Commodity contracts (1) 2 Other operating income, net Foreign currency contracts 8 (2) Other non-operating income (expense), net Total $ 32 $ (337) Six Months Ended March 31,: Loss Gain Reclassified from AOCI into Income Location of Gain Reclassified from AOCI into Income Cash Flow Hedges: 2024 2023 2024 2023 Interest rate contracts $ (5) $ (17) $ 27 $ 14 Interest expense Net Investment Hedges: Foreign currency contracts $ (2) $ (24) Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2024 2023 Location of Gain (Loss) Recognized in Income Commodity contracts $ 1 $ 10 Revenues Commodity contracts (129) (1,669) Cost of sales Commodity contracts 2 5 Other operating income, net Foreign currency contracts (8) (34) Other non-operating income (expense), net Total $ (134) $ (1,688)

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	6 Months Ended
	Mar. 31, 2024
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income, Net of Tax	The tables below present changes in AOCI, net of tax: Three Months Ended March 31, 2024 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total 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, 2023 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total 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, 2024 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total 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, 2023 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total 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)

Equity Method Investments (Tabl

Equity Method Investments (Tables)	6 Months Ended
	Mar. 31, 2024
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Equity Method Investments	Equity method investments comprise the following: Carrying Value Ownership Interest Investees March 31, 2024 September 30, March 31, March 31, September 30, March 31, Midstream & Marketing: Aurum Renewables $ 46 $ 45 $ 19 40% 40% 40% Pine Run 81 77 72 49% 49% 49% MBL Bioenergy 157 122 78 99.99% 99.99% 99.99% Other 21 20 20 various various various Total Midstream & Marketing 305 264 189 UGI International 35 35 30 various various various Total investments in equity method investees $ 340 $ 299 $ 219

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Mar. 31, 2024
Segment Reporting [Abstract]
Schedule of Segment Reporting Information	Three Months Ended March 31, 2024 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Corporate 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 investees 1 — — 2 (1) — — Other non-operating income, net 11 — 1 — 8 — 2 Earnings before interest expense and income taxes 729 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, 2023 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Corporate 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), net 2 — 2 — 10 — (10) Earnings (loss) before interest expense and income taxes 257 (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, 2024 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Corporate 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 investees 2 — — 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 Six Months Ended March 31, 2023 Total Eliminations Utilities Midstream & Marketing UGI International AmeriGas Corporate 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: Three Months Ended March 31, 2024 Location on Income Statement Midstream & Marketing UGI International AmeriGas Propane Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 41 $ 53 $ 34 Net gains on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ 1 $ — Restructuring costs Operating and administrative expenses $ — $ (34) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ — $ — $ (6) Unrealized gains on foreign currency derivative instruments Other non-operating income (expense), net $ — $ 1 $ — Costs associated with exit of the UGI International energy marketing business Operating and administrative expenses/Other operating income, net $ — $ (2) $ — Impairment of assets Other operating income, net $ — $ (7) $ — Three Months Ended March 31, 2023 Location on Income Statement Midstream & Marketing UGI International AmeriGas Propane Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ 4 $ 1 $ — Net (losses) gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ (78) $ (235) $ 8 Net losses on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ (1) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ — $ — $ (6) Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (10) $ — Six Months Ended March 31, 2024 Location on Income Statement Midstream & Marketing UGI International AmeriGas Propane Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ 1 $ 1 $ — Net (gains) losses on commodity derivative instruments not associated with current-period transactions Cost of sales $ (6) $ 12 $ 28 Net losses on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ (2) $ — Restructuring costs Operating and administrative expenses $ — $ (34) $ — Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (19) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ — $ — $ (13) Costs associated with exit of the UGI International energy marketing business Revenues $ — $ (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 business Loss on disposal of UGI International energy marketing business $ — $ (28) $ — Impairment of assets Other operating income, net $ — $ (7) $ — Six Months Ended March 31, 2023 Location on Income Statement Midstream & Marketing UGI International AmeriGas 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 transactions Other operating income, net $ — $ (3) $ — Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (50) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ — $ — $ (13) Costs associated with exit of the UGI International energy marketing business Loss on disposal of UGI International energy marketing business $ — $ (215) $ — Costs associated with exit of the UGI International energy marketing business Operating and administrative expenses $ — $ (19) $ — (b) Represents the elimination of intersegment transactions principally among Utilities, Midstream & Marketing and AmeriGas Propane.

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Schedule of Cash and Restricted Cash (Details) - USD ($) $ in Millions	Mar. 31, 2024	Sep. 30, 2023	Mar. 31, 2023	Sep. 30, 2022
Accounting Policies [Abstract]
Cash and cash equivalents	$ 263	$ 241	$ 321
Restricted cash	45	99	82
Cash, cash equivalents and restricted cash	$ 308	$ 340	$ 403	$ 469

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Shares Used in Computing Basic and Diluted Earnings Per Share (Details) - shares shares in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023
Denominator (thousands of shares):
Weighted-average common shares outstanding - basic (in shares)	209,826	209,857	209,789	209,902
Incremental shares issuable for stock options, common stock awards and Equity Units (in shares)	5,419	6,263	5,604	0
Weighted-average common shares outstanding - diluted (in shares)	215,245	216,120	215,393	209,902
Stock options
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	8,659	5,980	8,468	6,348

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Mar. 31, 2024	Mar. 31, 2023
Schedule of Equity Method Investments [Line Items]
Goodwill	$ 3,027	$ 3,048	$ 3,709
UGI International
Schedule of Equity Method Investments [Line Items]
Goodwill		931
Percentage of fair value exceeding carrying value	10%
AmeriGas Propane
Schedule of Equity Method Investments [Line Items]
Impairment of goodwill	$ 656
Goodwill		$ 1,400

Revenue from Contracts with C_3

Revenue from Contracts with Customers - Disaggregated Revenues by Reportable Segment (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 2,411	$ 3,041	$ 4,485	$ 5,762
Other revenues	56	65	103	103
Total revenues	2,467	3,106	4,588	5,865
Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	594	715	1,063	1,272
Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	353	424	635	760
Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	144	177	252	309
Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	54	53	103	100
Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	32	45	53	77
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	11	16	20	26
Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,817	2,326	3,422	4,490
Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,267	1,328	2,324	2,444
Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	89	109	160	211
Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	311	740	638	1,518
Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	65	66	130	131
Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	8	10	11	27
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4	4	7	7
Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	6	2	14	10
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	67	67	138	142
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(131)	(126)	(211)	(275)
Other revenues	0	(2)	0	(2)
Total revenues	(131)	(128)	(211)	(277)
Eliminations | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(24)	(29)	(36)	(62)
Eliminations | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(24)	(28)	(36)	(61)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	(1)	0	(1)
Eliminations | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(107)	(97)	(175)	(213)
Eliminations | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(38)	(39)	(64)	(116)
Eliminations | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(69)	(58)	(111)	(97)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Utilities
Disaggregation of Revenue [Line Items]
Total revenues	23	28	36	61
Eliminations | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues	108	98	175	213
Eliminations | UGI International
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Eliminations | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Operating Segments | Utilities
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	618	744	1,099	1,334
Other revenues	28	30	40	32
Total revenues	646	774	1,139	1,366
Operating Segments | Utilities | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	618	744	1,099	1,334
Operating Segments | Utilities | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	353	424	635	760
Operating Segments | Utilities | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	144	177	252	309
Operating Segments | Utilities | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	54	53	103	100
Operating Segments | Utilities | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	56	73	89	138
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	11	17	20	27
Operating Segments | Utilities | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	484	638	877	1,307
Other revenues	(1)	0	0	0
Total revenues	483	638	877	1,307
Operating Segments | Midstream & Marketing | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	484	638	877	1,307
Operating Segments | Midstream & Marketing | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	332	498	604	1,035
Operating Segments | Midstream & Marketing | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	65	66	130	131
Operating Segments | Midstream & Marketing | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	77	68	122	124
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4	4	7	7
Operating Segments | Midstream & Marketing | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	6	2	14	10
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	663	938	1,378	1,807
Other revenues	10	10	20	18
Total revenues	673	948	1,398	1,825
Operating Segments | UGI International | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	663	938	1,378	1,807
Operating Segments | UGI International | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	570	573	1,094	1,055
Operating Segments | UGI International | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	60	64	109	115
Operating Segments | UGI International | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	17	281	140	599
Operating Segments | UGI International | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	16	20	35	38
Operating Segments | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	777	847	1,384	1,589
Other revenues	18	20	40	44
Total revenues	795	867	1,424	1,633
Operating Segments | AmeriGas Propane | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	777	847	1,384	1,589
Operating Segments | AmeriGas Propane | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	697	755	1,230	1,389
Operating Segments | AmeriGas Propane | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	29	45	51	96
Operating Segments | AmeriGas Propane | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	51	47	103	104
Corporate & Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	(42)	0
Other revenues	1	7	3	11
Total revenues	1	7	(39)	11
Corporate & Other | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	(42)	0
Corporate & Other | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	(42)	0
Reduction in revenue			42
Corporate & Other | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 0	$ 0	$ 0	$ 0

Revenue from Contracts with C_4

Revenue from Contracts with Customers - Narrative (Details) - USD ($) $ in Millions	6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Sep. 30, 2023
Disaggregation of Revenue [Line Items]
Contract liabilities	$ 126	$ 126	$ 158
Revenue recognized	114	$ 119
Midstream & Marketing
Disaggregation of Revenue [Line Items]
Expected revenue	2,300
Utilities
Disaggregation of Revenue [Line Items]
Expected revenue	$ 200

Dispositions (Details)

Dispositions (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Sep. 30, 2023	Dec. 31, 2022	Oct. 31, 2023	Oct. 31, 2022
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operation, Gain (Loss) on Disposal, Statement of Income or Comprehensive Income [Extensible Enumeration]			Gain (Loss) on Disposition of Business
Sale | France
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net cash payment				$ 28
Pre-tax loss	$ 28
Sale | Belgium
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net cash payment		$ 3
Pre-tax loss		$ 6
Sale | United Kingdom
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net cash payment					$ 19
Pre-tax loss			$ 215
Net carrying value					$ 206
Sale | Netherlands
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Settlement gain (loss)	46
Reduction in revenue	42
Pre-tax impairment charges			$ 19
Sale | European energy marketing business
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Settlement gain (loss)	(5)
Total settlement consideration	$ 5

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Mar. 31, 2024	Sep. 30, 2023	Mar. 31, 2023
Inventory
Total inventories	$ 375	$ 433	$ 433
Non-utility LPG and natural gas
Inventory
Total inventories	196	212	230
Gas Utility natural gas
Inventory
Total inventories	8	55	20
Energy certificates
Inventory
Total inventories	63	64	76
Materials, supplies and other
Inventory
Total inventories	$ 108	$ 102	$ 107

Utility Regulatory Assets and_3

Utility Regulatory Assets and Liabilities and Regulatory Matters - Schedule of Regulatory Assets and Liabilities (Details) - Utilities - USD ($) $ in Millions	Mar. 31, 2024	Sep. 30, 2023	Mar. 31, 2023
Regulatory Assets
Regulatory assets	$ 312	$ 347	$ 359
Regulatory Liabilities
Regulatory liabilities	347	366	345
Postretirement benefit overcollections
Regulatory Liabilities
Regulatory liabilities	11	12	10
Deferred fuel and power refunds
Regulatory Liabilities
Regulatory liabilities	34	55	28
State tax benefits — distribution system repairs
Regulatory Liabilities
Regulatory liabilities	44	43	39
Excess federal deferred income taxes
Regulatory Liabilities
Regulatory liabilities	250	254	262
Other
Regulatory Liabilities
Regulatory liabilities	8	2	6
Income taxes recoverable
Regulatory Assets
Regulatory assets	93	94	94
Underfunded pension plans
Regulatory Assets
Regulatory assets	109	111	118
Environmental costs
Regulatory Assets
Regulatory assets	32	28	34
Deferred fuel and power costs
Regulatory Assets
Regulatory assets	0	27	38
Removal costs, net
Regulatory Assets
Regulatory assets	23	23	22
Other
Regulatory Assets
Regulatory assets	$ 55	$ 64	$ 53

Utility Regulatory Assets and_4

Utility Regulatory Assets and Liabilities and Regulatory Matters - Narrative (Details) - USD ($) $ in Millions

6 Months Ended

12 Months Ended

Apr. 11, 2024

Dec. 21, 2023

Oct. 06, 2023

Sep. 21, 2023

Jul. 31, 2023

Mar. 06, 2023

Jan. 27, 2023

Jan. 01, 2023

Nov. 01, 2022

Sep. 15, 2022

Jul. 29, 2022

Jan. 28, 2022

Mar. 31, 2024

Mar. 31, 2023

Sep. 30, 2023

Regulatory Assets

Net unrealized gains (losses)

$ (54)

$ (1,713)

Gas Utility

Regulatory Assets

Net unrealized gains (losses)

$ (7)

$ (17)

$ (2)

Utilities | PAPUC

Regulatory Assets

Requested rate increase (decrease)

$ 11

$ 83

Approved rate increase (decrease)

$ 9

Utilities | PAPUC | Joint Petition

Regulatory Assets

Requested rate increase (decrease)

$ 49

Property, plant and equipment, net threshold

3,368

Utilities | PAPUC | Beginning October 29, 2022

Regulatory Assets

Requested rate increase (decrease)

38

Utilities | PAPUC | Beginning October 1, 2023

Regulatory Assets

Requested rate increase (decrease)

$ 11

Utilities | PAPUC | Weather normalization adjustment rider

Regulatory Assets

Pilot program duration

5 years

Approved rate

3%

Mountaineer | WVPSC | Weather normalization adjustment rider

Regulatory Assets

Adjustment rider period

5 years

Mountaineer | WVPSC | Weather normalization adjustment rider | Subsequent event

Regulatory Assets

Approved rate

2%

Weather deviates threshold

2%

Mountaineer | WVPSC | 2023 IREP Recovery

Regulatory Assets

Requested rate increase (decrease)

$ 10

Total capital investments

383

Mountaineer | WVPSC | 2023 IREP

Regulatory Assets

Costs associated with capital investments

131

Mountaineer | WVPSC | 2023 IREP For 2024

Regulatory Assets

Costs associated with capital investments

$ 67

Mountaineer | WVPSC | Net Revenue Increase

Regulatory Assets

Requested rate increase (decrease)

$ 14

$ 20

Mountaineer | WVPSC | Base Rates

Regulatory Assets

Requested rate increase (decrease)

38

Mountaineer | WVPSC | IREP rate

Regulatory Assets

Requested rate increase (decrease)

$ (18)

Mountaineer | WVPSC | Over 2023 - 2027

Regulatory Assets

Requested rate increase (decrease)

$ 354

Mountaineer | WVPSC | Calendar Year 2023

Regulatory Assets

Requested rate increase (decrease)

$ 64

Approved rate increase (decrease)

$ 22

Debt (Details)

Debt (Details)	1 Months Ended	6 Months Ended
	Apr. 30, 2024 USD ($)	Mar. 31, 2024 USD ($) cure	Nov. 30, 2023 USD ($)	Nov. 15, 2023 USD ($)	Nov. 14, 2023 USD ($)	Nov. 09, 2023 USD ($)
2022 AmeriGas OLP Credit Agreement | AmeriGas OLP
Debt Instrument [Line Items]
Number of available equity cure | cure		5
Equity cure used | cure		1
Debt instrument, actual leverage ratio		5.74
2022 AmeriGas OLP Credit Agreement | AmeriGas OLP | Maximum
Debt Instrument [Line Items]
Debt instrument, financial covenant leverage ratio		5.75
2022 AmeriGas OLP Credit Agreement | AmeriGas OLP | Minimum
Debt Instrument [Line Items]
Debt instrument, financial covenant leverage ratio		5.50
Credit Agreement | UGI Corporation Credit Facility Agreement | Revolver | Subsequent event
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 300,000,000
Credit Agreement | UGI Corporation Credit Facility Agreement, Variable-Rate Term Loan 1 | Subsequent event
Debt Instrument [Line Items]
Principal amount	$ 215,000,000
Debt Instrument, Interest Rate, Increase (Decrease)	0.375%
Credit Agreement | UGI Corporation Credit Facility Agreement, Variable-Rate Term Loan 2 | Subsequent event
Debt Instrument [Line Items]
Principal amount	$ 300,000,000
Debt Instrument, Interest Rate, Increase (Decrease)	0.375%
Credit Agreement | UGI Corporation Credit Facility Agreement, Variable-Rate Term Loan 3 | Subsequent event
Debt Instrument [Line Items]
Principal amount	$ 250,000,000
Credit Agreement | 2022 AmeriGas OLP Credit Agreement | AmeriGas OLP | Revolver
Debt Instrument [Line Items]
Maximum borrowing capacity				$ 400,000,000	$ 600,000,000
Credit Agreement | UGI Utilities Credit Agreement | Utilities | Revolver
Debt Instrument [Line Items]
Maximum borrowing capacity						$ 375,000,000
Increase to limit						125,000,000
Credit Agreement | UGI Utilities Credit Agreement | Utilities | Letters of credit
Debt Instrument [Line Items]
Maximum borrowing capacity						50,000,000
Credit Agreement | UGI Utilities Credit Agreement | Utilities | Swingline loans
Debt Instrument [Line Items]
Maximum borrowing capacity						$ 38,000,000
Senior Notes | 5.50 Percent Senior Notes | AmeriGas Partners And AmeriGas Finance Corp.
Debt Instrument [Line Items]
Repurchase amount		$ 7,000,000
Interest rate		5.50%
Senior Notes | 5.875 Percent Senior Notes | AmeriGas Partners And AmeriGas Finance Corp.
Debt Instrument [Line Items]
Repurchase amount		$ 11,000,000
Interest rate		5.875%
Senior Notes | 5.75 Percent Senior Notes | AmeriGas Partners And AmeriGas Finance Corp.
Debt Instrument [Line Items]
Repurchase amount		$ 13,000,000
Interest rate		5.75%
Senior Notes | 9.375 Percent Senior Notes | AmeriGas Partners And AmeriGas Finance Corp.
Debt Instrument [Line Items]
Repurchase amount		$ 7,000,000
Interest rate		9.375%
Senior Notes | Senior Notes Due 2030 | Utilities
Debt Instrument [Line Items]
Principal amount			$ 25,000,000
Interest rate			6.02%
Senior Notes | Senior Notes Due 2033 | Utilities
Debt Instrument [Line Items]
Principal amount			$ 150,000,000
Interest rate			6.10%
Senior Notes | Senior Notes Due 2053 | Utilities
Debt Instrument [Line Items]
Principal amount			$ 75,000,000
Interest rate			6.40%
Senior Notes | Senior Notes | AmeriGas Partners And AmeriGas Finance Corp.
Debt Instrument [Line Items]
Aggregate principal amount		$ 38,000,000
Long-term debt, gross		$ 2,362,000,000

Commitments and Contingencies (

Commitments and Contingencies (Details)	3 Months Ended	6 Months Ended	12 Months Ended
	Mar. 31, 2024 USD ($) subsidiary	Mar. 31, 2024 USD ($) subsidiary	Dec. 31, 2017 USD ($) record_of_decision	Sep. 30, 2023 USD ($)	Mar. 31, 2023 USD ($)	Mar. 24, 2023 person
Loss Contingencies
Environmental expenditures cap during calendar year		$ 5,000,000
West Reading, Pennsylvania Explosion
Loss Contingencies
Number of fatalities | person						7
Number of injuries | person						11
MGP sites in Pennsylvania
Loss Contingencies
Accrual for environmental loss contingencies	$ 56,000,000	$ 56,000,000		$ 52,000,000	$ 52,000,000
Utilities
Loss Contingencies
Number of subsidiaries acquired with similar histories | subsidiary	2	2
AmeriGas OLP | Saranac Lake, New York | NYDEC ROD
Loss Contingencies
Accrual for environmental loss contingencies	$ 8,000,000	$ 8,000,000
Loss contingency, number of remediation plans | record_of_decision			3
Estimated remediation plan cost			$ 28,000,000
UGI International
Loss Contingencies
Pre-tax severance and other related expense	$ 34,000,000

Defined Benefit Pension and O_3

Defined Benefit Pension and Other Postretirement Plans - Components of Net Periodic Pension Benefit Cost (Income) (Details) - Pension Plan - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023
Defined Benefit Plan Disclosure
Service cost	$ 2	$ 3	$ 4	$ 5
Interest cost	9	8	18	17
Expected return on plan assets	(11)	(12)	(22)	(23)
Amortization of:
Actuarial loss (gain)	1	0	1	(1)
Net benefit cost (income)	$ 1	$ (1)	$ 1	$ (2)

Fair Value Measurements - Finan

Fair Value Measurements - Financial Assets and Liabilities that are Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Millions	Mar. 31, 2024	Sep. 30, 2023	Mar. 31, 2023
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	$ 173	$ 298	$ 422
Liabilities:	(226)	(276)	(457)
Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	8	6	19
Liabilities:	(14)	(8)	(36)
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	41	39	31
Recurring | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	146	232	374
Liabilities:	(222)	(274)	(432)
Recurring | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	16	38	23
Liabilities:	(1)	(2)	(4)
Recurring | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	11	28	25
Liabilities:	(3)		(21)
Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	41	39	31
Recurring | Level 1 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	107	117	229
Liabilities:	(184)	(193)	(294)
Recurring | Level 1 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	0	0	0
Liabilities:	0	0	0
Recurring | Level 1 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	0	0	0
Liabilities:	0		0
Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	0	0	0
Recurring | Level 2 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	39	115	145
Liabilities:	(38)	(81)	(138)
Recurring | Level 2 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	16	38	23
Liabilities:	(1)	(2)	(4)
Recurring | Level 2 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	11	28	25
Liabilities:	(3)		(21)
Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	0	0	0
Recurring | Level 3 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	0	0	0
Liabilities:	0	0	0
Recurring | Level 3 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	0	0	0
Liabilities:	0	0	0
Recurring | Level 3 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	0	$ 0	0
Liabilities:	$ 0		$ 0

Fair Value Measurements - Carry

Fair Value Measurements - Carrying Amounts and Estimated Fair Values of Long-term Debt (Details) - USD ($) $ in Millions	Mar. 31, 2024	Sep. 30, 2023	Mar. 31, 2023
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,826	$ 6,647	$ 6,805
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,647	$ 6,238	$ 6,480

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Narrative (Details) - USD ($)	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023	Sep. 30, 2023
Derivative [Line Items]
Pre-tax gains (losses) associated with net investment hedges	$ 17,000,000	$ (9,000,000)	$ (15,000,000)	$ (73,000,000)
Maximum amount of loss	173,000,000		173,000,000
Cash collateral received	6,000,000	55,000,000	6,000,000	55,000,000	$ 40,000,000
IRPAs
Derivative [Line Items]
Notional amount	0	$ 0	0	$ 0	$ 0
Pre-tax net gains associated with interest rate hedges	$ 19,000,000		$ 19,000,000
Forward foreign currency exchange contracts
Derivative [Line Items]
Derivative notional amount percent of required need coverage	90%		90%

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Schedule of Notional Amounts (Details) € in Millions, kWh in Millions, gal in Millions, DTH in Millions, $ in Millions	Mar. 31, 2024 USD ($) kWh DTH gal	Mar. 31, 2024 EUR (€) kWh DTH gal	Sep. 30, 2023 USD ($) DTH kWh gal	Sep. 30, 2023 EUR (€) DTH kWh gal	Mar. 31, 2023 USD ($) DTH gal kWh	Mar. 31, 2023 EUR (€) DTH gal kWh
Commodity contracts | Regulated Utility Operations | Natural Gas
Derivative [Line Items]
Notional amount (in units)	13	13	38	38	12	12
Commodity contracts | Non-utility Operations | LPG swaps
Derivative [Line Items]
Notional amount (in units) | gal	425	425	727	727	691	691
Commodity contracts | Non-utility Operations | Electricity forward and futures contracts
Derivative [Line Items]
Notional amount (in units) | kWh	544	544	1,260	1,260	1,890	1,890
Natural gas futures, forward, basis swap, options and pipeline contracts | Non-utility Operations | Natural Gas
Derivative [Line Items]
Notional amount (in units)	339	339	338	338	366	366
Interest rate swaps
Derivative [Line Items]
Notional amount	$ 1,263	€ 300	$ 1,270	€ 300	$ 1,277	€ 300
Forward foreign currency exchange contracts
Derivative [Line Items]
Notional amount	$ 240	€ 256	$ 425	€ 256	$ 285	€ 331

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2024	Sep. 30, 2023	Mar. 31, 2023
Derivative assets:
Total derivative assets — gross	$ 173	$ 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:
Total derivative liabilities — gross	(226)	(276)	(457)
Gross amounts offset in the balance sheet	111	124	190
Cash collateral pledged	56	53	102
Total derivative liabilities — net	(59)	(99)	(165)
Commodity contracts
Derivative assets:
Total derivative assets — gross	8	6	19
Derivative liabilities:
Total derivative liabilities — gross	(14)	(8)	(36)
Derivatives designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	22	42	34
Derivatives designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	11	14	9
Derivatives designated as hedging instruments: | Interest rate contracts
Derivative assets:
Total derivative assets — gross	11	28	25
Derivative liabilities:
Total derivative liabilities — gross	(3)	0	(21)
Derivatives not designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	143	250	369
Derivative liabilities:
Total derivative liabilities — gross	(209)	(268)	(400)
Derivatives not designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	5	24	14
Derivative liabilities:
Total derivative liabilities — gross	(1)	(2)	(4)
Derivatives not designated as hedging instruments: | Commodity contracts
Derivative assets:
Total derivative assets — gross	138	226	355
Derivative liabilities:
Total derivative liabilities — gross	$ (208)	(266)	$ (396)
Derivatives not designated as hedging instruments: | Commodity contracts | Prepaid expenses and other current assets
Derivative assets:
Total derivative assets — gross		10
Derivatives not designated as hedging instruments: | Commodity contracts | Other current liabilities
Derivative liabilities:
Total derivative liabilities — gross		$ (12)

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Effects of Derivative Instruments on the Condensed Consolidated Statements of Income and Changes in AOCI (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023
Derivatives not designated as hedging instruments:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 32	$ (337)	$ (134)	$ (1,688)
Interest rate contracts | Derivatives designated as hedging instruments: | Cash Flow Hedges:
Derivative Instruments, Gain (Loss)
Loss Recognized in AOCI	17	(21)	(5)	(17)
Interest rate contracts | Derivatives designated as hedging instruments: | Interest expense | Cash Flow Hedges:
Derivative Instruments, Gain (Loss)
Gain Reclassified from AOCI into Income	14	7	27	14
Foreign currency contracts | Derivatives designated as hedging instruments: | Net Investment Hedges:
Derivative Instruments, Gain (Loss)
Foreign currency contracts	8	(1)	(2)	(24)
Foreign currency contracts | Derivatives not designated as hedging instruments: | Other non-operating income (expense), net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	8	(2)	(8)	(34)
Commodity contracts | Derivatives not designated as hedging instruments: | Revenues
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(1)	6	1	10
Commodity contracts | Derivatives not designated as hedging instruments: | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	26	(343)	(129)	(1,669)
Commodity contracts | Derivatives not designated as hedging instruments: | Other operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ (1)	$ 2	$ 2	$ 5

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period			$ 4,394
Other comprehensive (loss) income before reclassification adjustments	$ (12)	$ (5)	22	$ 149
Amounts reclassified from AOCI	(10)	(5)	(20)	(10)
Other comprehensive (loss) income	(22)	(10)	2	139
Balance, end of period	4,831	5,214	4,831	5,214
Total
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(232)	(231)	(256)	(380)
Balance, end of period	(254)	(241)	(254)	(241)
Postretirement Benefit Plans
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	17	14	17	14
Other comprehensive (loss) income before reclassification adjustments	0	0	0	0
Amounts reclassified from AOCI	(1)	0	(1)	0
Other comprehensive (loss) income	(1)	0	(1)	0
Balance, end of period	16	14	16	14
Derivative Instruments
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	1	35	26	37
Other comprehensive (loss) income before reclassification adjustments	12	(15)	(3)	(12)
Amounts reclassified from AOCI	(9)	(5)	(19)	(10)
Other comprehensive (loss) income	3	(20)	(22)	(22)
Balance, end of period	4	15	4	15
Foreign Currency
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(250)	(280)	(299)	(431)
Other comprehensive (loss) income before reclassification adjustments	(24)	10	25	161
Amounts reclassified from AOCI	0	0	0	0
Other comprehensive (loss) income	(24)	10	25	161
Balance, end of period	$ (274)	$ (270)	$ (274)	$ (270)

Equity Method Investments (Deta

Equity Method Investments (Details) - USD ($) $ in Millions	Mar. 31, 2024	Sep. 30, 2023	Mar. 31, 2023
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 340	$ 299	$ 219
Midstream & Marketing
Schedule of Equity Method Investments [Line Items]
Carrying Value	305	264	189
Midstream & Marketing | Aurum Renewables
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 46	$ 45	$ 19
Ownership Interest	40%	40%	40%
Midstream & Marketing | Pine Run
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 81	$ 77	$ 72
Ownership Interest	49%	49%	49%
Midstream & Marketing | MBL Bioenergy
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 157	$ 122	$ 78
Ownership Interest	99.99%	99.99%	99.99%
Midstream & Marketing | Other
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 21	$ 20	$ 20
UGI International
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 35	$ 35	$ 30

Segment Information - Narrative

Segment Information - Narrative (Details)	6 Months Ended
	Mar. 31, 2024 segment
Segment Reporting [Abstract]
Number of reportable segments	4

Segment Information - Schedule

Segment Information - Schedule of Segment Reporting Information (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023	Sep. 30, 2023
Segment Reporting Information [Line Items]
Revenues	$ 2,467	$ 3,106	$ 4,588	$ 5,865
Cost of sales	1,030	2,148	2,232	5,254
Operating income (loss)	717	255	949	(949)
Income (loss) from equity investees	1	0	2	1
Other non-operating (expense) income, net	11	2	(2)	(26)
Earnings before interest expense and income taxes	729	257	949	(974)
Interest expense	(100)	(93)	(200)	(185)
Income (loss) before income taxes	629	164	749	(1,159)
Depreciation and amortization	138	132	275	263
Capital expenditures (including the effects of accruals)	167	214	300	392
Total assets	15,624	16,429	15,624	16,429	$ 15,401
Eliminations
Segment Reporting Information [Line Items]
Revenues	(131)	(128)	(211)	(277)
Cost of sales	(131)	(126)	(211)	(275)
Operating income (loss)	1	(1)	0	0
Income (loss) from equity investees	0	0	0	0
Other non-operating (expense) income, net	0	0	0	0
Earnings before interest expense and income taxes	1	(1)	0	0
Interest expense	0	0	0	0
Income (loss) before income taxes	1	(1)	0	0
Depreciation and amortization	0	0	0	0
Capital expenditures (including the effects of accruals)	0	0	0	0
Total assets	(131)	(232)	(131)	(232)
Eliminations | Utilities
Segment Reporting Information [Line Items]
Revenues	23	28	36	61
Eliminations | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	108	98	175	213
Eliminations | UGI International
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Eliminations | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Operating Segments | Utilities
Segment Reporting Information [Line Items]
Revenues	646	774	1,139	1,366
Revenues from external customers	623	746	1,103	1,305
Cost of sales	274	426	495	755
Operating income (loss)	225	203	359	329
Income (loss) from equity investees	0	0	0	0
Other non-operating (expense) income, net	1	2	2	4
Earnings before interest expense and income taxes	226	205	361	333
Interest expense	(24)	(21)	(47)	(42)
Income (loss) before income taxes	202	184	314	291
Depreciation and amortization	41	37	82	74
Capital expenditures (including the effects of accruals)	91	133	173	250
Total assets	5,850	5,643	5,850	5,643
Operating Segments | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	483	638	877	1,307
Revenues from external customers	375	540	702	1,094
Cost of sales	283	479	522	993
Operating income (loss)	151	103	250	209
Income (loss) from equity investees	2	2	5	3
Other non-operating (expense) income, net	0	0	0	0
Earnings before interest expense and income taxes	153	105	255	212
Interest expense	(9)	(11)	(20)	(22)
Income (loss) before income taxes	144	94	235	190
Depreciation and amortization	22	22	44	43
Capital expenditures (including the effects of accruals)	33	23	52	34
Total assets	3,204	3,116	3,204	3,116
Operating Segments | UGI International
Segment Reporting Information [Line Items]
Revenues	673	948	1,398	1,825
Cost of sales	368	633	814	1,295
Operating income (loss)	124	120	237	176
Income (loss) from equity investees	(1)	(2)	(3)	(2)
Other non-operating (expense) income, net	8	10	14	20
Earnings before interest expense and income taxes	131	128	248	194
Interest expense	(11)	(9)	(22)	(16)
Income (loss) before income taxes	120	119	226	178
Depreciation and amortization	29	28	59	56
Capital expenditures (including the effects of accruals)	19	30	31	57
Total assets	3,030	3,490	3,030	3,490
Operating Segments | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	795	867	1,424	1,633
Cost of sales	362	430	645	816
Operating income (loss)	138	138	209	248
Income (loss) from equity investees	0	0	0	0
Other non-operating (expense) income, net	0	0	0	0
Earnings before interest expense and income taxes	138	138	209	248
Interest expense	(40)	(39)	(81)	(82)
Income (loss) before income taxes	98	99	128	166
Depreciation and amortization	44	45	88	89
Capital expenditures (including the effects of accruals)	24	28	44	51
Total assets	3,467	4,248	3,467	4,248
Corporate & Other
Segment Reporting Information [Line Items]
Revenues from external customers	1	5	(39)	8
Cost of sales	(126)	306	(33)	1,670
Operating income (loss)	78	(308)	(106)	(1,911)
Income (loss) from equity investees	0	0	0	0
Other non-operating (expense) income, net	2	(10)	(18)	(50)
Earnings before interest expense and income taxes	80	(318)	(124)	(1,961)
Interest expense	(16)	(13)	(30)	(23)
Income (loss) before income taxes	64	(331)	(154)	(1,984)
Depreciation and amortization	2	0	2	1
Capital expenditures (including the effects of accruals)	0	0	0	0
Total assets	204	164	204	164
Intersegment revenues Corporate & Other
Segment Reporting Information [Line Items]
Revenues	$ 0	$ 2	$ 0	$ 3

Segment Information - Reconcili

Segment Information - Reconciliation of Partnership Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024	Mar. 31, 2023
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions			$ (54)	$ (1,713)
Midstream & Marketing | Revenues
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions		$ 4	1	6
Costs associated with exit of the UGI International energy marketing business			0
Midstream & Marketing | Cost of sales
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions	$ 41	(78)	(6)	(261)
Midstream & Marketing | Other operating income, net
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions	0	0	0	0
Impairment of assets	0		0
Midstream & Marketing | Operating and administrative expenses
Segment Reporting Information [Line Items]
Restructuring costs	0		0
AmeriGas operations enhancement for growth project	0	0	0	0
Costs associated with exit of the UGI International energy marketing business				0
Midstream & Marketing | Other non-operating income (expense), net
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions	0	0	0	0
Midstream & Marketing | Operating and administrative expenses/Other operating income, net
Segment Reporting Information [Line Items]
Costs associated with exit of the UGI International energy marketing business	0		0
Midstream & Marketing | Loss on disposal of UGI International energy marketing business
Segment Reporting Information [Line Items]
Costs associated with exit of the UGI International energy marketing business			0	0
UGI International | Revenues
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions		1	1	3
Costs associated with exit of the UGI International energy marketing business			(42)
UGI International | Cost of sales
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions	53	(235)	12	(1,404)
UGI International | Other operating income, net
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions	1	(1)	(2)	(3)
Impairment of assets	(7)		(7)
UGI International | Operating and administrative expenses
Segment Reporting Information [Line Items]
Restructuring costs	(34)		(34)
AmeriGas operations enhancement for growth project	0	0	0	0
Costs associated with exit of the UGI International energy marketing business				19
UGI International | Other non-operating income (expense), net
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions	1	(10)	(19)	(50)
UGI International | Operating and administrative expenses/Other operating income, net
Segment Reporting Information [Line Items]
Costs associated with exit of the UGI International energy marketing business	(2)		(10)
UGI International | Loss on disposal of UGI International energy marketing business
Segment Reporting Information [Line Items]
Costs associated with exit of the UGI International energy marketing business			(28)	215
AmeriGas Propane | Revenues
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions		0	0	0
Costs associated with exit of the UGI International energy marketing business			0
AmeriGas Propane | Cost of sales
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions	34	8	28	(4)
AmeriGas Propane | Other operating income, net
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions	0	0	0	0
Impairment of assets	0		0
AmeriGas Propane | Operating and administrative expenses
Segment Reporting Information [Line Items]
Restructuring costs	0		0
AmeriGas operations enhancement for growth project	(6)	(6)	(13)	(13)
Costs associated with exit of the UGI International energy marketing business				0
AmeriGas Propane | Other non-operating income (expense), net
Segment Reporting Information [Line Items]
Net (losses) gains on commodity derivative instruments not associated with current-period transactions	0	$ 0	0	0
AmeriGas Propane | Operating and administrative expenses/Other operating income, net
Segment Reporting Information [Line Items]
Costs associated with exit of the UGI International energy marketing business	$ 0		0
AmeriGas Propane | Loss on disposal of UGI International energy marketing business
Segment Reporting Information [Line Items]
Costs associated with exit of the UGI International energy marketing business			$ 0	$ 0