UGI (UGI) 10-K 28 Nov 23 2023 FY Annual report Financial data

Cover Page

Cover Page - USD ($)	12 Months Ended
	Sep. 30, 2023	Nov. 10, 2023	Mar. 31, 2023
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Sep. 30, 2023
Current Fiscal Year End Date	--09-30
Document Transition Report	false
Entity File Number	1-11071
Entity Registrant Name	UGI CORP
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 Well-Known Seasoned Issuer	Yes
Entity Voluntary Filers	No
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
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction [Flag]	false
Entity Shell Company	false
Entity Public Float			$ 7,252,195,251
Entity Common Stock, Shares Outstanding		210,899,583
Documents Incorporated by Reference	Portions of the Proxy Statement for the Annual Meeting of Shareholders to be held on January 26, 2024 are incorporated by reference into Part III of this Form 10-K.
Entity Central Index Key	0000884614
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	FY
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

Audit Information

Audit Information	12 Months Ended
	Sep. 30, 2023
Auditor Information [Abstract]
Auditor Name	Ernst & Young LLP
Auditor Location	Philadelphia, Pennsylvania
Auditor Firm ID	42

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Current assets
Cash and cash equivalents	$ 241	$ 405
Restricted cash	99	64
Accounts receivable (less allowances for doubtful accounts of $71 and $64, respectively)	878	1,127
Accrued utility revenues	33	23
Income taxes receivable	36	128
Inventories	433	665
Derivative instruments	75	865
Prepaid expenses	123	110
Held for sale assets	13	295
Other current assets	114	120
Total current assets	2,045	3,802
Property, plant and equipment
Non-utility	7,046	6,656
Utility	6,082	5,550
Total property, plant and equipment	13,128	12,206
Accumulated depreciation	(4,581)	(4,166)
Net property, plant, and equipment	8,547	8,040
Goodwill	3,027	3,612
Intangible assets, net	443	500
Utility regulatory assets	302	301
Derivative instruments	49	565
Other assets	988	755
Total assets	15,401	17,575
Current liabilities
Current maturities of long-term debt	57	149
Short-term borrowings	649	368
Accounts payable	613	891
Employee compensation and benefits accrued	142	147
Deposits and advances	232	225
Derivative instruments	60	144
Held for sale liabilities	16	19
Other current liabilities	505	501
Total current liabilities	2,274	2,444
Noncurrent liabilities
Long-term debt	6,543	6,483
Deferred income taxes	928	1,305
Derivative instruments	27	50
Other noncurrent liabilities	1,235	1,219
Total liabilities	11,007	11,501
Commitments and contingencies (Note 16)
UGI Corporation stockholders’ equity:
Preferred Stock, without par value (authorized 5,000,000 shares; issued 220,000 and 220,000 Series A shares, respectively)	167	162
UGI Common Stock, without par value (authorized – 450,000,000 shares; issued – 210,906,052 and 210,560,494 shares, respectively)	1,503	1,483
Retained earnings	3,027	4,841
Accumulated other comprehensive loss	(256)	(380)
Treasury stock, at cost	(55)	(40)
Total UGI Corporation stockholders’ equity	4,386	6,066
Noncontrolling interests	8	8
Total equity	4,394	6,074
Total liabilities and equity	$ 15,401	$ 17,575

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 71	$ 64
Preferred Stock, shares authorized (in shares)	5,000,000	5,000,000
Preferred Stock, shares issued (in shares)	220,000	220,000
Common Stock, shares authorized (in shares)	450,000,000	450,000,000
Common Stock, shares issued (in shares)	210,906,052	210,560,494

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Income Statement [Abstract]
Revenues	$ 8,928,000,000	$ 10,106,000,000	$ 7,447,000,000
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)	6,937,000,000	5,973,000,000	2,614,000,000
Operating and administrative expenses	2,158,000,000	2,028,000,000	2,014,000,000
Depreciation and amortization	532,000,000	518,000,000	502,000,000
Impairment of goodwill	656,000,000	0	0
Loss on disposal of UGI International energy marketing business	221,000,000	0	0
Other operating income, net	(132,000,000)	(79,000,000)	(33,000,000)
Total costs and expenses	10,372,000,000	8,440,000,000	5,097,000,000
Operating (loss) income	(1,444,000,000)	1,666,000,000	2,350,000,000
Income (loss) from equity investees	2,000,000	(14,000,000)	(63,000,000)
Loss on extinguishments of debt	(9,000,000)	(11,000,000)	0
Other non-operating (expense) income, net	(7,000,000)	75,000,000	12,000,000
Interest expense	(379,000,000)	(329,000,000)	(310,000,000)
(Loss) income before income taxes	(1,837,000,000)	1,387,000,000	1,989,000,000
Income tax benefit (expense)	335,000,000	(313,000,000)	(522,000,000)
Net (loss) income including noncontrolling interests	(1,502,000,000)	1,074,000,000	1,467,000,000
Deduct net income attributable to noncontrolling interests	0	(1,000,000)	0
Net (loss) income attributable to UGI Corporation	$ (1,502,000,000)	$ 1,073,000,000	$ 1,467,000,000
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ (7.16)	$ 5.11	$ 7.02
Diluted (in dollars per share)	$ (7.16)	$ 4.97	$ 6.92
Weighted-average common shares outstanding:
Basic (in shares)	209,806	209,940	209,063
Diluted (in shares)	209,806	215,821	212,126

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Statement of Comprehensive Income [Abstract]
Net (loss) income including noncontrolling interests	$ (1,502)	$ 1,074	$ 1,467
Net gains on derivative instruments (net of tax of $(9), $(27), and $(1), respectively)	16	64	3
Reclassifications of net (gains) losses on derivative instruments (net of tax of $13, $(1), and $(7), respectively)	(27)	6	18
Foreign currency translation adjustments (net of tax of $21, $(55), and $(4), respectively)	68	(193)	(11)
Foreign currency gains (losses) on long-term intra-company transactions	64	(148)	(12)
Benefit plans, principally actuarial gains (net of tax of $(2), $(10), and $(3), respectively)	5	28	7
Reclassifications of benefit plans actuarial (gains) losses and net prior service benefit (net of tax of $1, $(1), and $(1), respectively)	(2)	3	2
Other comprehensive income (loss)	124	(240)	7
Comprehensive (loss) income including noncontrolling interests	(1,378)	834	1,474
Deduct comprehensive income attributable to noncontrolling interests	0	(1)	0
Comprehensive (loss) income attributable to UGI Corporation	$ (1,378)	$ 833	$ 1,474

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Statement of Comprehensive Income [Abstract]
Net gains (losses) on derivative instruments, tax	$ (9)	$ (27)	$ (1)
Reclassifications of net losses on derivative instruments tax	13	(1)	(7)
Foreign currency translation adjustments, tax	21	(55)	(4)
Benefit plans, principally actuarial (losses) gains, tax	(2)	(10)	(3)
Reclassifications of benefit plans actuarial losses and net prior service benefit, tax	$ 1	$ (1)	$ (1)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income attributable to UGI Corporation	$ (1,502,000,000)	$ 1,074,000,000	$ 1,467,000,000
Adjustments to reconcile net (loss) income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization	532,000,000	518,000,000	502,000,000
Deferred income tax (benefit) expense, net	(420,000,000)	221,000,000	478,000,000
Provision for uncollectible accounts	69,000,000	61,000,000	36,000,000
Changes in unrealized gains and losses on derivative instruments	1,682,000,000	(648,000,000)	(1,398,000,000)
Impairment of assets	19,000,000	5,000,000	0
Loss on disposal of UGI International energy marketing business	221,000,000	0	0
Impairment of goodwill	656,000,000	0	0
Equity-based compensation expense	17,000,000	15,000,000	21,000,000
Loss on extinguishments of debt	9,000,000	11,000,000	0
(Income) loss from equity investees	(2,000,000)	14,000,000	63,000,000
Settlement of Energy Services interest rate swap, net of amortization	19,000,000	0	0
Gain on sale of fixed assets	(61,000,000)	(33,000,000)	(11,000,000)
Other, net	19,000,000	31,000,000	42,000,000
Net change in:
Accounts receivable and accrued utility revenues	212,000,000	(431,000,000)	(233,000,000)
Income taxes receivable	91,000,000	0	(48,000,000)
Inventories	247,000,000	(224,000,000)	(231,000,000)
Utility deferred fuel costs, net of changes in unsettled derivatives	64,000,000	(24,000,000)	(22,000,000)
Accounts payable	(291,000,000)	85,000,000	366,000,000
Derivative instruments collateral (paid) received	(420,000,000)	(9,000,000)	472,000,000
Other current assets	(36,000,000)	54,000,000	(10,000,000)
Other current liabilities	(18,000,000)	(4,000,000)	(13,000,000)
Net cash provided by operating activities	1,107,000,000	716,000,000	1,481,000,000
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(974,000,000)	(804,000,000)	(690,000,000)
Acquisitions of businesses and assets, net of cash and restricted cash acquired	(9,000,000)	(242,000,000)	(397,000,000)
Investments in equity method investees	(146,000,000)	(47,000,000)	(65,000,000)
Settlements of net investment hedges	22,000,000	26,000,000	0
Net proceeds from the disposition of businesses and assets	30,000,000	44,000,000	39,000,000
Other, net	0	11,000,000	0
Net cash used by investing activities	(1,077,000,000)	(1,012,000,000)	(1,113,000,000)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(308,000,000)	(296,000,000)	(282,000,000)
Issuances of debt, net of discount and issuance costs	1,930,000,000	1,257,000,000	656,000,000
Repayments of debt and finance leases, including redemption premiums	(2,031,000,000)	(978,000,000)	(405,000,000)
Receivables Facility net borrowings (repayments)	46,000,000	0	(19,000,000)
Increase (decrease) in short-term borrowings	221,000,000	1,000,000	(16,000,000)
Issuances of preferred stock, net of issuance costs	0	0	213,000,000
Issuances of UGI Common Stock	12,000,000	19,000,000	19,000,000
Repurchases of UGI Common Stock	(22,000,000)	(38,000,000)	0
Payments on Purchase Contracts	(16,000,000)	(16,000,000)	0
Net cash (used) provided by financing activities	(168,000,000)	(51,000,000)	166,000,000
Effect of exchange rate changes on cash, cash equivalents and restricted cash	9,000,000	(61,000,000)	(14,000,000)
Cash, cash equivalents and restricted cash (decrease) increase	(129,000,000)	(408,000,000)	520,000,000
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of year	340,000,000	469,000,000	877,000,000
Cash, cash equivalents and restricted cash at beginning of year	469,000,000	877,000,000	357,000,000
Cash, cash equivalents and restricted cash (decrease) increase	(129,000,000)	(408,000,000)	520,000,000
Cash paid (received) for:
Interest	332,000,000	320,000,000	297,000,000
Income taxes	$ (17,000,000)	$ 61,000,000	$ 96,000,000

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($)	Total	Total UGI Corporation stockholders’ equity	Preferred stock, without par value	Preferred stock, without par value Cumulative effect of change in accounting - ASU 2020-06 (Note 3)	Common stock, without par value	Common stock, without par value Cumulative effect of change in accounting - ASU 2020-06 (Note 3)	Retained earnings	Retained earnings Cumulative effect of change in accounting - ASU 2020-06 (Note 3)	Accumulated other comprehensive income (loss)	Treasury stock	Noncontrolling interests
Balance, beginning of year at Sep. 30, 2020					$ 1,416,000,000		$ 2,908,000,000		$ (147,000,000)	$ (49,000,000)	$ 9,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of preferred stock			$ 213,000,000		(45,000,000)
Other					(2,000,000)
Common Stock issued in connection with employee and director plans, net of tax withheld					9,000,000
Equity-based compensation expense					16,000,000
Net (loss) income attributable to UGI Corporation	$ 1,467,000,000						1,467,000,000
Cash dividends on common stock ($1.47, $1.41, and $1.35 per share, respectively)							(282,000,000)
Losses on treasury stock transactions in connection with employee and director plans							(12,000,000)
Net gains on derivative instruments	3,000,000								3,000,000
Reclassification of net (gains) losses on derivative instruments	18,000,000								18,000,000
Benefit plans, principally actuarial gains	7,000,000								7,000,000
Reclassification of benefit plans net actuarial (gains) losses and net prior service benefits	2,000,000								2,000,000
Foreign currency gains (losses) on long-term intra-company transactions	(12,000,000)								(12,000,000)
Foreign currency translation adjustments	(11,000,000)								(11,000,000)
Common Stock issued in connection with employee and director plans, net of tax withheld										24,000,000
Repurchases of common stock	0
Reacquired common stock – employee and director plans										(1,000,000)
Net income attributable to noncontrolling interests	1,467,000,000
Balance, end of year at Sep. 30, 2021	5,531,000,000	$ 5,522,000,000	213,000,000		1,394,000,000		4,081,000,000		(140,000,000)	(26,000,000)	9,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other			(51,000,000)		53,000,000						(2,000,000)
Common Stock issued in connection with employee and director plans, net of tax withheld					19,000,000
Equity-based compensation expense					17,000,000
Net (loss) income attributable to UGI Corporation	1,073,000,000						1,073,000,000
Cash dividends on common stock ($1.47, $1.41, and $1.35 per share, respectively)							(296,000,000)
Losses on treasury stock transactions in connection with employee and director plans							(17,000,000)
Net gains on derivative instruments	64,000,000								64,000,000
Reclassification of net (gains) losses on derivative instruments	6,000,000								6,000,000
Benefit plans, principally actuarial gains	28,000,000								28,000,000
Reclassification of benefit plans net actuarial (gains) losses and net prior service benefits	3,000,000								3,000,000
Foreign currency gains (losses) on long-term intra-company transactions	(148,000,000)								(148,000,000)
Foreign currency translation adjustments	(193,000,000)								(193,000,000)
Common Stock issued in connection with employee and director plans, net of tax withheld										34,000,000
Repurchases of common stock										(38,000,000)
Reacquired common stock – employee and director plans										(10,000,000)
Net income attributable to noncontrolling interests	1,074,000,000										1,000,000
Balance, end of year at Sep. 30, 2022	6,074,000,000	6,066,000,000	162,000,000	$ 5,000,000	1,483,000,000	$ (6,000,000)	4,841,000,000	$ 1,000,000	(380,000,000)	(40,000,000)	8,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock issued in connection with employee and director plans, net of tax withheld					8,000,000
Equity-based compensation expense					18,000,000
Net (loss) income attributable to UGI Corporation	(1,502,000,000)						(1,502,000,000)
Cash dividends on common stock ($1.47, $1.41, and $1.35 per share, respectively)							(308,000,000)
Losses on treasury stock transactions in connection with employee and director plans							(5,000,000)
Net gains on derivative instruments	16,000,000								16,000,000
Reclassification of net (gains) losses on derivative instruments	(27,000,000)								(27,000,000)
Benefit plans, principally actuarial gains	5,000,000								5,000,000
Reclassification of benefit plans net actuarial (gains) losses and net prior service benefits	(2,000,000)								(2,000,000)
Foreign currency gains (losses) on long-term intra-company transactions	64,000,000								64,000,000
Foreign currency translation adjustments	68,000,000								68,000,000
Common Stock issued in connection with employee and director plans, net of tax withheld										7,000,000
Repurchases of common stock										(22,000,000)
Net income attributable to noncontrolling interests	(1,502,000,000)
Balance, end of year at Sep. 30, 2023	$ 4,394,000,000	$ 4,386,000,000	$ 167,000,000		$ 1,503,000,000		$ 3,027,000,000		$ (256,000,000)	$ (55,000,000)	$ 8,000,000

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Statement of Stockholders' Equity [Abstract]
Accounting Standards Update [Extensible List]		Accounting Standards Update 2020-06 [Member]
Cash dividends on common stock (in dollars per share)	$ 1.47	$ 1.41	$ 1.35

Nature of Operations

Nature of Operations	12 Months Ended
	Sep. 30, 2023
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., we own and operate (1) a retail propane marketing and distribution business; (2) natural gas and electric distribution utilities; and (3) energy marketing, midstream infrastructure, storage, natural gas gathering and processing, natural gas production, electricity generation and energy services businesses. In Europe, we market and distribute propane and other LPG, and market other energy products and services. We conduct a domestic propane marketing and distribution business through AmeriGas Partners. AmeriGas Partners conducts its propane marketing and distribution business through its principal operating subsidiary AmeriGas OLP. UGI International, LLC, through its subsidiaries and affiliates, conducts (1) an LPG distribution business throughout much of Europe and (2) an energy marketing business in France and the Netherlands and, prior to its sales in Fiscal 2023, in Belgium and the United Kingdom. These businesses are conducted principally through our subsidiaries, UGI France, Flaga, AvantiGas, DVEP and UniverGas. See Note 5 for additional information regarding the UGI International energy marketing business. 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. 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

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Sep. 30, 2023
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 2 — Summary of Significant Accounting Policies Basis of Presentation Our consolidated financial statements are prepared in accordance with GAAP. 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. Principles of Consolidation The consolidated financial statements include the accounts of UGI and its controlled subsidiary companies which are majority owned. We report outside ownership interests in other consolidated but less than 100%-owned subsidiaries, as noncontrolling interests. We eliminate intercompany accounts and transactions when we consolidate. 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. See Note 21 for additional information on our equity method investments. Investments in equity securities related to entities in which we do not have significant influence over operating and financial policies are generally initially valued at their cost less impairment (if any) and subsequently remeasured at fair value, as applicable, in accordance with the relevant provisions under GAAP. Effects of Regulation Certain of our subsidiaries account for the financial effects of regulation in accordance with ASC 980. In accordance with this guidance, incurred costs that would otherwise be charged to expense are capitalized and recorded as regulatory assets when it is probable that the incurred costs will be recovered through rates in the future. Similarly, we recognize regulatory liabilities when it is probable that regulators will require customer refunds through future rates or when revenue is collected from customers for expenditures that have not yet been incurred. Regulatory assets and liabilities are classified as current if, upon initial recognition, the entire amount related to that item will be recovered or refunded within a year of the balance sheet date. Generally, regulatory assets and regulatory liabilities are amortized into expense and income over the periods authorized by the respective regulatory body. For additional information regarding the effects of rate regulation on our utility operations, see Note 9. Fair Value Measurements The Company applies fair value measurements on a recurring and, as otherwise required under ASC 820, on a nonrecurring basis. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Fair value measurements performed on a recurring basis principally relate to derivative instruments and investments held in supplemental executive retirement plan grantor trusts. ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels. The hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). A level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels: • Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date. • Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. • Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. Fair value is based upon assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. We evaluate the need for credit adjustments to our derivative instrument fair values. These credit adjustments were not material to the fair values of our derivative instruments. Derivative Instruments Derivative instruments are reported on the Consolidated Balance Sheets at their fair values, unless the NPNS exception is elected. The accounting for changes in fair value depends upon the purpose of the derivative instrument, whether it is subject to regulatory ratemaking mechanisms or if it qualifies and is designated as a hedge for accounting purposes. Certain of our derivative instruments qualify and are designated as cash flow hedges. For cash flow hedges, changes in the fair values of the derivative instruments are recorded in AOCI, to the extent effective at offsetting changes in the hedged item, until earnings are affected by the hedged item. We discontinue cash flow hedge accounting if occurrence of the forecasted transaction is determined to be no longer probable. Hedge accounting is also discontinued for derivatives that cease to be highly effective. We do not designate our commodity and certain foreign currency derivative instruments as hedges under GAAP. Changes in the fair values of these derivative instruments are reflected in net income. Gains and losses on substantially all of the commodity derivative instruments used by Utilities are included in regulatory assets or liabilities because it is probable such gains or losses will be recoverable from, or refundable to, customers. From time to time, we also enter into net investment hedges. Gains and losses on net investment hedges that relate to our foreign operations are included in the cumulative translation adjustment component in AOCI until such foreign net investment is substantially sold or liquidated. Cash flows from derivative instruments, other than certain net investment hedges, are included in cash flows from operating activities on the Consolidated Statements of Cash Flows. Cash flows from net investment hedges are included in cash flows from investing activities on the 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 18. Business Combination Purchase Price Allocations From time to time, the Company enters into material business combinations. The purchase price is allocated to the various assets acquired and liabilities assumed at their estimated fair value as of the acquisition date with the residual of the purchase price allocated to goodwill. Fair values of assets acquired and liabilities assumed are based upon available information. Estimating fair values is generally subject to significant judgment, estimates and assumptions especially with respect to intangible assets. The allocation of the purchase price may be modified up to one year after the acquisition date, under certain circumstances, as more information is obtained about the fair value of assets acquired and liabilities assumed. Foreign Currency Translation Balance sheets of international subsidiaries are translated into USD using the exchange rate at the balance sheet date. Income statements and equity investee results are translated into USD using an average exchange rate for each reporting period. Where the local currency is the functional currency, translation adjustments are recorded in other comprehensive income. Transactions denominated in currencies other than the functional currency are recorded based on exchange rates at the time such transactions arise with the impact of subsequent changes in such rates reflected in the income statement. The functional currency of a significant portion of our international operations is the euro. Revenue Recognition In accordance with ASC 606, 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. Certain revenues such as revenue from leases, financial instruments and other revenues are not within the scope of ASC 606 because they are not from contracts with customers. Such revenues are accounted for in accordance with other GAAP. Revenue-related taxes collected on behalf of customers and remitted to taxing authorities, principally sales and use taxes, are not included in revenues. Gross receipts taxes at Midstream & Marketing, Mountaineer and Electric Utility are presented on a gross basis. The Company has elected to use the practical expedient to expense the costs to obtain contracts when incurred for contracts that have a term less than one year. The costs incurred to obtain contracts that have durations of longer than one year are not material. See Note 4 for additional disclosures regarding the Company’s revenue from contracts with customers. Accounts Receivable Accounts receivable are reported on the Consolidated Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. Provisions for uncollectible accounts are established based upon our collection experience, the assessment of the collectability of specific amounts and the Company’s best estimate of current expected credit losses. Accounts receivable are written off in the period in which the receivable is deemed uncollectible. LPG Delivery Expenses Expenses associated with the delivery of LPG to customers of the Partnership and our UGI International operations (including vehicle expenses, expenses of delivery personnel, vehicle repair and maintenance and general liability expenses) are classified as “Operating and administrative expenses” on the Consolidated Statements of Income. Depreciation expense associated with the Partnership and UGI International delivery vehicles is classified in “Depreciation and amortization” on the Consolidated Statements of Income. Income Taxes AmeriGas Partners and AmeriGas OLP are not directly subject to federal income taxes. Instead, their taxable income or loss is allocated to the individual partners. We record income taxes on (1) our share of the Partnership’s current taxable income or loss and (2) the differences between the book and tax basis of our investment in the Partnership. AmeriGas OLP has subsidiaries which operate in corporate form and are directly subject to federal and state income taxes. Legislation in certain states allows for taxation of partnership income and the accompanying financial statements reflect state income taxes resulting from such legislation. Utilities records deferred income taxes in the Consolidated Statements of Income resulting from the use of accelerated tax depreciation methods based upon amounts recognized for ratemaking purposes. Utilities also records a deferred income tax liability for tax benefits, principally the result of accelerated tax depreciation for state income tax purposes, that are flowed through to ratepayers when temporary differences originate and records a regulatory income tax asset for the probable increase in future revenues that will result when the temporary differences reverse. We are amortizing deferred investment tax credits related to UGI Utilities’ plant additions over the service lives of the related property. UGI Utilities reduces its deferred income tax liability for the future tax benefits that will occur when investment tax credits, which are not taxable, are amortized. We also reduce the regulatory income tax asset for the probable reduction in future revenues that will result when such deferred investment tax credits amortize. Investment tax credits associated with Midstream & Marketing’s qualifying renewable natural gas property under the Inflation Reduction Act of 2022 are reflected in income taxes. We record interest on underpayments and overpayments of income taxes, and income tax penalties, in “Income tax benefit (expense)” on the Consolidated Statements of Income. Interest income or expense recognized was not material for all periods presented. Earnings Per Common Share Basic earnings per share attributable to UGI Corporation stockholders reflect the weighted-average number of common shares outstanding. Diluted earnings per share attributable to UGI Corporation 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: (Thousands of shares) 2023 2022 2021 Weighted-average common shares outstanding for basic computation 209,806 209,940 209,063 Incremental shares issuable for stock options, common stock awards and Equity Units (a) (b) — 5,881 3,063 Weighted-average common shares outstanding for diluted computation 209,806 215,821 212,126 (a) Includes the impact of common shares assumed to be outstanding under the if-converted method in connection with the May 2021 issuance of Equity Units (see Note 13). (b) For Fiscal 2023, 6,132 of such shares have been excluded as such incremental shares would be antidilutive due to the net loss for the period. For Fiscal 2022 and Fiscal 2021, 8,138 shares and 5,267 shares, respectively, associated with outstanding stock option awards were excluded from the computation of diluted earnings per share because their effect was antidilutive. Cash, Cash Equivalents and Restricted Cash Cash and cash equivalents include cash on hand, cash in banks and highly liquid investments with maturities of three months or less when purchased. 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 Consolidated Balance Sheets to the corresponding amounts reported on the Consolidated Statements of Cash Flows. 2023 2022 2021 Cash and cash equivalents $ 241 $ 405 $ 855 Restricted cash 99 64 22 Cash, cash equivalents and restricted cash $ 340 $ 469 $ 877 Inventories Our inventories are stated at the lower of cost or net realizable value. We determine cost using an average cost method for non-utility LPG and natural gas and utility inventories; specific identification for appliances; and the FIFO method for all other inventories. The Company accounts for renewable energy certificates as inventory, which generally represents costs incurred to generate a certificate for sale. The Company recognizes revenue from the sale of renewable energy certificates when control of the certificate is transferred to the buyer, and the cost of the certificate, if any, is then recorded within “Cost of sales” on the Consolidated Statements of Income. Property, Plant and Equipment and Related Depreciation We record property, plant and equipment at the lower of original cost or fair value, if impaired. Capitalized costs include labor, materials and other direct and indirect costs, and for certain operations subject to cost-of-service rate regulation, AFUDC. We also include in property, plant and equipment costs associated with computer software we develop or obtain for use in our businesses. The amounts assigned to property, plant and equipment of acquired businesses are based upon estimated fair value at date of acquisition. When we retire or otherwise dispose of non-utility plant and equipment, we eliminate the associated cost and accumulated depreciation and recognize any resulting gain or loss in "Other operating income, net" on the Consolidated Statements of Income. For property subject to cost of service rate regulation, upon retirement we charge the original cost to accumulated depreciation for financial accounting purposes. Costs incurred to retire UGI Utilities plant and equipment, net of salvage, are recorded in regulatory assets and amortized over five years, consistent with prior ratemaking treatment. We record depreciation expense on non-utility plant and equipment on a straight-line basis over estimated economic useful lives. We record depreciation expense for Utilities’ plant and equipment on a straight-line basis based upon the projected service lives of the various classes of its depreciable property. We classify amortization of computer software and related IT system installation costs included in property, plant and equipment as depreciation expense. No depreciation expense is included in cost of sales on the Consolidated Statements of Income. Goodwill and Intangible Assets Intangible Assets. We amortize intangible assets over their estimated useful lives unless we determine their lives to be indefinite. Estimated useful lives of definite-lived intangible assets, primarily consisting of customer relationships. We test definite-lived intangible assets for impairment whenever events or changes in circumstances indicate that the associated carrying amounts may be impaired. Determining whether an impairment loss occurred requires comparing the carrying amount to the estimated fair value of the asset in accordance with ASC 820. Intangible assets with indefinite lives are not amortized but are tested for impairment annually (and more frequently if events or changes in circumstances between annual tests indicate that it is more likely than not that they are impaired) and written down to fair value, if impaired. See Note 12 for additional information related to intangible asset impairments recognized in Fiscal 2023 and Fiscal 2021. 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. For certain of our reporting units with goodwill, we assess qualitative factors to determine whether it is more likely than not that the fair value of such reporting unit is less than its carrying amount. For our other reporting units with goodwill, we bypass the qualitative assessment and perform the quantitative assessment by comparing the fair values of the reporting units with their carrying amounts, including goodwill. If the carrying amount of a reporting unit exceeds its fair value, an impairment loss is recognized in an amount equal to such excess but not to exceed the total amount of the goodwill of the reporting unit. During the third quarter of Fiscal 2023, the Company identified interim impairment indicators at its AmeriGas Propane reporting unit and, as such, performed an interim impairment test of its goodwill as of May 31, 2023. Based on such impairment test, the Company recognized a non-cash pre-tax goodwill impairment charge of $656. See Note 12 for additional information. With respect to UGI International's Fiscal 2023 goodwill impairment test, the Company bypassed the qualitative assessment and performed a quantitative assessment. Such assessment used a weighting of income and market approaches to determine fair value. With respect to the income approach, management used a discounted cash flow (“DCF”) method, using unobservable inputs. The significant assumptions in our DCF model include projected EBITDA, and a discount rate (and estimates in the discount rate inputs). With respect to the market approach, management used recent transaction market multiples for similar companies. Based on our evaluation, 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 is approximately $911 of goodwill in this reporting unit as of September 30, 2023. The Company will continue to monitor its reporting units and related goodwill for any possible future non-cash impairment charges. Accumulated goodwill impairment was $656 at September 30, 2023. There were no accumulated goodwill impairment losses at September 30, 2022. Except for the previously mentioned impairment charge of $656 at the AmeriGas Propane reporting unit, there were no other impairments of goodwill recognized in all periods presented. Impairment of Long-Lived Assets Impairment testing for long-lived assets (or an asset group) is required when circumstances indicate that such assets may be impaired. If it is determined that a triggering event has occurred, we perform a recoverability test based upon estimated undiscounted cash flow projections expected to be realized over the remaining useful life of the long-lived asset. If the undiscounted cash flows used in the recoverability test are less than the long-lived asset's carrying amount, we determine its fair value. If the fair value is determined to be less than its carrying amount, the long-lived asset is reduced to its estimated fair value and an impairment loss is recognized in an amount equal to such shortfall. When determining whether a long-lived asset has been impaired, management groups assets at the lowest level that has identifiable cash flows that are independent of other assets. The impairment of AmeriGas Propane’s goodwill during the quarter ended June 30, 2023, was determined to be a triggering event requiring an interim impairment analysis of AmeriGas Propane’s long-lived and definite lived intangible assets. Accordingly, the Company performed a recoverability test of AmeriGas Propane’s long-lived assets, including right-of-use (“ROU”) assets and definite lived intangible assets, as of May 31, 2023, using estimated undiscounted cash flow projections expected to be generated over the remaining useful life of the primary asset of the asset group at the lowest level with identifiable cash flows that are independent of other assets. Based on the recoverability test performed, we determined that (1) AmeriGas Propane’s long-lived assets, including ROU assets and definite lived intangible assets, were recoverable and, as such, no impairment charges were recorded; and (2) no adjustments to the remaining useful lives were necessary. No material provisions for impairments of long-lived assets were recorded for all periods presented. Refundable Tank and Cylinder Deposits Included in “Other noncurrent liabilities” on our Consolidated Balance Sheets are customer paid deposits on tanks and cylinders primarily owned by subsidiaries of UGI France of $249 and $243 at September 30, 2023 and 2022, respectively. Deposits are refundable to customers when the tanks or cylinders are returned in accordance with contract terms. Environmental Matters We are subject to environmental laws and regulations intended to mitigate or remove the effects of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current or former operating sites. Environmental reserves are accrued when assessments indicate that it is probable that a liability has been incurred and an amount can be reasonably estimated. Amounts recorded as environmental liabilities on the Consolidated Balance Sheets represent our best estimate of costs expected to be incurred or, if no best estimate can be made, the minimum liability associated with a range of expected environmental investigation and remediation costs. These estimates are based upon a number of factors including whether the Company will be responsible for such remediation, the scope and cost of the remediation work to be performed, the portion of costs that will be shared with other potentially responsible parties, the timing of the remediation and possible impact of changes in technology, and the regulations and requirements of local governmental authorities. Our estimated liability for environmental contamination is reduced to reflect anticipated participation of other responsible parties but is not reduced for possible recovery from insurance carriers. Under GAAP, if the amount and timing of cash payments associated with environmental investigation and cleanup are reliably determinable, such liabilities are discounted to reflect the time value of money. We intend to pursue recovery of incurred costs through all appropriate means, including regulatory relief. PA Gas Utility receives ratemaking recognition of environmental investigation and remediation costs associated with in-state environmental sites. This ratemaking recognition balances the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. For further information, see Note 16. Loss Contingencies Subject to Insurance We are subject to risk of loss for general, automobile and product liability, and workers’ compensation claims for which we obtain insurance coverage under insurance policies that are subject to self-insured retentions or deductibles. In accordance with GAAP, we record accruals when it is probable that a liability exists and the amount or range of amounts can be reasonably estimated. When no amount within a range of possible loss is a better estimate than any other amount within the range, liabilities recorded are based upon the low end of the range. For litigation and pending claims including those covered by insurance policies, the analysis of probable loss is performed on a case by case basis and includes an evaluation of the nature of the claim, the procedural status of the matter, the probability or likelihood of success in prosecuting or defending the claim, the information available with respect to the claim, the opinions and views of outside counsel and other advisors, and past experience in similar matters. With respect to unasserted claims arising from unreported incidents, we may use the work of specialists to estimate the ultimate losses to be incurred using actuarially determined loss development factors applied to actual claims data. Our estimated reserves for loss contingencies may differ materially from the ultimate liability and such reserves may change materially as more information becomes available and estimated reserves are adjusted. We maintain insurance coverage such that our net exposure for claims covered by insurance would be limited to the self-insured retentions or deductibles, claims above which would be paid by the insurance carrier. For such claims, we record a receivable related to the amount of the liability expected to be paid by insurance. Employee Retirement Plans We use a market-related value of plan assets and an expected long-term rate of return to determine the expected return on assets of our U.S. pension and other postretirement plans. The market-related value of plan assets, other than equity investments, is based upon fair values. The market-related value of equity investments is calculated by rolling forward the prior-year’s market-related value with contributions, disbursements and the expected return on plan assets. One third of the difference between the expected and the actual value is then added to or subtracted from the expected value to determine the new market-related value (see Note 8).

Accounting Changes

Accounting Changes	12 Months Ended
	Sep. 30, 2023
Accounting Standards Update and Change in Accounting Principle [Abstract]
Accounting Changes	Note 3 — Accounting Changes New Accounting Standard Adopted in Fiscal 2023 Debt and Derivatives and Hedging . Effective October 1, 2022, the Company adopted ASU 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40),” using the modified retrospective approach. The amendments in this ASU affect entities that issue convertible instruments and/or contracts indexed to and potentially settled in an entity’s own equity. This ASU reduces the number of accounting models for convertible debt instruments and convertible preferred stock, expands disclosure requirements for convertible instruments, and simplifies the related earnings per share guidance. The adoption of the new guidance did not have a material impact on our consolidated financial statements.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
	Sep. 30, 2023
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. The Company generally has the right to consideration from a customer in an amount that corresponds directly with the value to the customer for performance completed to date. As such, we have elected to recognize revenue in the amount to which we have a right to invoice except in the case of certain of Utilities’ large delivery service customers and Midstream & Marketing’s peaking contracts for which we recognize revenue on a straight-line basis over the term of the contract, consistent with when the performance obligations are satisfied by the Company. We do not have a significant financing component in our contracts because we receive payment shortly before, at, or shortly after the transfer of control of the good or service. Because the period between the time the performance obligation is satisfied and payment is received is generally one year or less, the Company has elected to apply the significant financing component practical expedient and no amount of consideration has been allocated as a financing component. The Company’s revenues from contracts with customers are discussed below. Utility Revenues Utilities supplies natural gas and electricity and provides distribution services of natural gas and electricity to residential, commercial, and industrial customers who are generally billed at standard regulated tariff rates approved by the regulatory bodies through the ratemaking process. Tariff rates include a component that provides for a reasonable opportunity to recover operating costs and expenses and to earn a return on net investment, and a component that provides for the recovery, subject to reasonableness reviews, of PGC, PGA and DS costs. Customers may choose to purchase their natural gas and electricity from Utilities, or, alternatively, may contract separately with alternate suppliers. Accordingly, our contracts with customers comprise two promised goods or services: (1) delivery service of natural gas and electricity through the Company’s utility distribution systems and (2) the natural gas or electricity commodity itself for those customers who choose to purchase the natural gas or electricity directly from the Company. Revenue is not recorded for the sale of natural gas or electricity to customers who have contracted separately with alternate suppliers. For those customers who choose to purchase their natural gas or electricity from the Company, the performance obligation includes both the supply of the commodity and the delivery service. The terms of our core market customer contracts are generally considered day-to-day as customers can discontinue service at any time without penalty. Performance obligations are generally satisfied over time as the natural gas or electricity is delivered to customers, at which point the customers simultaneously receive and consume the benefits provided by the delivery service and, when applicable, the commodity. Amounts are billed to customers based upon the reading of a customer’s meter, which occurs on a cycle basis throughout each reporting period. An unbilled amount is recorded at the end of each reporting period based upon estimated amounts of natural gas or electricity delivered to customers since the date of the last meter reading. These unbilled estimates consider various factors such as historical customer usage patterns, customer rates and weather. Utilities has certain fixed-term contracts with large commercial and industrial customers to provide natural gas delivery services at contracted rates and at volumes generally based on the customer’s needs. The performance obligation to provide the contracted delivery service for these large commercial and industrial customers is satisfied over time and revenue is generally recognized on a straight-line basis. Utilities makes off-system sales whereby natural gas delivered to our system in excess of amounts needed to fulfill our distribution system needs is sold to other customers, primarily other distributors of natural gas, based on an agreed-upon price and volume between the Company and the counterparty. Utilities also sells excess natural gas capacity whereby interstate pipeline capacity in excess of amounts needed to meet our customer obligations is sold to other distributors of natural gas based upon an agreed-upon rate. Off-system sales and capacity releases are generally entered into one month at a time and comprise the sale of a specific volume of gas or pipeline capacity at a specific delivery point or points over a specific time. As such, performance obligations associated with off-system sales and capacity release customers are satisfied, and associated revenue is recorded, when the agreed upon volume of natural gas is delivered or capacity is provided, and title is transferred, in accordance with the contract terms. Electric Utility provides transmission services to PJM by allowing PJM to access Electric Utility’s electricity transmission facilities. In exchange for providing access, PJM pays Electric Utility consideration determined by a formula-based rate approved by the FERC. The formula-based rate, which is updated annually, allows recovery of costs incurred to provide transmission services and return on transmission-related net investment. We recognize revenue over time as we provide transmission service. Other Utility revenues represent revenues from other ancillary services provided to customers and are generally recorded as the service is provided to customers. Non-Utility Revenues LPG . AmeriGas Propane and UGI International record revenue principally from the sale of LPG to retail and wholesale customers. The primary performance obligation associated with the sale of LPG is the delivery of LPG to (1) the customer’s point of delivery for retail customers and (2) the customer’s specified location where LPG is picked up by wholesale customers, at which point control of the LPG is transferred to the customer, the performance obligation is satisfied, and the associated revenue is recognized. Contracts with customers comprise different types of contracts with varying length terms, fixed or variable prices, and fixed or variable quantities. Contracts with our residential customers, which comprise a substantial number of our customer contracts, are generally one year or less. Customer contracts for the sale of LPG include fixed-price, fixed-quantity contracts under which LPG is provided to customers at a fixed price and a fixed volume, and contracts that provide for the sale of LPG at market prices at date of delivery with no fixed volumes. AmeriGas Propane offers contracts that permit customers to lock in a fixed price for their volumes for a fee and also provide customers with the option to pre-buy a fixed amount of LPG at a fixed price. Amounts received under pre-buy arrangements are recorded as a contract liability when received and recorded as revenue when LPG is delivered and control is transferred to the customer. Fee revenue associated with fixed-price contracts are recorded as contract liabilities and recorded ratably over the contract period. AmeriGas Propane and UGI International also distribute LPG to customers in portable cylinders. Under certain contracts, filled cylinders are delivered, and control is transferred, to a reseller. In such instances, the reseller is our customer and we record revenue upon delivery to the reseller. Under other contracts, filled cylinders are delivered to a reseller, but the Company retains control of the cylinders. In such instances, we record revenue at the time the reseller transfers control of the cylinder to the end user. Certain retail LPG customers for AmeriGas Propane receive credits which we account for as variable consideration. We estimate these credits based upon past practices and historical customer experience and we reduce our revenues recognized for these credits. Energy Marketing. Midstream & Marketing and UGI International operate energy marketing businesses that sell energy commodities, principally natural gas and electricity, to residential, commercial, industrial and wholesale customers. See Note 5 regarding recent transactions related to UGI International’s energy marketing business. Midstream & Marketing and UGI International market natural gas and electricity on full-requirements or agreed-upon volume bases under contracts with varying length terms and at fixed or floating prices that are based on market indices adjusted for differences in price between the market location and delivery locations. Performance obligations associated with these contracts primarily comprise the delivery of the natural gas and electricity over a contractual period of time. Performance obligations also include other energy-related ancillary services provided to customers such as capacity. For performance obligations that are satisfied at a point in time such as the delivery of natural gas, revenue is recorded when customers take control of the natural gas. Revenue is recorded for performance obligations that qualify as a series, when customers consume the natural gas or electricity is delivered, which corresponds to the amount invoiced to the customer. For transactions where the price or volume is not fixed, the transaction price is not determined until delivery occurs. The billed amount, and the revenue recorded, is based upon consumption by the customer. Midstream. Midstream & Marketing provides natural gas pipeline transportation, natural gas gathering, natural gas processing and natural gas underground storage services, which generally contain a performance obligation for the Company to have availability to transport or store a product. Additionally, the Company provides stand-ready services to sell supplemental energy products and related services, primarily LNG and propane-air mixtures during periods of high demand that typically result from cold weather. The Company also sells LNG to end-user customers for use by trucks, drilling rigs and other motored vehicles and equipment, and facilities that are located off the natural gas grid. Contracts for natural gas transportation and gathering services are typically long-term contracts with terms of up to 30 years, while contracts for storage are typically for one-year or multiple storage season periods. Contracts to provide natural gas during periods of high demand have terms of up to 15 years. Contracts to sell LNG for trucks, drilling rigs and other motor vehicles and facilities are typically short-term (less than one year). Depending on the type of services provided or goods sold, midstream revenues may consist of demand rates, commodity rates, and transportation rates and may include other fees for ancillary services. Pipeline transportation, natural gas gathering and storage services provided and services to stand ready to sell supplemental energy products and services each are considered to have a single performance obligation satisfied through the passage of time ratably based upon providing a stand-ready service generally on a monthly basis. Contracts to sell LNG to end-user customers contain performance obligations to deliver LNG over the term of the contract and revenue is recognized at a point in time when the control of the energy products is transferred to the customer. The price in the contract corresponds to our efforts to satisfy the performance obligation and reflects the consideration we expect to receive for the satisfied performance obligation, and, therefore, the revenue is recognized based on the volume delivered and the price within the contract. In cases where shipping and handling occurs prior to the LNG being delivered to the customer’s storage vessel, we have elected to treat this as a cost of fulfillment and not a separate performance obligation. Revenues are typically billed and payment received monthly. Advance fees received from customers for stand-ready services are deferred as contract liabilities and revenue is recognized ratably over time as the performance obligation is satisfied over a period less than one year. Electricity Generation. Midstream & Marketing sells power generated from electricity generation assets in the wholesale electricity markets administered by PJM regional transmission organization. Power contracts with PJM consist of the sale of power, capacity and ancillary services, all of which are considered a bundle of various services. Performance obligations are satisfied over time, generally on a daily basis, as electricity is delivered to and simultaneously consumed by the customer. As such, the Company has elected to recognize revenue in the amount to which we have a right to invoice which is based on market prices at the time of the delivery of the electricity to the customers. Other. Other revenues from contracts with customers are generated primarily from AmeriGas Propane’s parts and services business. The performance obligations of this business include installation and repair services. The performance obligations under these contracts are satisfied, and revenue is recognized, as control of the product is transferred or the services are rendered. Other LPG revenues from contracts with customers are generated primarily from certain fees AmeriGas Propane and UGI International charge associated with the delivery of LPG, including hazmat safety compliance, inspection, metering, installation, fuel recovery and certain other services. Revenues from fees are typically recorded when the LPG is delivered to the customer or the associated service is completed. Revenue Disaggregation The following tables present our disaggregated revenues by reportable segment during Fiscal 2023, Fiscal 2022 and Fiscal 2021: 2023 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 1,020 $ — $ — $ — $ — $ 1,020 $ — Commercial & Industrial 413 — — — — 413 — Large delivery service 177 — — — — 177 — Off-system sales and capacity releases 89 (73) — — — 162 — Other 43 (1) — — — 44 — Total Utility 1,742 (74) — — — 1,816 — Non-Utility: LPG: Retail 3,952 — 2,184 1,768 — — — Wholesale 325 — 118 207 — — — Energy Marketing 2,139 (143) — 872 1,410 — — Midstream: Pipeline 251 — — — 251 — — Peaking 31 (106) — — 137 — — Other 14 — — — 14 — — Electricity Generation 33 — — — 33 — — Other 274 — 194 80 — — — Total Non-Utility 7,019 (249) 2,496 2,927 1,845 — — Total revenues from contracts with customers 8,761 (323) 2,496 2,927 1,845 1,816 — Other revenues (b)(c) 167 (3) 85 38 2 38 7 Total revenues $ 8,928 $ (326) $ 2,581 $ 2,965 $ 1,847 $ 1,854 $ 7 2022 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 875 $ — $ — $ — $ — $ 875 $ — Commercial & Industrial 365 — — — — 365 — Large delivery service 171 — — — — 171 — Off-system sales and capacity releases 76 (104) — — — 180 — Other 23 (1) — — — 24 — Total Utility 1,510 (105) — — — 1,615 — Non-Utility: LPG: Retail 4,436 — 2,439 1,997 — — — Wholesale 496 — 218 278 — — — Energy Marketing 2,951 (264) — 1,298 1,917 — — Midstream: Pipeline 211 — — — 211 — — Peaking 48 (105) — — 153 — — Other 9 — — — 9 — — Electricity Generation 34 — — — 34 — — Other 286 — 207 79 — — — Total Non-Utility 8,471 (369) 2,864 3,652 2,324 — — Total revenues from contracts with customers 9,981 (474) 2,864 3,652 2,324 1,615 — Other revenues (b) 125 (3) 79 34 2 5 8 Total revenues $ 10,106 $ (477) $ 2,943 $ 3,686 $ 2,326 $ 1,620 $ 8 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 568 $ — $ — $ — $ — $ 568 $ — Commercial & Industrial 218 — — — — 218 — Large delivery service 148 — — — — 148 — Off-system sales and capacity releases 51 (62) — — — 113 — Other 21 (2) — — — 23 — Total Utility 1,006 (64) — — — 1,070 — Non-Utility: LPG: Retail 3,957 — 2,203 1,754 — — — Wholesale 328 — 139 189 — — — Energy Marketing 1,564 (126) — 605 1,085 — — Midstream: Pipeline 181 — — — 181 — — Peaking 16 (98) — — 114 — — Other 8 — — — 8 — — Electricity Generation 13 — — — 13 — — Other 275 — 206 69 — — — Total Non-Utility 6,342 (224) 2,548 2,617 1,401 — — Total revenues from contracts with customers 7,348 (288) 2,548 2,617 1,401 1,070 — Other revenues (b) 99 (3) 66 34 5 9 (12) Total revenues $ 7,447 $ (291) $ 2,614 $ 2,651 $ 1,406 $ 1,079 $ (12) (a) Includes intersegment revenues principally among Midstream & Marketing, Utilities and AmeriGas Propane. (b) Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, revenues from alternative revenue programs at Utilities and 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. (c) Includes the impact of the weather normalization adjustment rider, a five-year pilot program beginning on November 1, 2022 for PA Gas Utility. See Note 9 for additional information. 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 at September 30, 2023 and 2022. 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 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 $158 and $164 at September 30, 2023 and 2022, respectively, and are primarily included in “Deposits and advances” on the Consolidated Balance Sheets. Revenues recognized during Fiscal 2023, Fiscal 2022 and Fiscal 2021 from the amounts included in contract liabilities at September 30, 2022, September 30, 2021 and September 30, 2020 was $127, $119 and $138, 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 September 30, 2023, Midstream & Marketing and Utilities expect to record approximately $2.2 billion and $0.2 billion of revenues, respectively, related to the minimum future performance obligations over the remaining terms of the related contracts.

Acquisitions and Dispositions

Acquisitions and Dispositions	12 Months Ended
	Sep. 30, 2023
Business Combination and Asset Acquisition [Abstract]
Acquisitions and Dispositions	Note 5 — Acquisitions and Dispositions Mountaineer Acquisition On September 1, 2021, UGI completed the Mountaineer Acquisition in which UGI acquired all of the equity interests in Mountaineer, the largest natural gas distribution company in West Virginia, for a purchase price of $540, including the assumption of $140 principal amounts of long-term debt. The Mountaineer Acquisition was consummated pursuant to a purchase and sale agreement between UGI and the iCON Sellers and is consistent with our growth strategies, including expanding our core utility operations in the mid-Atlantic region. The Mountaineer Acquisition was funded with cash proceeds from the 2021 UGI Corporation Senior Credit Facility $215 term loan and cash on hand including proceeds from the issuance of Equity Units . Accounts associated with Mountaineer are included within our Utilities reportable segment. The Company has accounted for the Mountaineer Acquisition using the acquisition method. The components of the Mountaineer purchase accounting are as follows: Assets acquired: Cash and cash equivalents $ 3 Accounts receivable 14 Inventories 41 Other current assets 21 Property, plant and equipment 397 Other noncurrent assets 48 Total assets acquired $ 524 Liabilities assumed: Short-term borrowings $ 55 Accounts payable 20 Other current liabilities 52 Long-term debt 164 Pension and other postretirement benefit obligation 33 Deferred income taxes 21 Other noncurrent liabilities 29 Total liabilities assumed $ 374 Goodwill 250 Net consideration transferred $ 400 Mountaineer is a regulated entity which accounts for the financial effects of regulation in accordance with ASC 980. The effects of regulation can impact the fair value of certain assets and liabilities acquired, and as such, the measurement of the fair value of regulated property assets using the predecessor’s carrying value is generally accepted since regulation attaches to the assets and regulation is so pervasive that the regulation extends to the individual assets. In certain other instances where assets or liabilities are subject to rate recovery, we recorded fair value adjustments to such assets and liabilities as regulatory assets and liabilities. The excess of the purchase price for the Mountaineer Acquisition over the fair values of the assets acquired and liabilities assumed has been reflected as goodwill, assigned to the Utilities reportable segment. Goodwill is attributable to the assembled workforce of Mountaineer, planned customer growth and planned growth in rate base through continued investment in utility infrastructure. The goodwill recognized from the Mountaineer Acquisition is not expected to be deductible for income tax purposes. The Company recognized $13 of direct transaction-related costs associated with the Mountaineer Acquisition during Fiscal 2021, which costs are reflected in “Operating and administrative expenses” on the 2021 Consolidated Statement of Income. The Mountaineer Acquisition did not have a material impact on the Company’s revenues or net income attributable to UGI for Fiscal 2021. In addition, the impact of the Mountaineer Acquisition on a pro forma basis as if the Mountaineer Acquisition had occurred on October 1, 2019 was not material to the Company’s revenues or net income for Fiscal 2021. Acquisitions of Assets Pennant . During the fourth quarter of Fiscal 2022, Energy Services completed the Pennant Acquisition and acquired the remaining 53% of the equity interests in Pennant for total cash consideration of approximately $61. The Pennant Acquisition was funded using available cash. The acquisition of the remaining interests has been accounted for as an acquisition of assets, and the purchase price has been primarily allocated to property, plant and equipment. See Note 21 for additional information related to the acquired interest in Pennant. Stonehenge . In January 2022, Energy Services completed the Stonehenge Acquisition and acquired all of the equity interests in Stonehenge for total cash consideration of approximately $190. The Stonehenge business includes a natural gas gathering system, located in western Pennsylvania, with more than 47 miles of pipeline and associated compression assets. The Stonehenge Acquisition is consistent with our growth strategies, including expanding our midstream natural gas gathering assets within the Appalachian basin production region. The Stonehenge Acquisition was funded using available cash. This transaction has been accounted for as an acquisition of assets, and the purchase price has been primarily allocated to property, plant and equipment. We refer to Stonehenge and its assets as “UGI Moraine East.” Dispositions UGI International Energy Marketing Transactions During Fiscal 2023 and in October 2023, the Company entered into a number of transactions pursuant to its previously announced decision to exit its European energy marketing business. The European energy marketing business primarily markets natural gas and electricity to customers through third-party distribution systems in France, the Netherlands and, prior to its sales, in Belgium 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 $25 (which approximates a pre-tax loss), subject to certain adjustments principally related to the pending transfer of certain customer contracts. As of September 30, 2023, the $25 cash to be paid to the buyer in October 2023 had been placed in escrow and is reflected in “Other current assets” on the September 30, 2023 Consolidated Balance Sheet. The carrying values of the assets and liabilities associated with this business, principally comprising certain commodity derivative instruments, energy certificates and certain working capital, have been classified as held-for-sale on the September 30, 2023 Consolidated Balance Sheet. The Company did not recognize any impairment associated with the assets held for sale in Fiscal 2023 because, in accordance with our policy related to such assets, any impairment is limited to the disposal group’s long-lived assets, and such assets 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, the Company recorded a pre-tax loss of $6 ($5 after-tax) which amount includes the net payment to the buyer, the write-off of certain prepaid energy broker payments and associated transaction costs and fees. The loss is reflected in “Loss on disposal of UGI International energy marketing business” on the Consolidated Statements of Income. 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, the Company recorded a pre-tax loss of $215 ($151 after-tax) substantially all of which loss 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 will continue to provide for the delivery of electricity and natural gas at fixed prices through December 31, 2023, but the Company’s obligations to provide future services will be 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 carrying values of these commodity derivative instruments are subject to change until such contracts are settled, and the cash payments are made during the first quarter of Fiscal 2024. At September 30, 2023, the carrying value of these commodity derivative instruments was $44. The early termination agreements with DVEP customers are considered contract modifications and the cash consideration to be paid to these customers has been, and will be reflected as a reduction in revenues, on a pro-rata basis, over the remaining performance period of such agreements through December 31, 2023. Accordingly, during the fourth quarter of Fiscal 2023, the Company reduced its revenues from these customers by $4, which represents the pro-rated performance obligation through September 30, 2023 from the aforementioned $44. In conjunction with the wind-down of its European energy marketing business, in July 2023, DVEP agreed to sell a substantial portion of its power purchase agreements to a third party for a cash payment to the buyer of $6. The closing of the sale is expected to occur during the first quarter of Fiscal 2024. The loss from the sale is not expected to be material. 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 Consolidated Statements of Income and included in the UGI International reportable segment.

Debt

Debt	12 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
Debt	Note 6 — Debt Significant Financing Activities Since September 30, 2022 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 rate applicable to borrowings under the UGI Utilities 2023 Credit Agreement will remain unchanged. The 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 maturity of the credit agreement was extended to November 2024 with an additional automatic 5-year extension upon receipt of authorization for such extension from the PAPUC. 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. On December 13, 2022, UGI Utilities entered into an amendment to the UGI Utilities Credit Agreement, providing for borrowings up to $425 and to replace the use of LIBOR with Term SOFR. Borrowings under the amended UGI Utilities Credit Agreement bear interest, subject to our election, at a floating rate of either (i) Term SOFR plus the applicable margin plus a credit spread adjustment of 0.10% or (ii) the base rate plus the applicable margin. The applicable margin remains unchanged from the original credit agreement. AmeriGas Partners Senior Notes. On May 31, 2023, AmeriGas Partners and AmeriGas Finance Corp. issued $500 principal amount of 9.375% Senior Notes due May 2028. The 9.375% Senior Notes rank equally with AmeriGas Partners’ existing senior notes. The net proceeds from the issuance of the 9.375% Senior Notes, together with cash on hand, a $150 cash contribution from the Company and other sources of liquidity, were used for the early repayment, pursuant to a tender offer and notice of redemption, of all AmeriGas Partners 5.625% Senior Notes having an aggregate principal balance of $675, plus tender premiums and accrued and unpaid interest. In conjunction with the early repayment of the 5.625% Senior Notes, in June 2023 the Partnership recognized a pre-tax loss of $9 primarily comprising tender premiums and the write-off of unamortized debt issuance costs, which is reflected in “Loss on extinguishments of debt” on the Consolidated Statement of Income. The 9.375% Senior Notes are redeemable at the issuers’ option prior to June 2025 at a make whole premium or, on or after June 2025, at a call premium that declines from 4.688% to 0% depending on the year of redemption. The 9.375% Senior Notes indenture contains customary covenants and default provisions that limit AmeriGas Partners’ ability to, among other things: incur additional indebtedness; create or incur liens; engage in transactions with affiliates; engage in mergers or consolidations or sell all or substantially all of the issuers’ assets; make restricted payments, loans and investments; enter into business combinations and sell assets; and engage in other lines of business. UGI International 2023 Credit Facilities Agreement. On March 7, 2023, UGI International, LLC and its indirect wholly-owned subsidiary, UGI International Holdings B.V., entered into the UGI International 2023 Credit Facilities Agreement, a five-year unsecured senior facilities agreement, maturing March 7, 2028, with a consortium of banks. The UGI International 2023 Credit Facilities Agreement consists of (1) a €300 variable-rate term loan facility ("Facility A") and (2) a €500 multicurrency revolving credit facility, including a €100 sublimit for swingline loans ("Facility B"). We have designated borrowings under Facility A as a net investment hedge. In connection with entering into the UGI International 2023 Credit Facilities Agreement, UGI International, LLC paid off in full and terminated the UGI International Credit Facilities Agreement, dated as of October 18, 2018. Borrowings under the multicurrency revolving credit facility may be used to finance the working capital needs of UGI International, LLC and its subsidiaries and for general corporate purposes. Borrowings under Facility A bear interest at the euro interbank offered rate plus the applicable margin and borrowings under Facility B bear interest at the daily non-cumulative compounded Reference Rate Terms, as defined in the Agreement, plus the applicable margin. The applicable margin for Facility A ranges from 1.70% to 3.35%, and for Facility B from 1.35% to 3.35%, and are dependent on the total net leverage ratio of UGI International, LLC and its subsidiaries on a consolidated basis. UGI International, LLC entered into an interest rate swap, effective March 31, 2023, that fixes the underlying market-based interest rate on Facility A at 3.10% through March 2026. The UGI International 2023 Credit Facilities Agreement contains customary covenants and default provisions and requires compliance with certain financial covenants including a consolidated net leverage ratio as defined in the agreement. UGI Energy Services Credit Agreement. On May 12, 2023, Energy Services entered into the second amendment to the UGI Energy Services Credit Agreement, which provides that the Term SOFR rate (as defined in the UGI Energy Services Credit Agreement) shall replace LIBOR as a reference rate. After giving effect to the second amendment, the UGI Energy Services Credit Agreement shall bear interest at a floating rate of, at Energy Services’ option, either (i) Term SOFR plus the Applicable Rate (as defined in the UGI Energy Services Credit Agreement) plus a credit spread adjustment of 0.10%, or (ii) the base rate plus the applicable margin that is based on the leverage of Energy Services. Energy Services Amended Term Loan Credit Agreement. On February 23, 2023, Energy Services entered into the Energy Services Amended Term Loan Credit Agreement, the first amendment to the Energy Services Term Loan Credit Agreement, dated August 13, 2019. The Energy Services Amended Term Loan Credit Agreement provides, among other items, that (i) the outstanding principal amount of the loans shall be increased by $125 to $800, (ii) the maturity date of the loans shall be extended to February 22, 2030, (iii) Term SOFR (as defined in the Energy Services Amended Term Loan Credit Agreement) shall replace LIBOR as a reference rate and (iv) borrowings under the Energy Services Amended Term Loan Credit Agreement shall bear interest at a floating rate of, at Energy Services’ option, either (x) Term SOFR plus the applicable margin plus a credit spread adjustment of 0.10% or (y) the base rate, as defined in the Agreement, plus the applicable margin. The applicable margin shall be 3.25% per annum for Term SOFR loans and 2.25% per annum for base rate loans. Borrowings under the Energy Services Amended Term Loan Credit Agreement are payable in equal quarterly installments of $2, commencing in March 2023, with the balance of the principal being due and payable in full at maturity. The Energy Services Amended Term Loan Credit Agreement contains customary covenants and default provisions and requires compliance with certain financial covenants including a minimum debt service coverage ratio as defined in the Agreement. In March 2023, in connection with the Energy Services Amended Term Loan Credit Agreement, Energy Services terminated and settled its existing interest rate swap associated with the Energy Services Term Loan Credit Agreement at a $32 gain. This gain has been deferred in AOCI and is being amortized to interest expense over the remaining term of the initial interest rate swap ending July 2024. Energy Services entered into a new interest rate swap, effective March 31, 2023, that fixes the underlying market-based interest rate on this variable-rate term loan at 4.53% through September 2026. Mountaineer 2023 Credit Agreement. On October 20, 2022, Mountaineer entered into the Mountaineer 2023 Credit Agreement with a group of lenders. The Mountaineer 2023 Credit Agreement amends and restates a previous credit agreement and provides for borrowings up to $150, including a $20 sublimit for letters of credit. Mountaineer may request an increase in the amount of loan commitments to a maximum aggregate amount of $250, subject to certain terms and conditions. Borrowings under the Mountaineer 2023 Credit Agreement can be used to finance the working capital needs of Mountaineer and for general corporate purposes. The Mountaineer 2023 Credit Agreement is scheduled to expire in November 2024, and Mountaineer has the option, with the consent of the lenders, to extend the maturity date up to November 2026. Borrowings under the Mountaineer 2023 Credit Agreement bear interest, subject to our election, at either (i) the base rate, defined as the highest of (a) the prime rate, (b) the federal funds rate plus 0.50% and (c) the adjusted Term SOFR rate for a one-month tenor plus 1%, in each case, plus the applicable margin or (ii) the adjusted Term SOFR rate plus the applicable margin. The applicable margin for base rate loans ranges from 0% to 1.25%, and for Term SOFR loans from 1.00% to 2.25%, depending on the debt rating of Mountaineer. The adjusted Term SOFR rate is defined as the Term SOFR reference rate for the selected interest period, plus 0.10% per annum for a one-month interest period, 0.15% per annum for a three-month interest period, or 0.25% per annum for a six-month interest period. The Mountaineer Credit Agreement contains customary covenants and default provisions and requires compliance with certain financial covenants including a maximum leverage ratio and a minimum interest coverage ratio as defined in the agreement. UGI Corporation Credit Facility Agreement . On May 12, 2023, the Company entered into the second amendment to the UGI Corporation Credit Agreement, which provides that the Term SOFR rate (as defined in the UGI Corporation Credit Agreement) shall replace LIBOR as a reference rate. After giving effect to the second amendment, the UGI Corporation Credit Agreement shall bear interest at a floating rate of, at the Company’s option, either (i) Term SOFR plus the Applicable Rate (as defined in the UGI Corporation Credit Agreement) plus a credit spread adjustment of 0.10%, or (ii) the base rate plus the applicable margin that will be based on the leverage of the Company or credit ratings assigned to certain indebtedness of the Company. On September 20, 2023, UGI amended the UGI Corporation Credit Facility Agreement which extended the maturity date of the (1) five-year $250 amortizing variable-rate term loan and (2) five-year $300 revolving credit facility to May 2025 and increased the applicable rate (as defined in the amended UGI Corporation Credit Agreement) by 0.125%. Credit Facilities and Short-term Borrowings Information about the Company’s principal credit agreements (excluding the Energy Services Receivables Facility, which is discussed below) as of September 30, 2023 and 2022, is presented in the following table. Borrowings on these credit agreements bear interest at rates indexed to short-term market rates. Borrowings outstanding under these agreements (other than the 2021 UGI Corporation Senior Credit Facility) are classified as “Short-term borrowings” on the Consolidated Balance Sheets. Expiration Date Total Capacity Borrowings Outstanding Letters of Credit and Guarantees Outstanding Available Borrowing Capacity Weighted Average Interest Rate - End of Year September 30, 2023 AmeriGas OLP (a) September 2026 $ 600 $ — $ 2 $ 598 N.A. UGI International, LLC (b) March 2028 € 500 € 202 € — € 298 5.17 % Energy Services (c) March 2025 $ 260 $ 57 $ — $ 203 7.67 % UGI Utilities (d) June 2024 $ 425 $ 248 $ — $ 177 6.30 % Mountaineer (e) November 2024 $ 150 $ 84 $ — $ 66 6.68 % UGI Corporation (f) May 2025 $ 300 $ 283 $ — $ 17 7.80 % September 30, 2022 AmeriGas OLP (a) September 2026 $ 600 $ 131 $ 2 $ 467 7.27 % UGI International, LLC (b) October 2023 € 300 € — € — € 300 N.A. Energy Services (c) March 2025 $ 260 $ — $ — $ 260 N.A. UGI Utilities (d) June 2024 $ 350 $ 151 $ — $ 199 4.37 % Mountaineer (e) November 2024 $ 100 $ 85 $ — $ 15 3.82 % UGI Corporation (f) August 2024 $ 300 $ 252 $ — $ 48 5.62 % (a) At September 30, 2023 and 2022 the 2022 AmeriGas OLP Credit Agreement includes a $100 sublimit for letters of credit. (b) The UGI International 2023 Credit Facilities Agreement and the previous UGI International Credit Facilities Agreement permits borrowings in euros or USD. (c) The Energy Services Credit Agreement includes a $50 sublimit for letters of credit and is guaranteed by certain subsidiaries of Energy Services. (d) The UGI Utilities Credit Agreement includes a $100 sublimit for letters of credit. On November 9, 2023, UGI Utilities entered into the UGI Utilities 2023 Credit Agreement and concurrently terminated the UGI Utilities Credit Agreement, a predecessor agreement. See Significant Financing Activities above and Note 6 for additional information. See Significant Financing Activities Since September 30, 2022 above for additional information. (e) The Mountaineer 2023 Credit Agreements includes a $20 sublimit for letters of credit. (f) At September 30, 2023 and 2022, management intended to maintain a substantial portion of amounts outstanding under the UGI Corporation Senior Credit Facility beyond twelve months from the respective balance sheet dates. As such, borrowings outstanding are classified as “Long-term debt” on the Consolidated Balance Sheets. Subsequent to September 30, 2022, the Company repaid $87 of such borrowings and classified these repayments as “Current maturities of long-term debt” on the Consolidated Balance Sheets. The UGI Corporation Senior Credit Facility includes a $10 sublimit for letters of credit. N.A. - Not applicable Energy Services Receivables Facility. Energy Services has a Receivables Facility with an issuer of receivables-backed commercial paper. On October 20, 2023, the expiration date of the Receivables Facility was extended to October 18, 2024. The Receivables Facility provides Energy Services with the ability to borrow up to $200 of eligible receivables during the period October 20, 2023 to April 30, 2024, and up to $100 of eligible receivables during the period May 1, 2024 to October 18, 2024. Energy Services uses the Receivables Facility to fund working capital, margin calls under commodity futures contracts, capital expenditures, dividends and for general corporate purposes. Under the Receivables Facility, Energy Services transfers, on an ongoing basis and without recourse, its trade accounts receivable to its wholly owned, special purpose subsidiary, ESFC, which is consolidated for financial statement purposes. ESFC, in turn, has sold and, subject to certain conditions, may from time to time sell, an undivided interest in some or all of the receivables to a major bank. Amounts sold to the bank are reflected as “Short-term borrowings” on the Consolidated Balance Sheets. ESFC was created and has been structured to isolate its assets from creditors of Energy Services and its affiliates, including UGI. Trade receivables sold to the bank remain on the Company’s balance sheet and the Company reflects a liability equal to the amount advanced by the bank. The Company records interest expense on amounts owed to the bank. Energy Services continues to service, administer and collect trade receivables on behalf of the bank, as applicable. Information regarding the amounts of trade receivables transferred to ESFC and the amounts sold to the bank are as follows: 2023 2022 2021 Trade receivables transferred to ESFC during the year $ 1,946 $ 2,221 $ 1,353 ESFC trade receivables sold to the bank during the year $ 535 $ 152 $ 308 ESFC trade receivables - end of year (a) $ 62 $ 101 $ 61 (a) At September 30, 2023, the amounts of ESFC trade receivables sold to the bank was $46, and is reflected as “Short-term borrowings” on the Consolidated Balance Sheets. At September 30, 2022 there were no ESFC trade receivables sold to the bank. Long-term Debt Long-term debt comprises the following at September 30: 2023 2022 AmeriGas Propane: AmeriGas Partners Senior Notes: 5.50% due May 2025 $ 700 $ 700 5.875% due August 2026 675 675 5.625% due May 2024 — 675 5.75% due May 2027 525 525 9.375% due May 2028 500 — Unamortized debt issuance costs (15) (12) Total AmeriGas Propane 2,385 2,563 UGI International: 2.50% Senior Notes due December 2029 424 392 UGI International, LLC variable-rate term loan due March 2028 (a) 317 — UGI International, LLC variable-rate term loan due October 2023 (b) — 294 Other 6 2 Unamortized debt issuance costs (8) (6) Total UGI International 739 682 Midstream & Marketing: Energy Services variable-rate term loan due through February 2030 (c) 794 677 Other 41 40 Unamortized discount and debt issuance costs (15) (7) Total Energy Services 820 710 Utilities: UGI Utilities Senior Notes: 4.12% due September 2046 200 200 4.98% due March 2044 175 175 3.12% due April 2050 150 150 4.55% due February 2049 150 150 4.12% due October 2046 100 100 6.21% due September 2036 100 100 2.95% due June 2026 100 100 1.59% due June 2026 100 100 1.64% due September 2026 75 75 4.75% due July 2032 90 90 4.99% due September 2052 85 85 UGI Utilities Medium-Term Notes: 6.13% due October 2034 20 20 6.50% due August 2033 20 20 Mountaineer senior notes (d) 199 201 UGI Utilities variable-rate term loan due through July 2027 (e) 89 95 Other 2 1 Unamortized debt issuance costs (6) (6) Total Utilities 1,649 1,656 UGI Corporation: UGI Corporation Credit Facilities: UGI Corporation revolving credit facility maturing May 2025 (f) 283 252 UGI Corporation variable-rate term loan due May 2025 (g) 300 300 UGI Corporation variable-rate term loan due through May 2025 (h) 212 250 UGI Corporation variable-rate term loan due May 2025 (i) 215 215 Unamortized debt issuance costs (3) (2) Total UGI Corporation 1,007 1,015 Other — 6 Total long-term debt 6,600 6,632 Less: current maturities (57) (149) Total long-term debt due after one year $ 6,543 $ 6,483 (a) At September 30, 2023, the effective interest rate on the term loan was 4.95%. We have entered into pay-fixed, receive-variable interest rate swaps that fix the underlying variable rate at 3.10% through March 2026. (b) At September 30, 2022, the effective interest rate on the term loan was 1.89%. The term loan was repaid in full and terminated concurrently with the execution of the UGI International 2023 Credit Facilities Agreement. (c) At September 30, 2023 and 2022, the effective interest rates on the term loan were 7.82% and 5.13%, respectively. We have entered into a pay-fixed, receive-variable interest rate swap to effectively fix the underlying variable rate at 4.53% on these borrowings through September 2026. Term loan borrowings are due in equal quarterly installments of $2, with the balance of the principal being due in full at maturity. Under certain circumstances, Energy Services is required to make additional principal payments if the consolidated total leverage ratio, as defined, is greater than defined thresholds. This term loan is collateralized by substantially all of the assets of Energy Services, subject to certain exceptions and carveouts including, but not limited to, accounts receivable and certain real property. (d) Total long-term debt at September 30, 2023 and 2022, comprises $180 principal amount of Mountaineer senior secured notes plus unamortized premium of $19 and $21 for September 30, 2023 and 2022, respectively. The face interest rates on the Mountaineer senior notes range from 3.50% to 4.49%, with maturities ranging from 2027 to 2052. (e) At September 30, 2023 and 2022, the effective interest rate on this term loan was 3.92%. We have entered into a pay-fixed, receive-variable interest rate swap to effectively fix the underlying variable rate at approximately 2.82% on a portion of these borrowings through June 2026. Term loan borrowings are due in equal quarterly installments of $2, with the balance of the principal being due in full at maturity. (f) At September 30, 2023 and 2022, the effective interest rates on credit facility borrowings were 7.80% and 5.61%, respectively. (g) At September 30, 2023 and 2022, the effective interest rates on the term loan were 2.77% and 2.67%, respectively. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate at approximately 0.70% on these borrowings through September 2024. (h) At September 30, 2023 and 2022, the effective interest rates on the term loan were 7.79% and 4.15%, respectively. Term loan borrowings are due in equal quarterly installments of $9, commencing December 2022, which the balance of the principal being due in full at maturity. (i) At September 30, 2023 and 2022, the effective interest rates on the term loan were 4.73% and 3.53%, respectively. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate at approximately 0.70% on a portion of these borrowings through September 2024. Scheduled principal repayments of long-term debt for each of the next five fiscal years ending September 30 are as follows: 2024 2025 2026 2027 2028 AmeriGas Propane $ — $ 700 $ 675 $ 525 $ 500 UGI International 1 — — — 317 Midstream & Marketing 12 8 8 8 8 Utilities 6 6 281 70 40 UGI Corporation 38 973 — — — Total $ 57 $ 1,687 $ 964 $ 603 $ 865 Restrictive Covenants Our long-term debt and credit facility agreements generally contain customary covenants and default provisions which may include, among other things, restrictions on the incurrence of additional indebtedness and also restrict liens, guarantees, investments, loans and advances, payments, mergers, consolidations, asset transfers, transactions with affiliates, sales of assets, acquisitions and other transactions. These agreements contain standard provisions which require compliance with certain financial ratios. Certain of the subsidiaries nonrecourse debt agreements contain cross-default provisions, whereby default under an agreement with one lender simultaneously causes default under agreements with other lenders. In addition, under the default provisions, a default of a subsidiary results in or is at risk of triggering a cross-default under the debt of the parent company. UGI and its subsidiaries were in compliance with all debt covenants as of September 30, 2023. 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. On November 15 2023, the Company entered into an amendment to the 2022 AmeriGas OLP Credit Agreement, which amends certain provisions of the credit agreement dated as of September 28, 2022 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 the fourth quarter of Fiscal 2024 and (iii) beginning for the first quarter of Fiscal 2025, the minimum interest coverage ratio will remain reduced if the net leverage ratio is below a 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. As of March 31, 2023, AmeriGas OLP was in breach of the leverage ratio debt covenant and interest coverage ratio, which it cured with the funds received from UGI. 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. UGI made capital contributions to AmeriGas OLP of $20 and $11 on March 31, 2023 and April 24, 2023, respectively, which in aggregate represented one equity cure in accordance with the 2022 AmeriGas OLP Credit Agreement. As a result of these capital contributions, AmeriGas OLP and the Partnership were in compliance with its financial covenants after considering the equity cure provision as of June 30, 2023 and March 31, 2023. As of September 30, 2023, the Partnership was in compliance with all debt covenants as set forth in the amended 2022 AmeriGas OLP Credit Agreement without the consideration of the equity cure provision. UGI also 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. In addition, in May 2023, the Company contributed $52 in an equity contribution principally to fund debt service on the senior notes. Restricted Net Assets At September 30, 2023, the amount of net assets of UGI’s consolidated subsidiaries that were restricted from transfer to UGI under debt agreements, subsidiary partnership agreements and regulatory requirements under foreign laws totaled approximately $3,600.

Income Taxes

Income Taxes	12 Months Ended
	Sep. 30, 2023
Income Tax Disclosure [Abstract]
Income Taxes	Note 7 — Income Taxes (Loss) income before income taxes comprises the following: 2023 2022 2021 Domestic $ (346) $ 362 $ 647 Foreign (1,491) 1,025 1,342 Total (loss) income before income taxes $ (1,837) $ 1,387 $ 1,989 The provisions for income taxes consist of the following: 2023 2022 2021 Current expense (benefit): Federal $ (1) $ 24 $ (48) State 37 18 7 Foreign 49 50 85 Total current expense 85 92 44 Deferred expense (benefit): Federal 34 45 168 State (21) (17) 48 Foreign (433) 193 262 Total deferred (benefit) expense (420) 221 478 Total income tax (benefit) expense $ (335) $ 313 $ 522 Federal income taxes for Fiscal 2023 and Fiscal 2022 are net of foreign tax credits of $25 and $5, respectively. There were no foreign tax credits utilized in Fiscal 2021. A reconciliation from the U.S. federal statutory tax rate to our effective tax rate is as follows: 2023 2022 2021 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % Difference in tax rate due to: Goodwill impairment not deductible for tax (7.3) — — Effects of foreign operations 3.9 4.4 4.6 State income taxes, net of federal benefit (1.1) 1.5 1.9 Valuation allowance adjustments 1.1 (0.5) 1.0 Effects of tax rate changes – State, net of federal benefit 0.2 (1.4) — Effects of tax rate changes - International — (2.3) (1.3) Effects of U.S. tax legislation — — (0.8) Other, net 0.4 (0.1) (0.2) Effective tax rate 18.2 % 22.6 % 26.2 % In July 2022, tax legislation was enacted in Pennsylvania reducing the state’s corporate net income tax rate from 9.99% to 4.99% over a nine-year period, beginning with an initial reduction to 8.99% beginning in Fiscal 2024. The legislation resulted in $4 and $20 of tax benefits being recorded in Fiscal 2023 and Fiscal 2022, respectively, based on the Company’s analysis of future reversals of net deferred tax liabilities. In February 2021, tax legislation was enacted in Italy which allowed the Company to align book basis with tax basis on certain assets in exchange for paying a three percent substitute tax payment payable in three annual installments. This election resulted in a $23 net benefit in Fiscal 2021. Timing of the recovery of the resulting incremental tax basis was changed with legislation in Fiscal 2022 extending the deductible period of recovery from 18 to 50 years . On March 27, 2020 the CARES Act was enacted into law. The primary impact of the legislation was the change in federal net operating loss carryback rules which allowed the Company’s U.S. federal tax losses generated in Fiscal 2021 to be carried back to Fiscal 2016. The carryback of our Fiscal 2021 U.S. federal tax losses from a 21% rate environment to offset taxable income in Fiscal 2016 in a 35% rate environment generated incremental benefits of $15. A $37 refund claim for the Fiscal 2021 claim has been filed and is included in “Income taxes receivable” on the Consolidated Balance Sheet at September 30, 2023 and 2022. Our effective tax rate is subject to the impact of changes to the taxation of foreign source income made by the TCJA and the high tax exception regulations issued in July 2020. Income tax expense for Fiscal 2023, Fiscal 2022 and Fiscal 2021 includes $13, $3, and $8, respectively, of GILTI taxes that are treated as current period costs and carry no related deferred taxes. Pennsylvania and West Virginia utility ratemaking practices permit the flow through to ratepayers of state tax benefits resulting from accelerated tax depreciation. For Fiscal 2023, Fiscal 2022 and Fiscal 2021, the beneficial effects of state tax flow through of accelerated depreciation reduced income tax expense by $11, $10, and $9, respectively. Deferred tax liabilities (assets) comprise the following at September 30: 2023 2022 Excess book basis over tax basis of property, plant and equipment $ 966 $ 867 Utility regulatory assets 84 106 Intangible assets and goodwill 81 75 Derivative instrument assets 19 514 Other 37 33 Gross deferred tax liabilities 1,187 1,595 Investment in AmeriGas Partners (28) (79) Pension plan liabilities (14) (21) Employee-related benefits (37) (38) Operating loss carryforwards (75) (48) Foreign tax credit carryforwards (64) (76) Utility regulatory liabilities (83) (85) Utility environmental liabilities (15) (15) Interest expense (83) (51) Other (58) (74) Gross deferred tax assets (457) (487) Deferred tax assets valuation allowance 141 141 Net deferred tax liabilities $ 871 $ 1,249 At September 30, 2023, we carried foreign net operating loss carryforwards of $6 relating to Flaga, $23 at certain subsidiaries of UGI France, $10 relating to Belgium, $5 relating to U.K., and $44 in the Netherlands with no expiration dates. We have state net operating loss carryforwards primarily relating to certain subsidiaries that approximate $1,071 and expire through 2043. We also have federal operating loss carryforwards of $9 for certain operations of AmeriGas Propane. At September 30, 2023, deferred tax assets relating to operating loss carryforwards amounted to $75 related to various UGI subsidiaries. Valuation allowances against deferred tax assets exist for foreign tax credit carryforwards, net operating loss carryforwards of foreign subsidiaries, capital loss carryforwards and a notional interest deduction. The valuation allowance for all deferred tax remained the same in Fiscal 2023, which included an increase of $19 for disallowed interest, an increase of $11 for foreign net operating losses, $5 for a notional interest deduction and $3 from state tax rate decreases were offset by $22 decrease against capital losses and a $16 decrease against FTC’s. The valuation allowance for all deferred tax assets increased by $3 in Fiscal 2022, which included a $17 increase in a notional interest deduction carryover, offset by a release of $6 against FTCs that will be realizable in the future, a $4 decrease from state tax rate changes, and a $4 decrease related to foreign net operating loss carry forwards. We conduct business and file tax returns in the U.S., and various local, state and foreign jurisdictions. Our U.S. federal income tax returns are settled through the 2019 tax year, and our European tax returns are effectively settled for various years from 2015 to 2020. State and other income tax returns in the U.S. are generally subject to examination for a period of three to five years after the filing of the respective returns. The Company’s unrecognized tax benefits including amounts related to accrued interest, which if subsequently recognized would be recorded as a benefit to income taxes, amounted to $26, $5, and $3 at September 30, 2023, 2022 and 2021, respectively. Generally, a net reduction in unrecognized tax benefits could occur because of the expiration of the statute of limitations in certain jurisdictions or as a result of settlements with tax authorities. The expected change in unrecognized tax benefits and related interest in the next twelve months as the result of the expiration of certain statutes is immaterial. A reconciliation of the beginning and ending amounts of unrecognized tax benefits is as follows: 2023 2022 2021 Unrecognized tax benefits — beginning of year $ 5 $ 3 $ 4 Additions for tax positions of the current year 3 2 — Decreases for tax positions taken in prior years — — (2) Increases for tax positions taken in prior years 19 1 1 Settlements with tax authorities/statute lapses (1) (1) — Unrecognized tax benefits — end of year $ 26 $ 5 $ 3

Employee Retirement Plans

Employee Retirement Plans	12 Months Ended
	Sep. 30, 2023
Retirement Benefits [Abstract]
Employee Retirement Plans	Note 8 — Employee Retirement Plans Defined Benefit Pension and Other Postretirement Plans The U.S. Pension Plans consist of (1) a defined benefit pension plan for employees hired prior to January 1, 2009, of UGI, UGI Utilities, and certain of UGI’s other domestic wholly owned subsidiaries and (2) a defined benefit pension plan for Mountaineer employees hired prior to January 1, 2023. U.S. Pension Plans’ benefits are based on years of service, age and employee compensation. In addition, certain UGI International employees in France and Belgium are covered by defined benefit pension and postretirement plans. Although the disclosures in the tables below include amounts related to the UGI International plans, such amounts are not material. We also provide postretirement health care benefits to certain retirees and postretirement life insurance benefits to certain U.S. active and retired employees. The ABO of our other postretirement benefit plans was $21 and $22 as of September 30, 2023 and 2022, respectively. The fair value of the plan assets of our other postretirement benefit plans was $18 and $16 as of September 30, 2023 and 2022, respectively. The following table provides a reconciliation of the PBOs of our pension plans (the U.S. Pension Plans and the UGI International pension plans), plan assets, and the related funded status of our pension plans as of September 30, 2023 and 2022. ABO is the present value of benefits earned to date with benefits based upon current compensation levels. PBO is ABO increased to reflect estimated future compensation. Pension Benefits 2023 2022 Change in benefit obligations: Benefit obligations — beginning of year $ 633 $ 870 Service cost 9 16 Interest cost 35 26 Actuarial gain (20) (240) Plan amendments — 1 Foreign currency 2 (6) Benefits paid (36) (34) Benefit obligations — end of year (a) $ 623 $ 633 Pension Benefits 2023 2022 Change in plan assets: Fair value of plan assets — beginning of year $ 541 $ 736 Actual gain (loss) on plan assets 31 (173) Foreign currency 1 (3) Employer contributions 19 15 Benefits paid (36) (34) Fair value of plan assets — end of year $ 556 $ 541 Funded status of the plans — end of year (b) $ (67) $ (92) Amounts recorded in UGI Corporation stockholders’ equity (pre-tax): Prior service cost $ 3 $ 3 Net actuarial gain (17) (17) Total $ (14) $ (14) Amounts recorded in regulatory assets and liabilities (pre-tax): Net actuarial loss 110 114 Total $ 110 $ 114 (a) The ABO for the U.S. Pension Plans was $558 and $570 as of September 30, 2023 and 2022, respectively. (b) Amounts are reflected in “Other noncurrent liabilities” and “Other assets” on the Consolidated Balance Sheets. Amounts reflected in “Other assets” are not material. In Fiscal 2023 and Fiscal 2022, the change in the pension plans’ PBO due to actuarial gains is principally the result of changes in discount rates. Actuarial assumptions for our U.S. Pension Plans are described below. The discount rate assumption was determined by selecting a hypothetical portfolio of high quality corporate bonds appropriate to provide for the projected benefit payments of the plans. The discount rate was then developed as the single rate that equates the market value of the bonds purchased to the discounted value of the plans’ benefit payments. The expected rate of return on assets assumption is based on current and expected asset allocations as well as historical and expected returns on various categories of plan assets (as further described below). Pension Plans 2023 2022 2021 Weighted-average assumptions: Discount rate – benefit obligations 6.09 % 5.70 % 3.13 % Discount rate – benefit cost 5.70 % 3.13 % 2.90 % Expected return on plan assets 7.50 % 7.10 % 7.10 % Rate of increase in salary levels 3.25 % 3.25 % 3.25 % The service cost component of our pension and other postretirement plans, net of amounts capitalized, is reflected in “Operating and administrative expenses” on the 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 (expense) income, net” on the Consolidated Statements of Income. Other postretirement benefit cost was not material for all periods presented. Net periodic pension (income) cost includes the following components: Pension Benefits 2023 2022 2021 Service cost $ 9 $ 16 $ 12 Interest cost 35 26 22 Expected return on assets (45) (50) (40) Amortization of: Actuarial (gain) loss (3) 7 14 Net benefit (income) cost $ (4) $ (1) $ 8 It is our general policy to fund amounts for U.S. Pension Plans benefits equal to at least the minimum required contribution set forth in applicable employee benefit laws. From time to time, we may, at our discretion, contribute additional amounts. During Fiscal 2023, Fiscal 2022 and Fiscal 2021, we made cash contributions to the U.S. Pension Plans of $18 , $14 and $13, respectively. The minimum required contributions to the U.S. Pension Plans in Fiscal 2024 is $22. UGI Utilities has established a VEBA trust to pay certain retiree health care and life insurance benefits by depositing into the VEBA the annual amount of postretirement benefits costs, if any. Assets associated with the VEBA are not material and we do not expect to be required to make any contributions to the VEBA during Fiscal 2024. Expected payments for postretirement benefits over the next 10 years are not material. Expected payments for pension benefits are as follows: Pension Fiscal 2024 $ 39 Fiscal 2025 $ 39 Fiscal 2026 $ 41 Fiscal 2027 $ 43 Fiscal 2028 $ 44 Fiscal 2029 - 2033 $ 238 We also sponsor unfunded and non-qualified supplemental executive defined benefit retirement plans. At September 30, 2023 and 2022, the PBOs of these plans, including obligations for amounts held in grantor trusts, totale d $34 and $44, respectively. Costs associated with these plans and amounts recorded in UGI’s stockholder’s equity representing actuarial gains and losses were not material for all periods presented and are excluded from the tables above. During Fiscal 2023 and Fiscal 2022, the payments the Company made with respect to the supplemental executive defined benefit retirement plans were not material . During Fiscal 2021, the Company made $12 of payments for the supplemental executive defined benefit retirement plans. The total fair value of the grantor trust investment assets associated with the supplemental executive defined benefit retirement plans, which are included in “Other assets” on the Consolidated Balance Sheets, totaled $26 and $31 at September 30, 2023 and 2022, respectively. U.S. Pension Plans’ Assets The assets of the U.S. Pension Plans are held in trust. The investment policies and asset allocation strategies for the assets in these trusts are determined by the Retirement Plan Committee comprising certain members of UGI’s senior management. The overall investment objective is to minimize projected funded status volatility by more closely aligning the duration of the U.S. Pension Plans’ fixed income portfolio to the duration of its liabilities. The proportion of plan assets allocated to fixed income investments will increase as the funded status increases. Investments are made principally in common collective trust funds that consist of equity index investments, bond index investments and short-term investments, and, to a much less extent, UGI Common Stock. The targets and actual allocations for the U.S. Pension Plans’ trust assets at September 30 are as follows: Actual Target Asset Allocation (b) 2023 2022 2023 2022 Equity investments: U.S. equities 25.8 % 26.5 % 27.6 % 24.7 % Non-U.S. equities 21.7 % 20.9 % 23.3 % 20.9 % Global equities (a) 13.9 % 13.8 % 10.7 % 13.1 % Total 61.4 % 61.2 % 61.6 % 58.7 % Fixed income funds & cash equivalents 35.5 % 35.5 % 35.0 % 35.0 % Alternative investments 3.1 % 3.3 % 3.4 % 6.3 % Total 100.0 % 100.0 % 100.0 % 100.0 % (a) Comprises investment funds that consist of a mix of U.S. and Non-U.S. equity securities. (b) There is a permitted range for the allocation of the trust assets for the U.S. Pension Plans, excluding the defined benefit pension plan for Mountaineer employees, which is 5% less than and greater than the target allocation. Common collective trust funds in the U.S. Pension Plans primarily include investments in U.S., Non-U.S. and global (a mix of U.S. and Non-U.S.) equities, fixed income and short-term investments. The fair values of common collective trust funds and cash equivalents are valued at the NAV of units of the collective trusts. The NAVs, as provided by the trustee, are used as a practical expedient to estimate fair value based on the fair values of the underlying investments held by the funds less their liabilities. The fair values of the U.S. Pension Plans trust assets by asset class as of September 30, 2023 and 2022 are as follows: 2023 2022 U.S. Pension Plans: Domestic equity investments: UGI Corporation Common Stock $ 19 $ 26 Total domestic equity investments (a) 19 26 Common collective trust funds: U.S. equity index investments 120 113 Non-U.S. equity index investments 117 110 Global equity index investments 75 72 Bond index investments 183 177 Cash equivalents 8 10 Total common collective trust funds (b) 503 482 Alternative investments (b) 17 17 Total $ 539 $ 525 (a) Level 1 investments within the fair value hierarchy. (b) Assets measured at NAV and therefore excluded from the fair value hierarchy. The expected long-term rates of return on U.S. Pension Plans’ trust assets have been developed using a best estimate of expected returns, volatilities and correlations for each asset class. The estimates are based on historical capital market performance data and future expectations provided by independent consultants. Future expectations are determined by using simulations that provide a wide range of scenarios of future market performance. The market conditions in these simulations consider the long-term relationships between equities and fixed income as well as current market conditions at the start of the simulation. The expected rate begins with a risk-free rate of return with other factors being added such as inflation, duration, credit spreads and equity risk premiums. The rates of return derived from this process are applied to our target asset allocation to develop a reasonable return assumption. Defined Contribution Plans We sponsor 401(k) savings plans for eligible employees of UGI and certain of UGI’s domestic subsidiaries. Generally, participants in these plans may contribute a portion of their compensation on either a before-tax basis, or on both a before-tax and after-tax basis. These plans also provide for employer matching contributions at various rates. The cost of benefits under the savings plans totaled $22 in Fiscal 2023, $21 in Fiscal 2022 and $21 in Fiscal 2021. The Company also sponsors certain nonqualified supplemental defined contribution executive retirement plans. These plans generally provide supplemental benefits to certain executives that would otherwise be provided under retirement plans but are prohibited due to limitations imposed by the IRC. The Company makes payments to self-directed grantor trusts with respect to these supplemental defined contribution plans. Such payments during Fiscal 2023, Fiscal 2022 and Fiscal 2021 were not material. At September 30, 2023 and 2022, the total fair values of these grantor trust investment assets, which amounts are included in “Other assets” on the Consolidated Balance Sheets, were $9 and $7, respectively.

Utility Regulatory Assets and L

Utility Regulatory Assets and Liabilities and Regulatory Matters	12 Months Ended
	Sep. 30, 2023
Regulated Operations [Abstract]
Utility Regulatory Assets and Liabilities and Regulatory Matters	Note 9 — Utility Regulatory Assets and Liabilities and Regulatory Matters The following regulatory assets and liabilities associated with our Utilities reportable segment are included in our Consolidated Balance Sheets at September 30: 2023 2022 Regulatory assets (a): Income taxes recoverable $ 94 $ 83 Underfunded pension plans 111 114 Environmental costs 28 37 Deferred fuel and power costs 27 32 Removal costs, net 23 22 Other 64 52 Total regulatory assets $ 347 $ 340 Regulatory liabilities (a): Postretirement benefits $ 12 $ 11 Deferred fuel and power refunds 55 3 State income tax benefits — distribution system repairs 43 38 Excess federal deferred income taxes 254 279 Other 2 4 Total regulatory liabilities $ 366 $ 335 (a) Current regulatory assets are recorded in “Other current assets” on the Consolidated Balance Sheets. Regulatory liabilities are recorded in “Other current liabilities” and “Other noncurrent liabilities” on the Consolidated Balance Sheets. Other than removal costs, Utilities currently does not recover a rate of return on the regulatory assets included in the table above. Income taxes recoverable . This regulatory asset is the result of recording deferred tax liabilities pertaining to temporary tax differences principally as a result of the pass through to ratepayers of the tax benefit on accelerated tax depreciation for state income tax purposes, and the flow through of accelerated tax depreciation for federal income tax purposes for certain years prior to 1981. These deferred taxes have been reduced by deferred tax assets pertaining to utility deferred investment tax credits. Utilities has recorded regulatory income tax assets related to these deferred tax liabilities representing future revenues recoverable through the ratemaking process over the average remaining depreciable lives of the associated property ranging from 1 to approximately 65 years. Underfunded pension plans . This regulatory asset represents the portion of net actuarial losses and prior service costs (credits) associated with Gas Utility and Electric Utility pension benefits which are probable of being recovered through future rates based upon established regulatory practices. These regulatory assets are adjusted annually or more frequently under certain circumstances when the funded status of the plans is remeasured in accordance with GAAP. These costs are amortized over the average remaining future service lives of plan participants. Environmental costs . Environmental costs principally represent estimated probable future environmental remediation and investigation costs that PA Gas Utility expects to incur, primarily at MGP sites in Pennsylvania, in conjunction with a remediation COA with the PADEP. Pursuant to base rate orders, PA Gas Utility receives ratemaking recognition of its estimated environmental investigation and remediation costs associated with its environmental sites. This ratemaking recognition balances the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. The period over which PA Gas Utility expects to recover these costs will depend upon future remediation activity. For additional information on environmental costs, see Note 16. Removal costs, net . This regulatory asset represents costs incurred, net of salvage, associated with the retirement of depreciable utility plant of UGI Utilities. As required by PAPUC ratemaking, removal costs include actual costs incurred associated with asset retirement obligations. Consistent with prior ratemaking treatment, UGI Utilities expects to recover these costs over five years. Postretirement benefits . This regulatory liability represents the difference between amounts recovered through rates by PA Gas Utility and Electric Utility and actual costs incurred in accordance with accounting for postretirement benefits. A portion of this liability will be refunded to customers over the average remaining future service lives of plan participants. Another portion of this liability represents overcollections for which refund periods have been established within ratemaking proceedings. With respect to Gas Utility, postretirement benefit overcollections are generally being refunded to customers over a ten-year period beginning October 19, 2016. With respect to Electric Utility, the overcollections are being refunded to ratepayers over a 20-year period effective October 27, 2018. 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. The WVPSC, in an effort to mitigate the impact of WV Gas Utility’s 2022 PGA rate increase to customers, delayed the effective date in 2022 from November 1 to December 1 and deferred $12 of unrecovered gas costs in determining the rates to be charged to the various customer classes effective December 1, 2022. Additionally, in order to lower winter bills for residential customers, the WVPSC removed transportation and storage costs from the volumetric rate and created a fixed monthly pipeline demand charge applicable only to residential customers. On April 12, 2023, the WVPSC issued a final order that increased the PGA rate, which included the unrecovered gas cost balance initially deferred in the interim order, and continued the fixed monthly demand charge for residential customers. 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) gains on such contracts at September 30, 2023 and 2022 were $(2) and $5, respectively. State income tax benefits — distribution system repairs. This regulatory liability represents Pennsylvania state income tax benefits, net of federal benefit, resulting from the deduction for income tax purposes of repair and maintenance costs associated with UGI Utilities’ assets that are capitalized for regulatory and GAAP reporting. The tax benefits associated with these repair and maintenance deductions will be reflected as a reduction to income tax expense over the remaining tax lives of the related book assets. Excess federal deferred income taxes. This regulatory liability is the result of remeasuring Utilities’ federal deferred income tax liabilities on utility plant due to the enactment of the TCJA on December 22, 2017. In order for our utility assets to continue to be eligible for accelerated tax depreciation, current law requires that excess federal deferred income taxes resulting from the remeasurement be amortized no more rapidly than over the remaining lives of the assets that gave rise to the excess federal deferred income taxes, ranging from 1 year to approximately 65 years. This regulatory liability has been increased to reflect the tax benefit generated by the amortization of the excess deferred federal income taxes and is being amortized and credited to tax expense. Other . Other regulatory assets and liabilities comprise a number of deferred items including, among others, certain fair value adjustments related to the Mountaineer Acquisition, certain information technology costs, energy efficiency conservation costs and rate case expenses. 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 will not be 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%, 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). On February 8, 2021, Electric Utility filed a request with the PAPUC to increase its annual base distribution revenues by $9. On October 28, 2021, the PAPUC issued a final order approving a settlement that permitted Electric Utility, effective November 9, 2021, to increase its base distribution revenues by $6. Mountaineer. On July 31, 2023, Mountaineer submitted its 2023 IREP filing to the WVPSC requesting recovery of $10, an increase of $6, for costs associated with capital investments after December 31, 2022, that total $131, including $67 in calendar year 2024. With new base rates expected to be effective January 1, 2024, revenues from IREP rates would decrease by $12. The filing included capital investments totaling $383 over the 2024 - 2028 period. On March 6, 2023, Mountaineer submitted a base rate case filing with the WVPSC seeking a net revenue increase of $20, which consisted of an increase in base rates of $38 and a decrease in the IREP rates of $18 annually to be effective on April 5, 2023. On March 31, 2023, the WVPSC suspended the effective date of the requested rate change increase until January 1, 2024 to allow for a full review of the filing. 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. An order from the Commission is expected in December and new rates will take effect on January 1, 2024.

Inventories

Inventories	12 Months Ended
	Sep. 30, 2023
Inventory Disclosure [Abstract]
Inventories	Note 10 — Inventories Inventories comprise the following at September 30: 2023 2022 Non-utility LPG and natural gas $ 212 $ 335 Gas Utility natural gas 55 166 Energy certificates 64 70 Materials, supplies and other 102 94 Total inventories $ 433 $ 665

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Sep. 30, 2023
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Note 11 — Property, Plant and Equipment Property, plant and equipment comprise the following at September 30: 2023 2022 Estimated Useful Life Utility: Distribution $ 5,204 $ 4,746 Transmission 123 123 General and other 660 557 Work in process 95 124 Total Utility 6,082 5,550 Non-utility: Land 174 179 Buildings and improvements 418 426 10 - 40 years Transportation equipment 238 234 3 - 10 years Equipment, primarily cylinders and tanks 3,903 3,645 5 - 30 years Electric generation 190 216 25 - 40 years Pipeline and related assets 1,577 1,523 25 - 40 years Other 390 380 1 - 12 years Work in process 156 53 Total non-utility 7,046 6,656 Total property, plant and equipment $ 13,128 $ 12,206 The average composite depreciation rates at our Gas Utility and Electric Utility were as follows: 2023 2022 2021 Regulated natural gas utilities 2.4 % 2.6 % 2.6 % Electric Utility 2.3 % 2.4 % 2.3 % Depreciation expense totaled $476, $460 and $437 for Fiscal 2023, Fiscal 2022 and Fiscal 2021, respectively.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Sep. 30, 2023
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	Note 12 — Goodwill and Intangible Assets Changes in the carrying amount of goodwill by reportable segment are as follows: AmeriGas UGI International Midstream & Marketing Utilities Total Balance September 30, 2021 $ 2,004 $ 993 $ 336 $ 437 $ 3,770 Purchase accounting adjustments — — — (5) (5) Foreign currency translation — (153) — — (153) Balance September 30, 2022 2,004 840 336 432 3,612 Impairment of goodwill (656) — — — (656) Acquisitions — 3 — — 3 Foreign currency translation — 68 — — 68 Balance September 30, 2023 $ 1,348 $ 911 $ 336 $ 432 $ 3,027 During the third quarter of Fiscal 2023, the Company identified interim impairment indicators related to goodwill within the AmeriGas Propane reporting unit: (1) AmeriGas Partners issued $500 of Senior Notes at an interest rate of 9.375%, which was significantly higher than the interest rates on the other AmeriGas Propane debt obligations; and (2) financial projections for the AmeriGas Propane reporting unit were reduced significantly compared to previous forecasts following declines in gross margins and customer retention and higher operating expenses. The Company concluded that these events constituted triggering events that indicate that the AmeriGas Propane goodwill may be impaired and, as such, performed an interim impairment test of its goodwill as of May 31, 2023. Using level 3 inputs, we performed a quantitative assessment of the AmeriGas Propane reporting unit using a weighting of the income and market approaches to determine its fair value. With respect to the income approach, management used a discounted cash flow (“DCF”) method, using unobservable inputs. The significant assumptions in our DCF model include projected EBITDA and a discount rate (and estimates in the discount rate inputs). With respect to the market approach, management used recent transaction market multiples for similar companies in the U.S. The resulting estimates of fair value from the income approach and the market approach were then weighted equally in determining the overall estimated fair value of AmeriGas Propane. Based on our evaluation, the estimated fair value of the AmeriGas Propane reporting unit was determined to be less than its carrying value. As a result, the Company recorded a non-cash pre-tax goodwill impairment charge of $656, included in “Impairment of goodwill” on the Fiscal 2023 Consolidated Statement of Income, to reduce the carrying value of AmeriGas Propane to its fair value. The Company calculated the deferred tax effect using the simultaneous equation method. The performance of the AmeriGas Propane reporting unit and the potential for future developments in the global economic environment, including the prospect of higher interest rates, introduces a heightened risk for additional impairment in the AmeriGas Propane reporting unit. If there is continued deterioration in the results of operations, a portion or all of the remaining recorded goodwill for the AmeriGas Propane reporting unit, which was $1.3 billion as of September 30, 2023, could be subject to further impairment. Intangible assets comprise the following at September 30: 2023 2022 Customer relationships $ 977 $ 1,006 Trademarks and tradenames 4 3 Noncompete agreements and other 26 71 Accumulated amortization (602) (621) Intangible assets, net (definite-lived) 405 459 Trademarks and tradenames (indefinite-lived) 38 41 Total intangible assets, net $ 443 $ 500 During Fiscal 2023, the Company recognized a $10 non-cash, pre-tax impairment charge related to customer relationships intangible assets and indefinite-lived tradenames at DVEP in connection with the wind-down of the energy marketing business in the Netherland s (see Note 5). D uring Fiscal 2021, the Company recognized a $20 non-cash, pre-tax impairment charge related to a customer relationship intangible asset at DVEP resulting from a decline in anticipated volumes attributable to a historical customer. These charges are reflected in “Operating and administrative expenses” on the Consolidated Statements of Income. Amortization expense of intangible assets wa s $56, $61 and $76 for Fiscal 2023, Fiscal 2022 and Fiscal 2021, respectively. Estimated amortization expense of intangible assets during the next five fiscal years is as follows: Fiscal 2024 — $53; Fiscal 2025 — $51; Fiscal 2026 — $50; Fiscal 2027 — $27; Fiscal 2028 — $18.

Equity

Equity	12 Months Ended
	Sep. 30, 2023
Equity [Abstract]
Equity	Note 13 — Equity On February 2, 2022, UGI’s Board of Directors authorized an extension of an existing share repurchase program for up to 8,000,000 shares of UGI Corporation Common Stock for an additional four-year period, expiring February 2026. Pursuant to the Board authorization, during Fiscal 2023 and Fiscal 2022 the Company purchased and placed in treasury stock 600,000 shares and 900,000 shares at a total cost of $22 and $38, respectively. There were no such repurchases during Fiscal 2021. UGI Preferred Stock and Common Stock share activity for Fiscal 2023, Fiscal 2022 and Fiscal 2021 is as follows: Preferred Stock Common Stock Issued/Outstanding Issued Treasury Outstanding Balance at September 30, 2020 — 209,514,044 (1,159,606) 208,354,438 Issued: Equity Unit Offering 220,000 — — — Employee and director plans — 329,252 554,315 883,567 Reacquired common stock – employee and director plans — — (21,870) (21,870) Balance at September 30, 2021 220,000 209,843,296 (627,161) 209,216,135 Issued: Employee and director plans — 717,198 799,152 1,516,350 Repurchases of common stock — — (900,000) (900,000) Reacquired common stock – employee and director plans — — (250,273) (250,273) Balance at September 30, 2022 220,000 210,560,494 (978,282) 209,582,212 Issued: Employee and director plans — 345,558 167,313 512,871 Repurchases of common stock — — (600,000) (600,000) Balance at September 30, 2023 220,000 210,906,052 (1,410,969) 209,495,083 UGI also has 5,000,000 shares of UGI Series Preference Stock authorized for issuance. UGI had no shares of UGI Series Preference Stock outstanding at September 30, 2023 or 2022. Issuance of Equity Units On May 25, 2021, the Company issued 2.2 million Equity Units with a total notional value of $220. Each Equity Unit has a stated amount of $100 and consists of (i) a 10% undivided beneficial ownership interest in one share of Convertible Preferred Stock with a liquidation preference of $1,000 per share and (ii) a 2024 Purchase Contract. The Company received approximately $213 of proceeds from the issuance of the Equity Units, net of offering expenses and underwriting costs and commissions, and issued 220,000 shares of Convertible Preferred Stock which was recorded in “Preferred stock” on the accompanying Consolidated Balance Sheet. The proceeds were used to pay a portion of the purchase price for the Mountaineer Acquisition and related fees and expenses, and for general corporate purposes. During the second quarter of Fiscal 2022, the Company reclassified certain amounts on the Consolidated Balance Sheet and Consolidated Statement of Changes in Equity related to the accounting for the Equity Units. Convertible Preferred Stock. Holders of the Convertible Preferred Stock will generally have no voting rights, except under the limited circumstances as described in the Equity Unit Agreements, and will be entitled to receive cumulative dividends at an initial annual rate of 0.125% when, as, and if declared by the UGI Board of Directors, payable quarterly in arrears on March 1, June 1, September 1 and December 1, commencing September 1, 2021. The Company may elect to pay such dividends in cash, shares of UGI’s common stock or a combination of cash and shares of UGI’s common stock. Unless all accumulated and unpaid dividends on the Convertible Preferred Stock for prior completed dividend periods have been declared and paid, the Company may not make any distributions on, or repurchase, any of its capital stock ranking equal or junior to the Convertible Preferred Stock as to dividends or upon liquidation, subject to certain exceptions. The Convertible Preferred Stock has no maturity date and will remain outstanding unless converted by holders or redeemed by the Company. The Company has the option to redeem all or a portion of the Convertible Preferred Stock at any time, and from time to time, on or after September 3, 2024, for cash at a redemption price equal to the liquidation preference of the Convertible Preferred Stock being redeemed plus any accumulated and unpaid dividends. Each share of Convertible Preferred Stock may be converted at the option of the holders on and after June 1, 2024, only after it has been separated from the Equity Units and, prior to June 1, 2024, only under limited circumstances in connection with a fundamental change, as defined in the Equity Unit Agreements. The Company will settle conversions by paying or delivering (i) one share of UGI’s 0.125% Series B preferred stock (or, for conversions in connection with a redemption of the Convertible Preferred Stock, up to $1,000 per share in cash plus all accumulated but unpaid dividends to, but excluding, the payment date immediately preceding the relevant conversion date) per share of Convertible Preferred Stock being converted; and (ii) to the extent the conversion value exceeds the liquidation preference of the Convertible Preferred Stock, shares of UGI’s common stock. The conversion rate is initially 19.0215 shares of UGI’s common stock per one share of Convertible Preferred Stock, which is equivalent to an initial conversion price of approximately $52.57 per share of UGI’s common stock. At September 30, 2023, 2022 and 2021, there were 220,000 shares of Series B preferred stock authorized for issuance pursuant to the settlement terms discussed above. The Convertible Preferred Stock can be remarketed during either (i) an optional remarketing period beginning on, and including, March 1, 2024 and ending on, and including, May 13, 2024 or (ii) a final remarketing period beginning on, and including, May 23, 2024 and ending on, and including, May 30, 2024. In connection with a successful remarketing, the conversion rate and dividend rate of the Convertible Preferred Stock may be increased, and the earliest redemption date for the Convertible Preferred Stock may be changed to a later date that is on or before August 29, 2025. 2024 Purchase Contracts. The 2024 Purchase Contracts obligate the holders to pay $100 to UGI to purchase a variable number of shares of UGI common stock on the purchase contract settlement date, which is scheduled to occur on June 1, 2024. The number of shares of UGI common stock to be issued upon settlement of each 2024 Purchase Contract on the purchase contract settlement date will be equal to $100 divided by the market value per share of UGI common stock, which will be determined over a market value averaging period preceding the settlement date, subject to a maximum settlement rate of 2.2826 shares of UGI common stock per 2024 Purchase Contract, subject to adjustment. The initial maximum settlement rate of the 2024 Purchase Contracts is approximately equal to $100 divided by the last reported sale price of $43.81 per share of UGI common stock on May 17, 2021. Absent any fundamental changes, as defined in the Equity Unit Agreements, the holders can settle the 2024 Purchase Contracts early, subject to certain exceptions and conditions. Upon early settlement of any 2024 Purchase Contracts, other than in connection with a fundamental change, the Company will deliver the number of shares of UGI common stock equal to 85% of the number of shares of UGI common stock that would have otherwise been deliverable. The Company will pay holders of the 2024 Purchase Contracts quarterly contract adjustment payments at an annual rate of 7.125%, payable quarterly in arrears on March 1, June 1, September 1 and December 1, commencing September 1, 2021. The Company may elect to pay such contract adjustment payments in cash, shares of UGI common stock or a combination of cash and shares of UGI common stock. The Company may defer the contract adjustment payments for one or more consecutive periods but generally not beyond the purchase contract settlement date. If contract adjustment payments are deferred, the Company will be subject to certain dividend, distribution, and other restrictions related to its capital stock as defined in the Equity Unit Agreements. The present value of the quarterly contract adjustment payments liability was $45 upon issuance of the Equity Units and is recorded in “Other current liabilities” and “Other noncurrent liabilities” (with a corresponding reduction to “UGI Preferred Stock”) on the Consolidated Balance Sheet. As each quarterly contract adjustment payment is made, the related liability is reduced and the difference between the cash payment and the present value will accrete to “Interest expense” on the Consolidated Statements of Income. This accretion was not material during Fiscal 2023, Fiscal 2022, and Fiscal 2021.

Equity-Based Compensation

Equity-Based Compensation	12 Months Ended
	Sep. 30, 2023
Share-Based Payment Arrangement [Abstract]
Equity-Based Compensation	Note 14 — Equity-Based Compensation The Company grants equity-based awards to employees and non-employee directors comprising UGI stock options and, UGI Common Stock-based equity instruments. We recognized total pre-tax equity-based compensation expense of $17 ($13 after-tax), $15 ($11 after-tax) and $21 ($15 after-tax) in Fiscal 2023, Fiscal 2022 and Fiscal 2021, respectively. UGI Equity-Based Compensation Plans and Awards. On January 29, 2021, the Company’s shareholders approved the 2021 IAP. Under the 2021 IAP, awards representing up to 20,500,000 shares of UGI Common Stock may be granted. UGI Unit Awards granted to employees and non-employee directors, including dividend equivalents, are settled in shares of UGI Common Stock and cash. The 2021 IAP supersedes and replaces the 2013 OICP for awards granted on or after February 1, 2021. The terms and conditions of the 2013 OICP will continue to govern any outstanding awards granted thereunder. Similar to the 2013 OICP, under the 2021 IAP, we may grant options to acquire shares of UGI Common Stock, SARs, UGI Units (comprising “Stock Units” and “UGI Performance Units”), other equity-based awards and cash to key employees and non-employee directors. The exercise price for options may not be less than the fair market value on the grant date. Awards granted under the 2021 IAP may vest immediately or ratably over a period of years, and stock options can be exercised no later than ten years from the grant date. Except in the event of retirement, death or disability, each grant, unless paid, will terminate when the participant ceases to be employed. There are certain change of control and retirement eligibility conditions that, if met, generally result in accelerated vesting or elimination of further service requirements. There we re 16,014,039 s hares of Common Stock available for future grants under the 2021 IAP at September 30, 2023 . UGI Stock Option Awards . We measure the fair value of stock options using a Black-Scholes option pricing model that uses certain key assumptions for such options related to the expected life, volatility, dividend yield and the Company’s risk-free rate at the valuation date. The per share weighted average fair value of stock options granted under our option plans w as $9.31, $8.47 and $6.05 in Fiscal 2023, Fiscal 2022 and Fiscal 2021, respectively. As of September 30, 2023, there wa s $5 of unrecognized compensation cost associated with unvested stock options that is expected to be recognized over a weighted-average period of 1.9 years. There were 8,358,125 stock options outstanding at September 30, 2023, of which, 7,122,824 stock options were exercisable with a weighted-average option price of $42.79. UGI Unit Awards . Awards of UGI Stock Units and UGI Performance Units subject to market-based conditions entitle the grantee to shares of UGI Common Stock or cash once the service condition is met and, with respect to UGI Performance Unit subject to market-based conditions, subject to UGI’s TSR percentile rank relative to companies in the UGI comparator group. Recipients of UGI Performance Unit subject to market-based conditions are awarded a target number of such awards. The number of UGI Performance Units subject to market-based conditions ultimately paid at the end of the performance period (generally 3 years) may be higher or lower than the target amount, or even zero, based on UGI’s TSR percentile rank relative to companies in the UGI comparator group. Grantees may receive 0% to 200% of the target award granted. Awards granted vest ratably over the performance period. In January 2023, the Company granted the UGI EPS Performance Unit awards. UGI EPS Performance Unit awards entitle the grantee to shares of UGI Common Stock or cash once the service condition is met and subject to the achievement of a UGI EPS goal, which is a non-market performance condition. UGI EPS Performance Unit grant recipients are awarded a target number of UGI EPS Performance Units. The number of UGI EPS Performance Units ultimately paid at the end of the service period may be higher or lower than the target amount, or even zero, based upon the actual EPS performance. Grantees may receive 0% to 200% of the target award granted. The EPS performance period for the UGI EPS Performance Unit awards granted in January 2023 is October 1, 2022 through September 30, 2024. The fair value of UGI Stock Units on the grant date is equal to the market price of UGI Stock on the grant date plus the fair value of dividend equivalents if applicable. The fair value of UGI Performance Units is estimated using a Monte Carlo valuation model. The fair value associated with the target award is accounted for as equity and the fair value of the award over the target, as well as all dividend equivalents, is accounted for as a liability. The fair value of UGI EPS Performance Units is equal to the market price of UGI stock on the grant date plus the fair value of dividend equivalents if applicable. The weighted-average grant date fair value of UGI Stock Units, UGI Performance Units and EPS Performance Units granted to employees during Fiscal 2023, Fiscal 2022, and Fiscal 2021 was $44.62, $51.24 and $41.41, respectively. As of September 30, 2023, there was a total of $25 unrecognized compensation cost associated with UGI Unit awards outstanding that is expected to be recognized over a weighted-average per iod of 2.0 years. As of September 30, 2023, there were 1,502,253 UGI Unit awards outstanding with a weighted-average grant-date fair value of $43.09 pe r share.

Leases

Leases	12 Months Ended
	Sep. 30, 2023
Leases [Abstract]
Leases	Note 15 — Leases Lessee We lease various buildings and other facilities, real estate, vehicles, rail cars and other equipment, the majority of which are operating leases. We determine if a contract is or contains a lease by evaluating whether the contract explicitly or implicitly identifies an asset, whether we have the right to obtain substantially all of the economic benefits of the identified leased asset and to direct its use. ROU assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. We recognize ROU assets at the lease commencement date at the value of the lease liability adjusted for any prepayments, lease incentives received, and initial direct costs incurred. Lease liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term. These payments are discounted using the discount rate implicit in the lease, when available. We apply an incremental borrowing rate, which is developed utilizing a credit notching approach based on information available at the lease commencement date, to substantially all of our leases as the implicit rate is often not available. Lease expense is recognized on a straight-line basis over the expected lease term. Renewal and termination options are not included in the lease term unless we are reasonably certain that such options will be exercised. Leases with an original lease term of one year or less, including consideration of any renewal options assumed to be exercised, are not included in the Consolidated Balance Sheets. Certain lease arrangements, primarily fleet vehicle leases with lease terms of one Certain leasing arrangements require variable payments that are dependent on asset usage or are based on changes in index rates, such as the Consumer Price Index. The variable payments component of such leases cannot be determined at lease commencement and is not recognized in the measurement of ROU assets or lease liabilities, but is recognized in earnings in the period in which the obligation occurs. Sale-leaseback transaction. During the fourth quarter of Fiscal 2023, AmeriGas OLP completed a sale-leaseback transaction with an independent third party for the land, building and improvements of an office and service center located in Gardena, California. The office and service center was leased back to AmeriGas OLP under an operating lease agreement having an initial six-year term with an option to renew. In conjunction with the transaction, AmeriGas OLP received approximately $32 in cash proceeds which resulted in a pre-tax gain of $29, reflected in Other operating income, net on the Fiscal 2023 Consolidated Statement of Income. ROU assets and lease liabilities recorded in the Consolidated Balance Sheets as of September 30 are as follows: 2023 2022 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 420 $ 368 Other assets Finance lease ROU assets 50 48 Property, plant and equipment Total ROU assets $ 470 $ 416 Lease liabilities: Operating lease liabilities — current $ 87 $ 82 Other current liabilities Operating lease liabilities — noncurrent 340 294 Other noncurrent liabilities Finance lease liabilities — current 5 4 Current maturities of long-term debt Finance lease liabilities — noncurrent 45 41 Long-term debt Total lease liabilities $ 477 $ 421 The components of lease cost for Fiscal 2023, Fiscal 2022 and Fiscal 2021 are as follows: 2023 2022 2021 Operating lease cost $ 104 $ 96 $ 101 Finance lease cost: Amortization of ROU assets 3 4 4 Interest on lease liabilities 3 3 3 Variable lease cost 2 6 4 Short-term lease cost 4 2 2 Total lease cost $ 116 $ 111 $ 114 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statements of Cash Flows during Fiscal 2023, Fiscal 2022 and Fiscal 2021: 2023 2022 2021 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 103 $ 95 $ 99 Operating cash flows — finance leases $ 3 $ 3 $ 3 Financing cash flows — finance leases $ 1 $ 2 $ 3 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities $ 136 $ 72 $ 85 ROU assets obtained in exchange for finance lease liabilities $ 6 $ 2 $ 1 The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2023 2022 Operating leases 7.1 6.0 Finance leases 5.3 3.7 Weighted-average discount rate (%) 2023 2022 Operating leases 4.5% 3.6% Finance leases 2.2% 1.8% Expected annual lease payments based on maturities of operating and finance leases, as well as a reconciliation to the lease liabilities on the Consolidated Balance Sheet, as of September 30, 2023, were as follows: 2024 2025 2026 2027 2028 After 2028 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 104 $ 86 $ 72 $ 61 $ 49 $ 130 $ 502 $ (75) $ 427 Finance leases $ 5 $ 5 $ 5 $ 4 $ 4 $ 76 $ 99 $ (49) $ 50 Approximately 80% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2023, operating and finance leases that had not yet commenced were not material. Lessor
Leases	Note 15 — Leases Lessee We lease various buildings and other facilities, real estate, vehicles, rail cars and other equipment, the majority of which are operating leases. We determine if a contract is or contains a lease by evaluating whether the contract explicitly or implicitly identifies an asset, whether we have the right to obtain substantially all of the economic benefits of the identified leased asset and to direct its use. ROU assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. We recognize ROU assets at the lease commencement date at the value of the lease liability adjusted for any prepayments, lease incentives received, and initial direct costs incurred. Lease liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term. These payments are discounted using the discount rate implicit in the lease, when available. We apply an incremental borrowing rate, which is developed utilizing a credit notching approach based on information available at the lease commencement date, to substantially all of our leases as the implicit rate is often not available. Lease expense is recognized on a straight-line basis over the expected lease term. Renewal and termination options are not included in the lease term unless we are reasonably certain that such options will be exercised. Leases with an original lease term of one year or less, including consideration of any renewal options assumed to be exercised, are not included in the Consolidated Balance Sheets. Certain lease arrangements, primarily fleet vehicle leases with lease terms of one Certain leasing arrangements require variable payments that are dependent on asset usage or are based on changes in index rates, such as the Consumer Price Index. The variable payments component of such leases cannot be determined at lease commencement and is not recognized in the measurement of ROU assets or lease liabilities, but is recognized in earnings in the period in which the obligation occurs. Sale-leaseback transaction. During the fourth quarter of Fiscal 2023, AmeriGas OLP completed a sale-leaseback transaction with an independent third party for the land, building and improvements of an office and service center located in Gardena, California. The office and service center was leased back to AmeriGas OLP under an operating lease agreement having an initial six-year term with an option to renew. In conjunction with the transaction, AmeriGas OLP received approximately $32 in cash proceeds which resulted in a pre-tax gain of $29, reflected in Other operating income, net on the Fiscal 2023 Consolidated Statement of Income. ROU assets and lease liabilities recorded in the Consolidated Balance Sheets as of September 30 are as follows: 2023 2022 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 420 $ 368 Other assets Finance lease ROU assets 50 48 Property, plant and equipment Total ROU assets $ 470 $ 416 Lease liabilities: Operating lease liabilities — current $ 87 $ 82 Other current liabilities Operating lease liabilities — noncurrent 340 294 Other noncurrent liabilities Finance lease liabilities — current 5 4 Current maturities of long-term debt Finance lease liabilities — noncurrent 45 41 Long-term debt Total lease liabilities $ 477 $ 421 The components of lease cost for Fiscal 2023, Fiscal 2022 and Fiscal 2021 are as follows: 2023 2022 2021 Operating lease cost $ 104 $ 96 $ 101 Finance lease cost: Amortization of ROU assets 3 4 4 Interest on lease liabilities 3 3 3 Variable lease cost 2 6 4 Short-term lease cost 4 2 2 Total lease cost $ 116 $ 111 $ 114 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statements of Cash Flows during Fiscal 2023, Fiscal 2022 and Fiscal 2021: 2023 2022 2021 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 103 $ 95 $ 99 Operating cash flows — finance leases $ 3 $ 3 $ 3 Financing cash flows — finance leases $ 1 $ 2 $ 3 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities $ 136 $ 72 $ 85 ROU assets obtained in exchange for finance lease liabilities $ 6 $ 2 $ 1 The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2023 2022 Operating leases 7.1 6.0 Finance leases 5.3 3.7 Weighted-average discount rate (%) 2023 2022 Operating leases 4.5% 3.6% Finance leases 2.2% 1.8% Expected annual lease payments based on maturities of operating and finance leases, as well as a reconciliation to the lease liabilities on the Consolidated Balance Sheet, as of September 30, 2023, were as follows: 2024 2025 2026 2027 2028 After 2028 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 104 $ 86 $ 72 $ 61 $ 49 $ 130 $ 502 $ (75) $ 427 Finance leases $ 5 $ 5 $ 5 $ 4 $ 4 $ 76 $ 99 $ (49) $ 50 Approximately 80% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2023, operating and finance leases that had not yet commenced were not material. Lessor
Leases	Note 15 — Leases Lessee We lease various buildings and other facilities, real estate, vehicles, rail cars and other equipment, the majority of which are operating leases. We determine if a contract is or contains a lease by evaluating whether the contract explicitly or implicitly identifies an asset, whether we have the right to obtain substantially all of the economic benefits of the identified leased asset and to direct its use. ROU assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. We recognize ROU assets at the lease commencement date at the value of the lease liability adjusted for any prepayments, lease incentives received, and initial direct costs incurred. Lease liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term. These payments are discounted using the discount rate implicit in the lease, when available. We apply an incremental borrowing rate, which is developed utilizing a credit notching approach based on information available at the lease commencement date, to substantially all of our leases as the implicit rate is often not available. Lease expense is recognized on a straight-line basis over the expected lease term. Renewal and termination options are not included in the lease term unless we are reasonably certain that such options will be exercised. Leases with an original lease term of one year or less, including consideration of any renewal options assumed to be exercised, are not included in the Consolidated Balance Sheets. Certain lease arrangements, primarily fleet vehicle leases with lease terms of one Certain leasing arrangements require variable payments that are dependent on asset usage or are based on changes in index rates, such as the Consumer Price Index. The variable payments component of such leases cannot be determined at lease commencement and is not recognized in the measurement of ROU assets or lease liabilities, but is recognized in earnings in the period in which the obligation occurs. Sale-leaseback transaction. During the fourth quarter of Fiscal 2023, AmeriGas OLP completed a sale-leaseback transaction with an independent third party for the land, building and improvements of an office and service center located in Gardena, California. The office and service center was leased back to AmeriGas OLP under an operating lease agreement having an initial six-year term with an option to renew. In conjunction with the transaction, AmeriGas OLP received approximately $32 in cash proceeds which resulted in a pre-tax gain of $29, reflected in Other operating income, net on the Fiscal 2023 Consolidated Statement of Income. ROU assets and lease liabilities recorded in the Consolidated Balance Sheets as of September 30 are as follows: 2023 2022 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 420 $ 368 Other assets Finance lease ROU assets 50 48 Property, plant and equipment Total ROU assets $ 470 $ 416 Lease liabilities: Operating lease liabilities — current $ 87 $ 82 Other current liabilities Operating lease liabilities — noncurrent 340 294 Other noncurrent liabilities Finance lease liabilities — current 5 4 Current maturities of long-term debt Finance lease liabilities — noncurrent 45 41 Long-term debt Total lease liabilities $ 477 $ 421 The components of lease cost for Fiscal 2023, Fiscal 2022 and Fiscal 2021 are as follows: 2023 2022 2021 Operating lease cost $ 104 $ 96 $ 101 Finance lease cost: Amortization of ROU assets 3 4 4 Interest on lease liabilities 3 3 3 Variable lease cost 2 6 4 Short-term lease cost 4 2 2 Total lease cost $ 116 $ 111 $ 114 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statements of Cash Flows during Fiscal 2023, Fiscal 2022 and Fiscal 2021: 2023 2022 2021 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 103 $ 95 $ 99 Operating cash flows — finance leases $ 3 $ 3 $ 3 Financing cash flows — finance leases $ 1 $ 2 $ 3 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities $ 136 $ 72 $ 85 ROU assets obtained in exchange for finance lease liabilities $ 6 $ 2 $ 1 The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2023 2022 Operating leases 7.1 6.0 Finance leases 5.3 3.7 Weighted-average discount rate (%) 2023 2022 Operating leases 4.5% 3.6% Finance leases 2.2% 1.8% Expected annual lease payments based on maturities of operating and finance leases, as well as a reconciliation to the lease liabilities on the Consolidated Balance Sheet, as of September 30, 2023, were as follows: 2024 2025 2026 2027 2028 After 2028 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 104 $ 86 $ 72 $ 61 $ 49 $ 130 $ 502 $ (75) $ 427 Finance leases $ 5 $ 5 $ 5 $ 4 $ 4 $ 76 $ 99 $ (49) $ 50 Approximately 80% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2023, operating and finance leases that had not yet commenced were not material. Lessor

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Sep. 30, 2023
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 16 — 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 September 30, 2023 and 2022, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the COA totaled $52 and $53, respectively. We do not expect the costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to UGI Utilities’ results of operations because UGI Utilities receives ratemaking recovery of actual environmental investigation and remediation costs associated with the sites covered by the COA. This ratemaking recognition reconciles the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. As such, UGI Utilities has recorded an associated regulatory asset for these costs because recovery of these costs from customers is probable (see Note 9). 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 September 30, 2023 and 2022, 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. That report identifies a fracture in a retired UGI 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.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Sep. 30, 2023
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 17 — 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 as described in Note 2: Asset (Liability) Level 1 Level 2 Level 3 Total September 30, 2023: Derivative instruments: Assets: Commodity contracts (c) $ 117 $ 115 $ — $ 232 Foreign currency contracts $ — $ 38 $ — $ 38 Interest rate contracts $ — $ 28 $ — $ 28 Liabilities: Commodity contracts (c) $ (193) $ (81) $ — $ (274) Foreign currency contracts $ — $ (2) $ — $ (2) Non-qualified supplemental postretirement grantor trust investments (a) $ 39 $ — $ — $ 39 September 30, 2022 Derivative instruments: Assets: Commodity contracts (b) $ 938 $ 1,268 $ 27 $ 2,233 Foreign currency contracts $ — $ 119 $ — $ 119 Interest rate contracts $ — $ 66 $ — $ 66 Liabilities: Commodity contracts (b) $ (377) $ (136) $ — $ (513) Foreign currency contracts $ — $ (2) $ — $ (2) Non-qualified supplemental postretirement grantor trust investments (a) $ 43 $ — $ — $ 43 (a) Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans (see Note 8). (b) Includes derivative assets and liabilities associated with the October 2022 sale of UGI International energy marketing business located in the U.K., classified as held for sale (see Note 5). (c) 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 our Level 3 natural gas commodity contracts at September 30, 2022 attributable to our UGI International operations have been determined using unobservable inputs in an illiquid market and ranged from $7 to $27 given the available inputs considered. The fair values of investments held in grantor trusts are derived from quoted market prices as substantially all of the investments in these trusts have active markets. Nonrecurring Fair Value Measurements During the quarter ended June 30, 2023, the Company performed an interim goodwill impairment test for its AmeriGas Propane reporting unit, which resulted in a non-cash pre-tax goodwill impairment charge of $656 to reduce the carrying value of AmeriGas Propane to its fair value as of May 31, 2023. See Note 12 for further information on the results of the impairment test including the key assumptions used to determine the fair value of the AmeriGas Propane reporting unit. 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: 2023 2022 Carrying amount $ 6,647 $ 6,665 Estimated fair value $ 6,238 $ 6,189

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Sep. 30, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Note 18 — 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 9 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. 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. 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. In March 2023, in connection with the Energy Services Amended Term Loan Credit Agreement, Energy Services terminated and settled its existing interest rate swap associated with the Energy Services Term Loan Credit Agreement (see Note 6). 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 September 30, 2023, the amount of pre-tax net gains associated with interest rate hedges expected to be reclassified into earnings during the next twelve months is $46. 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 (expense) income, net” on the 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. Concurrent with the repayment of UGI International’s 3.25% Senior Notes on December 7, 2021, we settled an associated net investment hedge having a notional value of €93. Additionally, in May 2022, we restructured certain net investment hedges associated with anticipated foreign currency denominated dividends. Cash flows from these settlements are included in cash flows from investing activities on the Consolidated Statements of Cash Flows. 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 (losses) gains associated with these net investment hedges in the foreign currency component of AOCI totaling $(57), $123 and $9 during Fiscal 2023, Fiscal 2022, and Fiscal 2021, respectively. Quantitative Disclosures Related to Derivative Instruments The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at September 30, 2023 and 2022 and the final settlement dates of the Company's open derivative contracts as of September 30, 2023, but excluding those derivatives that qualified for the NPNS exception: Notional Amounts September 30, Type Units Settlements Extending Through 2023 2022 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms September 2024 38 19 Non-utility Operations LPG swaps Gallons February 2026 727 874 Natural gas futures, forward, basis swap, options and pipeline contracts (a) Dekatherms December 2027 338 363 Electricity forward and futures contracts Kilowatt hours December 2026 1,260 2,446 Interest Rate Risk: Interest rate swaps Euro March 2026 € 300 € 300 Interest rate swaps USD September 2026 $ 1,270 $ 1,358 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD September 2026 $ 425 $ 465 Net investment hedge forward foreign exchange contracts Euro December 2026 € 256 € 411 (a) Amounts at September 30, 2023 and 2022 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 September 30, 2023, 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 $298. 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 September 30, 2023, we had received cash collateral from derivative instrument counterparties totaling $40. 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 September 30, 2023, 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 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 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, as of September 30: 2023 2022 Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 14 $ 57 Interest rate contracts 28 66 42 123 Derivatives subject to PGC and DS mechanisms: Commodity contracts 6 31 Derivatives not designated as hedging instruments: Commodity contracts (a) 226 2,202 Foreign currency contracts 24 62 250 2,264 Total derivative assets – gross 298 2,418 Gross amounts offset in the balance sheet (124) (295) Cash collateral received (40) (398) Total derivative assets – net $ 134 $ 1,725 Derivative liabilities: Derivatives subject to PGC and DS mechanisms: Commodity contracts $ (8) $ (26) Derivatives not designated as hedging instruments: Commodity contracts (a) (266) (487) Foreign currency contracts (2) (2) (268) (489) Total derivative liabilities – gross (276) (515) Gross amounts offset in the balance sheet 124 295 Cash collateral pledged 53 7 Total derivative liabilities – net $ (99) $ (213) (a) Includes certain derivative contracts associated with UGI International energy marketing business transactions (see Note 5) that are classified as held for sale on the Consolidated Balance Sheets at September 30, 2023 and 2022. At September 30, 2023 and 2022, there were $10 and $295 of derivative assets, respectively, included in Held for sale assets and $12 and $19 of derivative liabilities, respectively, included in Held for sale liabilities, on the Consolidated Balance Sheets. Effects of Derivative Instruments The following tables provide information on the effects of derivative instruments on the Consolidated Statements of Income and changes in AOCI for Fiscal 2023, Fiscal 2022 and Fiscal 2021: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from 2023 2022 2021 2023 2022 2021 Cash Flow Hedges: Interest rate contracts $ 25 $ 91 $ 4 $ 40 $ (7) $ (25) Interest expense Net Investment Hedges: Foreign currency contracts $ (21) $ 69 $ 4 Gain (Loss) Location of 2023 2022 2021 Derivatives Not Designated as Hedging Instruments: Commodity contracts $ 11 $ (9) $ (17) Revenues Commodity contracts (1,771) 1,181 1,545 Cost of sales Commodity contracts 2 1 5 Other operating income, net Foreign currency contracts (23) 63 9 Other non-operating (expense) income, net Total $ (1,781) $ 1,236 $ 1,542 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)	12 Months Ended
	Sep. 30, 2023
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	Note 19 — Accumulated Other Comprehensive Income (Loss) Other comprehensive income (loss) principally comprises (1) gains and losses on derivative instruments qualifying as cash flow hedges, net of reclassifications to net income; (2) actuarial gains and losses on postretirement benefit plans, net of associated amortization; and (3) foreign currency translation and long-term intra-company transaction adjustments. The tables below present changes in AOCI, net of tax, during Fiscal 2023, Fiscal 2022 and Fiscal 2021: Postretirement Derivative Foreign Total AOCI - September 30, 2020 $ (26) $ (54) $ (67) $ (147) Other comprehensive income (loss) before reclassification adjustments 7 3 (23) (13) Amounts reclassified from AOCI 2 18 — 20 Other comprehensive income (loss) attributable to UGI 9 21 (23) 7 AOCI - September 30, 2021 $ (17) $ (33) $ (90) $ (140) Other comprehensive income (loss) before reclassification adjustments 28 64 (341) (249) Amounts reclassified from AOCI 3 6 — 9 Other comprehensive income (loss) attributable to UGI 31 70 (341) (240) AOCI - September 30, 2022 $ 14 $ 37 $ (431) $ (380) Other comprehensive income (loss) before reclassification adjustments 5 16 132 153 Amounts reclassified from AOCI (2) (27) — (29) Other comprehensive income (loss) attributable to UGI 3 (11) 132 124 AOCI - September 30, 2023 $ 17 $ 26 $ (299) $ (256)

Other Operating Income, Net and

Other Operating Income, Net and Other Non-Operating Income (Expense), Net	12 Months Ended
	Sep. 30, 2023
Component of Operating Income [Abstract]
Other Operating Income, Net and Other Non-Operating (Expense) Income, Net	Note 20 — Other Operating Income, Net and Other Non-Operating Income (Expense), Net Other Operating Income, Net Other operating income, net, comprises the following: 2023 2022 2021 Finance charges $ 17 $ 18 $ 17 Gains on sales of fixed assets, net (a) 61 33 11 Gain on early derivative termination — — 5 Foreign currency transaction gains (losses) 7 (5) — Cylinder deposit income 23 18 9 Interest and interest-related income 6 1 — Other, net 18 14 (9) Total other operating income, net $ 132 $ 79 $ 33 (a) Fiscal 2023 includes a $15 gain on the sale of UGI Corporation’s headquarters building in August 2023. Other Non-Operating (Expense) Income, Net Other non-operating (expense) income, net comprises the following: 2023 2022 2021 (Losses) gains on foreign currency contracts, net $ (23) $ 63 $ 9 Amortization of excluded components of certain net investment hedges 7 7 2 Pension and other postretirement plans non-service income, net 9 5 1 Total other non-operating (expense) income, net $ (7) $ 75 $ 12

Equity Method Investments

Equity Method Investments	12 Months Ended
	Sep. 30, 2023
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Note 21 — Equity Method Investments Equity method investments which are included within “Other assets” on the Consolidated Balance Sheets, comprises the following as of September 30: Carrying Value Ownership Interest Investees 2023 2022 2023 2022 Midstream & Marketing Aurum Renewables $ 45 $ — 40% N/A Pine Run 77 68 49% 49% MBL Bioenergy 122 23 99.99% 99.99% Other 20 18 various various Total Midstream & Marketing 264 109 UGI International 35 21 various various Total investments in equity method investees $ 299 $ 130 Aurum Renewables . In January 2023, the Company, through its wholly owned indirect subsidiary, entered into a joint venture agreement with a third party Archaea Holdings, LLC (“Archaea”). The primary purpose of the joint venture, Aurum Renewables LLC, is to upgrade landfill gas from the Commonwealth Environmental Systems landfill located in Hegins, Pennsylvania to pipeline-quality RNG. Pursuant to this agreement, the Company contributed its existing 11 megawatt landfill gas-to-electricity facility, as non-cash consideration, in return for a 40% equity interest in the joint venture. Once complete, the project is expected to have the capacity to produce approximately 5,000 MMBtu per day of pipeline-quality RNG. Archaea will lead the development, engineering, construction, and operation of the new RNG facility, and Energy Services will take a lead role in marketing the RNG produced by the facility. Pine Run. Pine Run is a company jointly owned by UGI Pine Run, LLC (a wholly-owned subsidiary of Energy Services) and Stonehenge Energy Resources . In February 2021, Pine Run completed the acquisition of Pine Run Midstream, an affiliate of PennEnergy, and minority partners for approximately $205. The acquisition was funded by cash contributions by UGI Pine Run, LLC and Stonehenge Energy Resources totaling approximately $115, and the issuance by Pine Run of $90 of long-term debt. Pine Run Midstream operates dry gas gathering pipelines and compression assets in western Pennsylvania. Pine Run is accounted for as an equity method investment as we have the ability to exercise significant influence, but not control, over the entity. MBL Bioenergy . MBL Bioenergy is a company jointly owned by UGI Dakota, LLC (a wholly-owned subsidiary of Energy Services), Sevana Bioenergy and a subsidiary of California Bioenergy. The sole purpose of MBL Bioenergy is the development of RNG projects in South Dakota comprising three dairy waste anaerobic digester systems. MBL Bioenergy is a variable interest entity whereby the Company has determined that it is not the primary beneficiary since it does not direct the activities that most significantly impact the entity’s economic performance. In addition to consent being required for all equity holders for significant activities, such as major procurement, construction contracting and offtake, our partners manage the day-to-day project management and operations for MBL Bioenergy and its subsidiaries. Pennant. During the fourth quarter of Fiscal 2022, Energy Services completed the Pennant Acquisition and acquired the remaining 53% of the equity interests in Pennant. Prior to the Pennant Acquisition, the Company’s investment in Pennant was accounted for as an equity method investment as we had the ability to exercise significant influence, but not control, over the entity. The acquisition of the remaining interests was accounted for as an acquisition of assets, and the purchase price of approximately $61 was primarily allocated to property, plant and equipment. In connection with the acquisition of the controlling financial interest in Pennant, the Company recognized an other-than-temporary pre-tax impairment charge of $44 related to its then existing 47% membership interest, which amount is reflected in “Income (loss) from equity investees” in the Consolidated Statements of Income. PennEast . UGI PennEast, LLC and four other members each hold a 20% membership interest in PennEast. PennEast was formed to construct an approximate 120-mile natural gas pipeline from Luzerne County, Pennsylvania to the Trenton- Woodbury interconnection in New Jersey. PennEast is accounted for as an equity method investment as we have the ability to exercise significant influence, but not control, over PennEast. During the third-quarter of Fiscal 2021, the partners of the PennEast project re-assessed the remaining legal and regulatory contingencies which needed to be resolved before construction could commence. Based on the significant remaining legal challenges and the expected further delays in obtaining necessary regulatory approvals, which were preventing the commencement of construction and commercial operation of the project, the Company concluded that its investment in PennEast was impaired at June 30, 2021, and that such impairment was other-than-temporary. The estimated fair value of the Company’s investment in PennEast was measured using probability-weighted cash flows under an expected present value technique based on management's estimates and assumptions regarding the likelihood of certain outcomes (and the related timing) that would be used by market participants at the time. Based upon this analysis, the Company recognized an other-than-temporary pre-tax impairment charge of $93 in June 2021, which is reflected in “Income (loss) from equity investees” in the Consolidated Statements of Income. In September 2021, the PennEast partners announced that further development of the project is no longer supported and all further development has ceased. Following this announcement, the estimated fair value of the remaining assets of the project was assessed using the liquidation value of equipment held by PennEast. Such assessment did not result in a material change in the carrying value and no further impairment loss was recognized. The estimated fair value of the Company’s investment in PennEast was determined to be a Level 2 measurement within the fair value hierarchy. During the fourth quarter of Fiscal 2022, the Company recognized $9 of equity earnings related to the ongoing liquidation of PennEast assets. The carrying value of our investment in PennEast at September 30, 2023 and 2022 was not material. Other Equity Method Investment s.

Segment Information

Segment Information	12 Months Ended
	Sep. 30, 2023
Segment Reporting [Abstract]
Segment Information	Note 22 — Segment Information Our operations comprise four reportable segments generally based upon products or services sold, geographic location and regulatory environment: (1) AmeriGas Propane; (2) UGI International; (3) Midstream & Marketing; and (4) Utilities. AmeriGas Propane derives its revenues principally from the sale of propane and related equipment and supplies to retail customers in all 50 states. UGI International derives its revenues principally from the distribution of LPG to retail customers throughout much of Europe. In addition, UGI International derives revenue from energy marketing business that primarily markets natural gas and electricity to customers in France, the Netherlands and, prior to its sales, in Belgium and the United Kingdom (see Note 5 regarding the sale and wind-down of the UGI International energy marketing business). Midstream & Marketing derives its revenues principally from the sale of natural gas, liquid fuels and electricity as well as revenues and fees from storage, pipeline transportation, natural gas gathering, and natural gas and RNG production activities primarily in the Mid-Atlantic region of the U.S. eastern Ohio, the panhandle of West Virginia and California. Midstream & Marketing also derives revenues from the sale of electricity through PJM, a regional electricity transmission organization in the eastern U.S. Our Utilities segment primarily derives its revenues from the sale and distribution of natural gas to customers in eastern and central Pennsylvania and subsequent to the Mountaineer Acquisition in September 2021, in West Virginia (see Note 5). To a much lesser extent, Utilities also derives revenues from the sale and distribution of electricity in two northeastern Pennsylvania counties. 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. Our CODM evaluates the performance of all of our reportable segments based upon earnings before interest expense and income taxes, excluding the items noted below. No single customer represents more than ten percent of our consolidated revenues. In addition, all of our reportable segments’ revenues, other than those of UGI International, are derived from sources within the United States, and all of our reportable segments’ long-lived assets, other than those of UGI International, are located in the United States. The amounts of revenues and long-lived assets associated with our operations in France represent approximately 20% and 10% of the respective consolidated amounts. Total Elim- AmeriGas UGI International Midstream Utilities Corporate & 2023 Revenues from external customers $ 8,928 $ — $ 2,581 $ 2,965 $ 1,596 $ 1,780 $ 6 Intersegment revenues $ — $ (326) (b) $ — $ — $ 251 $ 74 $ 1 Cost of sales $ 6,937 $ (325) (b) $ 1,250 $ 2,045 $ 1,360 $ 953 $ 1,654 Operating (loss) income $ (1,444) $ — $ 268 $ 215 $ 285 $ 357 $ (2,569) Income (loss) from equity investees 2 — — (4) 6 — — Loss on extinguishments of debt (9) — — — — — (9) Other non-operating (loss) income, net (7) — — 23 — 8 (38) (Loss) earnings before interest expense and income taxes (1,458) — 268 234 291 365 (2,616) Interest expense (379) — (163) (37) (45) (82) (52) Income tax benefit (expense) 335 — (34) (25) (53) (64) 511 Net (loss) income attributable to UGI $ (1,502) $ — $ 71 $ 172 $ 193 $ 219 $ (2,157) Depreciation and amortization $ 532 $ — $ 177 $ 116 $ 86 $ 152 $ 1 Total assets $ 15,401 $ (173) $ 3,415 $ 3,105 $ 3,160 $ 5,691 $ 203 Short-term borrowings $ 649 $ — $ — $ 214 $ 103 $ 332 $ — Capital expenditures (including the effects of accruals) $ 956 $ 134 $ 129 $ 130 $ 563 $ — Investments in equity investees $ 299 $ — $ — $ 35 $ 264 $ — $ — Total Elim- AmeriGas UGI International Midstream Utilities Corporate & 2022 Revenues from external customers $ 10,106 $ — $ 2,943 $ 3,686 $ 1,957 $ 1,515 $ 5 Intersegment revenues $ — $ (477) (b) $ — $ — $ 369 $ 105 $ 3 Cost of sales $ 5,973 $ (474) (b) $ 1,613 $ 2,751 $ 1,876 $ 798 $ (591) Operating income $ 1,666 $ — $ 307 $ 237 $ 246 $ 327 $ 549 (Loss) income from equity investees (14) — — (2) 23 — (35) Loss on extinguishments of debt (11) — — — — — (11) Other non-operating income, net 75 — — 19 — 9 47 Earnings before interest expense and income taxes 1,716 — 307 254 269 336 550 Interest expense (329) — (160) (28) (41) (65) (35) Income tax expense (313) — (35) (50) (65) (65) (98) Noncontrolling interests’ net (income) loss (1) — — (1) — — — Net income attributable to UGI $ 1,073 $ — $ 112 $ 175 $ 163 $ 206 $ 417 Depreciation and amortization $ 518 $ — $ 177 $ 116 $ 79 $ 144 $ 2 Total assets $ 17,575 $ (203) $ 4,332 $ 4,610 $ 3,286 $ 5,354 $ 196 Short-term borrowings $ 368 $ — $ 131 $ 1 $ — $ 236 $ — Capital expenditures (including the effects of accruals) $ 835 $ — $ 128 $ 107 $ 38 $ 562 $ — Investments in equity investees $ 130 $ — $ — $ 20 $ 109 $ — $ 1 2021 Revenues from external customers $ 7,447 $ — $ 2,614 $ 2,651 $ 1,182 $ 1,015 $ (15) Intersegment revenues $ — $ (291) (b) $ — $ — $ 224 $ 64 $ 3 Cost of sales $ 2,614 $ (288) (b) $ 1,217 $ 1,598 $ 1,033 $ 458 $ (1,404) Operating income $ 2,350 $ — $ 385 $ 314 $ 160 $ 241 $ 1,250 (Loss) income from equity investees (63) — — — 30 — (93) Other non-operating income, net 12 — — 3 — 1 8 Earnings before interest expense and income taxes 2,299 — 385 317 190 242 1,165 Interest expense (310) — (159) (27) (42) (56) (26) Income tax expense (522) — (58) (69) (41) (42) (312) Net income attributable to UGI $ 1,467 $ — $ 168 $ 221 $ 107 $ 144 $ 827 Depreciation and amortization $ 502 $ — $ 173 $ 134 $ 76 $ 119 $ — Total assets $ 16,723 $ (241) $ 4,485 $ 4,421 $ 3,010 $ 4,859 $ 189 Short-term borrowings $ 367 $ — $ 170 $ — $ — $ 197 $ — Capital expenditures (including the effects of accruals) $ 674 $ — $ 130 $ 107 $ 43 $ 394 $ — Investments in equity investees $ 174 $ — $ — $ 11 $ 163 $ — $ — (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, for Fiscal 2023, Fiscal 2022 and Fiscal 2021: Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing 2023 Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 4 $ 6 Net losses on commodity derivative instruments not associated with current-period transactions Cost of Sales $ (16) $ (1,402) $ (236) AmeriGas performance enhancement Operating and administrative expenses $ (24) $ — $ — Loss on extinguishment of debt Loss on extinguishments of debt $ (9) $ — $ — Unrealized losses on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ (38) $ — Loss associated with impairment of AmeriGas Propane goodwill Impairment of goodwill $ (656) $ — $ — Costs associated with exit of the UGI International energy marketing business Revenues/Operating and administrative expenses $ — $ (27) $ — Costs associated with exit of the UGI International energy marketing business Loss on disposal of UGI International energy marketing business $ — $ (221) $ — 2022 Net gains (losses) on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 9 $ (4) Net (losses) gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ (185) $ 797 $ (21) Net gains on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ 2 $ — Restructuring costs Operating and administrative expenses $ (16) $ (9) $ (1) Loss on extinguishment of debt Loss on extinguishments of debt $ — $ (11) $ — Unrealized gains on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 50 $ — AmeriGas performance enhancement Operating and administrative expenses $ (5) $ — $ — Costs associated with exit of the UGI International energy marketing business Operating and administrative expenses $ — $ (5) $ — Impairments associated with certain equity method investments Income (loss) from equity investees $ — $ — $ (35) 2021 Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (15) Net gains on commodity derivative instruments not associated with current-period transactions Cost of Sales $ 167 $ 1,065 $ 173 Unrealized gains on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 8 $ — Business transformation expenses Operating and administrative expenses $ (54) $ (33) $ — Impairment of customer relationship intangible Operating and administrative expenses $ — $ (20) $ — Impairments associated with certain equity method investments Income (loss) from equity investees $ — $ — $ (93) (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, Utilities and AmeriGas Propane.

Global LPG Business Transformat

Global LPG Business Transformation Initiatives	12 Months Ended
	Sep. 30, 2023
Restructuring and Related Activities [Abstract]
Global LPG Business Transformation Initiatives	Note 23 — Global LPG Business Transformation Initiatives AmeriGas Propane and UGI International. Beginning in Fiscal 2019, we began executing on multi-year business transformation initiatives at our AmeriGas Propane and UGI International business segments. These initiatives are designed to improve long-term operational performance by, among other things, reducing costs and improving efficiency in the areas of sales and marketing, supply and logistics, operations, purchasing, and administration. In addition, these business transformation initiatives focus on enhancing the customer experience through, among other things, enhanced customer relationship management and an improved digital customer experience. During Fiscal 2021 we incurred $87 of costs principally comprising consulting, advisory, marketing and employee-related costs. These costs are primarily reflected in “Operating and administrative expenses” on the Consolidated Statements of Income. These previously announced business transformation initiatives were substantially complete by the end of Fiscal 2021.

SCHEDULE I _ CONDENSED FINANCIA

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)	12 Months Ended
	Sep. 30, 2023
Condensed Financial Information Disclosure [Abstract]
SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)	BALANCE SHEETS (Millions of dollars) September 30, 2023 2022 ASSETS Current assets: Cash and cash equivalents $ 7 $ 20 Accounts receivable – related parties 11 24 Prepaid expenses and other current assets 23 20 Total current assets 41 64 Property, plant and equipment, net — 1 Investments in subsidiaries 5,343 7,035 Other assets 143 97 Total assets $ 5,527 $ 7,197 LIABILITIES AND COMMON STOCKHOLDERS’ EQUITY Current liabilities: Current maturities of long-term debt $ 38 $ 125 Accounts and notes payable 28 20 Accrued liabilities 39 51 Total current liabilities 105 196 Long-term debt 969 889 Other noncurrent liabilities 67 46 Total liabilities 1,141 1,131 Commitments and contingencies (Note 1) Equity: Preferred Stock, without par value (authorized - 5,000,000; issued - 220,000 and 220,000, respectively) 167 162 Common Stock, without par value (authorized – 450,000,000 shares; issued – 210,906,052 and 210,560,494 shares, respectively) 1,503 1,483 Retained earnings 3,027 4,841 Accumulated other comprehensive loss (256) (380) Treasury stock, at cost (55) (40) Total common stockholders’ equity 4,386 6,066 Total liabilities and common stockholders’ equity $ 5,527 $ 7,197 Note 1 — Commitments and Contingencies: At September 30, 2023, UGI Corporation had agreed to indemnify the issuers of $105 of surety bonds issued on behalf of certain UGI subsidiaries. UGI Corporation is authorized to guarantee up to $475 of obligations to suppliers and customers of Energy Services and subsidiaries of which $358 of such obligations were outstanding as of September 30, 2023. Scheduled principal repayments of long-term debt include $38 in Fiscal 2024 and $973 in Fiscal 2025. STATEMENTS OF INCOME (Millions of dollars, except per share amounts) Year Ended September 30, 2023 2022 2021 Revenues $ — $ — $ — Costs and expenses: Operating and administrative expenses 95 74 94 Other operating income, net (a) (83) (63) (65) 12 11 29 Operating loss (12) (11) (29) Pension and other postretirement plans non-service expense — (3) — Interest expense (52) (35) (27) Loss before income taxes (64) (49) (56) Income tax (benefit) expense (13) — 9 Loss before equity in income of unconsolidated subsidiaries (51) (49) (65) Equity in (loss) income of unconsolidated subsidiaries (1,451) 1,122 1,532 Net (loss) income attributable to UGI Corporation $ (1,502) $ 1,073 $ 1,467 Other comprehensive (loss) income (8) 34 7 Equity in other comprehensive income (loss) of unconsolidated subsidiaries 132 (274) — Comprehensive (loss) income attributable to UGI Corporation $ (1,378) $ 833 $ 1,474 (Loss) earnings per common share attributable to UGI Corporation stockholders: Basic $ (7.16) $ 5.11 $ 7.02 Diluted $ (7.16) $ 4.97 $ 6.92 Weighted - average common shares outstanding (thousands): Basic 209,806 209,940 209,063 Diluted 209,806 215,821 212,126 (a) UGI provides certain financial and administrative services to certain of its subsidiaries. UGI bills these subsidiaries monthly for all direct expenses incurred by UGI on behalf of its subsidiaries as well as allocated shares of indirect corporate expense incurred or paid with respect to services provided by UGI. The allocation of indirect UGI corporate expenses to certain of its subsidiaries utilizes a weighted, three-component formula comprising revenues, operating expenses, and net assets employed and considers the relative percentage of such items for each subsidiary to the total of such items for all UGI operating subsidiaries for which general and administrative services are provided. Management believes that this allocation method is reasonable and equitable to its subsidiaries. These billed expenses are classified as “Other operating income, net” in the Statements of Income above. STATEMENTS OF CASH FLOWS (Millions of dollars) Year Ended September 30, 2023 2022 2021 NET CASH PROVIDED BY OPERATING ACTIVITIES (a) $ 636 $ 485 $ 300 CASH FLOWS FROM INVESTING ACTIVITIES: Return of capital distributions — 175 — Net investments in unconsolidated subsidiaries (309) (390) (401) Net cash used by investing activities (309) (215) (401) CASH FLOWS FROM FINANCING ACTIVITIES: Dividends on UGI Common Stock (308) (296) (282) Issuances of debt, net of issuance costs 327 597 483 Repayments of long-term debt (333) (530) (385) Issuance of Preferred Stock, net of issuance costs — — 213 Issuances of UGI Common Stock 12 19 19 Repurchases of UGI Common Stock (22) (38) — Payments on Purchase Contracts (16) (16) — Net cash (used) provided by financing activities (340) (264) 48 Cash and cash equivalents (decrease) increase $ (13) $ 6 $ (53) Cash and cash equivalents: End of year $ 7 $ 20 $ 14 Beginning of year 20 14 67 Cash and cash equivalents (decrease) increase $ (13) $ 6 $ (53) (a) Includes dividends received from unconsolidated subsidiaries of $680, $506 and $354 for the years ended September 30, 2023, 2022 and 2021, respectively.

SCHEDULE II _ VALUATION AND QUA

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS	12 Months Ended
	Sep. 30, 2023
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS	UGI CORPORATION AND SUBSIDIARIES SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS (Millions of dollars) Balance at Charged Other Balance at Year Ended September 30, 2023 Reserves deducted from assets in the consolidated balance sheet: Allowance for doubtful accounts $ 64 $ 69 $ (62) (1) $ 71 Other reserves: Deferred tax assets valuation allowance $ 141 $ (38) $ 38 (2) $ 141 Year Ended September 30, 2022 Reserves deducted from assets in the consolidated balance sheet: Allowance for doubtful accounts $ 53 $ 61 $ (50) (1) $ 64 Other reserves: Deferred tax assets valuation allowance $ 138 $ (14) $ 17 (2) $ 141 Year Ended September 30, 2021 Reserves deducted from assets in the consolidated balance sheet: Allowance for doubtful accounts $ 42 $ 36 $ (25) (1) $ 53 Other reserves: Deferred tax assets valuation allowance $ 105 $ 23 $ 10 (2) $ 138 (1) Uncollectible accounts written off, net of recoveries. (2) Primarily a notional interest deduction valuation allowance adjustment.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Pay vs Performance Disclosure
Net (loss) income attributable to UGI Corporation	$ (1,502)	$ 1,073	$ 1,467

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Sep. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Sep. 30, 2023
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation Our consolidated financial statements are prepared in accordance with GAAP. 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.
Principles of Consolidation	Principles of Consolidation The consolidated financial statements include the accounts of UGI and its controlled subsidiary companies which are majority owned. We report outside ownership interests in other consolidated but less than 100%-owned subsidiaries, as noncontrolling interests. We eliminate intercompany accounts and transactions when we consolidate.
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. See Note 21 for additional information on our equity method investments. Investments in equity securities related to entities in which we do not have significant influence over operating and financial policies are generally initially valued at their cost less impairment (if any) and subsequently remeasured at fair value, as applicable, in accordance with the relevant provisions under GAAP.
Effects of Regulation	Effects of RegulationCertain of our subsidiaries account for the financial effects of regulation in accordance with ASC 980. In accordance with this guidance, incurred costs that would otherwise be charged to expense are capitalized and recorded as regulatory assets when it is probable that the incurred costs will be recovered through rates in the future. Similarly, we recognize regulatory liabilities when it is probable that regulators will require customer refunds through future rates or when revenue is collected from customers for expenditures that have not yet been incurred. Regulatory assets and liabilities are classified as current if, upon initial recognition, the entire amount related to that item will be recovered or refunded within a year of the balance sheet date. Generally, regulatory assets and regulatory liabilities are amortized into expense and income over the periods authorized by the respective regulatory body.
Fair Value Measurements	Fair Value Measurements The Company applies fair value measurements on a recurring and, as otherwise required under ASC 820, on a nonrecurring basis. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Fair value measurements performed on a recurring basis principally relate to derivative instruments and investments held in supplemental executive retirement plan grantor trusts. ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels. The hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). A level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels: • Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date. • Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. • Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. Fair value is based upon assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. We evaluate the need for credit adjustments to our derivative instrument fair values. These credit adjustments were not material to the fair values of our derivative instruments.
Derivative Instruments	Derivative Instruments Derivative instruments are reported on the Consolidated Balance Sheets at their fair values, unless the NPNS exception is elected. The accounting for changes in fair value depends upon the purpose of the derivative instrument, whether it is subject to regulatory ratemaking mechanisms or if it qualifies and is designated as a hedge for accounting purposes. Certain of our derivative instruments qualify and are designated as cash flow hedges. For cash flow hedges, changes in the fair values of the derivative instruments are recorded in AOCI, to the extent effective at offsetting changes in the hedged item, until earnings are affected by the hedged item. We discontinue cash flow hedge accounting if occurrence of the forecasted transaction is determined to be no longer probable. Hedge accounting is also discontinued for derivatives that cease to be highly effective. We do not designate our commodity and certain foreign currency derivative instruments as hedges under GAAP. Changes in the fair values of these derivative instruments are reflected in net income. Gains and losses on substantially all of the commodity derivative instruments used by Utilities are included in regulatory assets or liabilities because it is probable such gains or losses will be recoverable from, or refundable to, customers. From time to time, we also enter into net investment hedges. Gains and losses on net investment hedges that relate to our foreign operations are included in the cumulative translation adjustment component in AOCI until such foreign net investment is substantially sold or liquidated. Cash flows from derivative instruments, other than certain net investment hedges, are included in cash flows from operating activities on the Consolidated Statements of Cash Flows. Cash flows from net investment hedges are included in cash flows from investing activities on the Consolidated Statements of Cash Flows.
Business Combination Purchase Price Allocations	Business Combination Purchase Price Allocations From time to time, the Company enters into material business combinations. The purchase price is allocated to the various assets acquired and liabilities assumed at their estimated fair value as of the acquisition date with the residual of the purchase price allocated to goodwill. Fair values of assets acquired and liabilities assumed are based upon available information. Estimating fair values is generally subject to significant judgment, estimates and assumptions especially with respect to intangible assets. The allocation of the purchase price may be modified up to one year after the acquisition date, under certain circumstances, as more information is obtained about the fair value of assets acquired and liabilities assumed.
Foreign Currency Translation	Foreign Currency Translation Balance sheets of international subsidiaries are translated into USD using the exchange rate at the balance sheet date. Income statements and equity investee results are translated into USD using an average exchange rate for each reporting period. Where the local currency is the functional currency, translation adjustments are recorded in other comprehensive income. Transactions denominated in currencies other than the functional currency are recorded based on exchange rates at the time such transactions arise with the impact of subsequent changes in such rates reflected in the income statement. The functional currency of a significant portion of our international operations is the euro.
Revenue Recognition	Revenue Recognition In accordance with ASC 606, 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.
Accounts Receivable	Accounts Receivable Accounts receivable are reported on the Consolidated Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. Provisions for uncollectible accounts are established based upon our collection experience, the assessment of the collectability of specific amounts and the Company’s best estimate of current expected credit losses. Accounts receivable are written off in the period in which the receivable is deemed uncollectible.
LPG Delivery Expenses	LPG Delivery Expenses Expenses associated with the delivery of LPG to customers of the Partnership and our UGI International operations (including vehicle expenses, expenses of delivery personnel, vehicle repair and maintenance and general liability expenses) are classified as “Operating and administrative expenses” on the Consolidated Statements of Income. Depreciation expense associated with the Partnership and UGI International delivery vehicles is classified in “Depreciation and amortization” on the Consolidated Statements of Income.
Income Taxes	Income Taxes AmeriGas Partners and AmeriGas OLP are not directly subject to federal income taxes. Instead, their taxable income or loss is allocated to the individual partners. We record income taxes on (1) our share of the Partnership’s current taxable income or loss and (2) the differences between the book and tax basis of our investment in the Partnership. AmeriGas OLP has subsidiaries which operate in corporate form and are directly subject to federal and state income taxes. Legislation in certain states allows for taxation of partnership income and the accompanying financial statements reflect state income taxes resulting from such legislation. Utilities records deferred income taxes in the Consolidated Statements of Income resulting from the use of accelerated tax depreciation methods based upon amounts recognized for ratemaking purposes. Utilities also records a deferred income tax liability for tax benefits, principally the result of accelerated tax depreciation for state income tax purposes, that are flowed through to ratepayers when temporary differences originate and records a regulatory income tax asset for the probable increase in future revenues that will result when the temporary differences reverse. We are amortizing deferred investment tax credits related to UGI Utilities’ plant additions over the service lives of the related property. UGI Utilities reduces its deferred income tax liability for the future tax benefits that will occur when investment tax credits, which are not taxable, are amortized. We also reduce the regulatory income tax asset for the probable reduction in future revenues that will result when such deferred investment tax credits amortize. Investment tax credits associated with Midstream & Marketing’s qualifying renewable natural gas property under the Inflation Reduction Act of 2022 are reflected in income taxes.
Earnings Per Common Share	Earnings Per Common ShareBasic earnings per share attributable to UGI Corporation stockholders reflect the weighted-average number of common shares outstanding. Diluted earnings per share attributable to UGI Corporation include the effects of dilutive stock options, common stock awards and Equity Units.
Cash, Cash Equivalents and Restricted Cash	Cash, Cash Equivalents and Restricted CashCash and cash equivalents include cash on hand, cash in banks and highly liquid investments with maturities of three months or less when purchased. Restricted cash principally represents those cash balances in our commodity futures brokerage accounts that are restricted from withdrawal.
Inventories	Inventories Our inventories are stated at the lower of cost or net realizable value. We determine cost using an average cost method for non-utility LPG and natural gas and utility inventories; specific identification for appliances; and the FIFO method for all other inventories. The Company accounts for renewable energy certificates as inventory, which generally represents costs incurred to generate a certificate for sale. The Company recognizes revenue from the sale of renewable energy certificates when control of the certificate is transferred to the buyer, and the cost of the certificate, if any, is then recorded within “Cost of sales” on the Consolidated Statements of Income.
Property, Plant and Equipment and Related Depreciation	Property, Plant and Equipment and Related Depreciation We record property, plant and equipment at the lower of original cost or fair value, if impaired. Capitalized costs include labor, materials and other direct and indirect costs, and for certain operations subject to cost-of-service rate regulation, AFUDC. We also include in property, plant and equipment costs associated with computer software we develop or obtain for use in our businesses. The amounts assigned to property, plant and equipment of acquired businesses are based upon estimated fair value at date of acquisition. When we retire or otherwise dispose of non-utility plant and equipment, we eliminate the associated cost and accumulated depreciation and recognize any resulting gain or loss in "Other operating income, net" on the Consolidated Statements of Income. For property subject to cost of service rate regulation, upon retirement we charge the original cost to accumulated depreciation for financial accounting purposes. Costs incurred to retire UGI Utilities plant and equipment, net of salvage, are recorded in regulatory assets and amortized over five years, consistent with prior ratemaking treatment.
Intangible Assets	Intangible Assets. We amortize intangible assets over their estimated useful lives unless we determine their lives to be indefinite. Estimated useful lives of definite-lived intangible assets, primarily consisting of customer relationships. We test definite-lived intangible assets for impairment whenever events or changes in circumstances indicate that the associated carrying amounts may be impaired. Determining whether an impairment loss occurred requires comparing the carrying amount to the estimated fair value of the asset in accordance with ASC 820. Intangible assets with indefinite lives are not amortized but are tested for impairment annually (and more frequently if events or changes in circumstances between annual tests indicate that it is more likely than not that they are impaired) and written down to fair value, if impaired. See Note 12 for additional information related to intangible asset impairments recognized in Fiscal 2023 and Fiscal 2021.
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. For certain of our reporting units with goodwill, we assess qualitative factors to determine whether it is more likely than not that the fair value of such reporting unit is less than its carrying amount. For our other reporting units with goodwill, we bypass the qualitative assessment and perform the quantitative assessment by comparing the fair values of the reporting units with their carrying amounts, including goodwill. If the carrying amount of a reporting unit exceeds its fair value, an impairment loss is recognized in an amount equal to such excess but not to exceed the total amount of the goodwill of the reporting unit. During the third quarter of Fiscal 2023, the Company identified interim impairment indicators at its AmeriGas Propane reporting unit and, as such, performed an interim impairment test of its goodwill as of May 31, 2023. Based on such impairment test, the Company recognized a non-cash pre-tax goodwill impairment charge of $656. See Note 12 for additional information. With respect to UGI International's Fiscal 2023 goodwill impairment test, the Company bypassed the qualitative assessment and performed a quantitative assessment. Such assessment used a weighting of income and market approaches to determine fair value. With respect to the income approach, management used a discounted cash flow (“DCF”) method, using unobservable inputs. The significant assumptions in our DCF model include projected EBITDA, and a discount rate (and estimates in the discount rate inputs). With respect to the market approach, management used recent transaction market multiples for similar companies. Based on our evaluation, 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 is approximately $911 of goodwill in this reporting unit as of September 30, 2023. The Company will continue to monitor its reporting units and related goodwill for any possible future non-cash impairment charges.
Impairment of Long-Lived Assets	Impairment of Long-Lived Assets Impairment testing for long-lived assets (or an asset group) is required when circumstances indicate that such assets may be impaired. If it is determined that a triggering event has occurred, we perform a recoverability test based upon estimated undiscounted cash flow projections expected to be realized over the remaining useful life of the long-lived asset. If the undiscounted cash flows used in the recoverability test are less than the long-lived asset's carrying amount, we determine its fair value. If the fair value is determined to be less than its carrying amount, the long-lived asset is reduced to its estimated fair
Refundable Tank and Cylinder Deposits	Refundable Tank and Cylinder DepositsIncluded in “Other noncurrent liabilities” on our Consolidated Balance Sheets are customer paid deposits on tanks and cylinders primarily owned by subsidiaries of UGI FranceDeposits are refundable to customers when the tanks or cylinders are returned in accordance with contract terms.
Environmental Matters	Environmental Matters We are subject to environmental laws and regulations intended to mitigate or remove the effects of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current or former operating sites.
Loss Contingencies Subject to Insurance	Loss Contingencies Subject to Insurance We are subject to risk of loss for general, automobile and product liability, and workers’ compensation claims for which we obtain insurance coverage under insurance policies that are subject to self-insured retentions or deductibles. In accordance with GAAP, we record accruals when it is probable that a liability exists and the amount or range of amounts can be reasonably estimated. When no amount within a range of possible loss is a better estimate than any other amount within the range, liabilities recorded are based upon the low end of the range. For litigation and pending claims including those covered by insurance policies, the analysis of probable loss is performed on a case by case basis and includes an evaluation of the nature of the claim, the procedural status of the matter, the probability or likelihood of success in prosecuting or defending the claim, the information available with respect to the claim, the opinions and views of outside counsel and other advisors, and past experience in similar matters. With respect to unasserted claims arising from unreported incidents, we may use the work of specialists to estimate the ultimate losses to be incurred using actuarially determined loss development factors applied to actual claims data. Our estimated reserves for loss contingencies may differ materially from the ultimate liability and such reserves may change materially as more information becomes available and estimated reserves are adjusted. We maintain insurance coverage such that our net exposure for claims covered by insurance would be limited to the self-insured retentions or
Employee Retirement Plans	Employee Retirement Plans We use a market-related value of plan assets and an expected long-term rate of return to determine the expected return on assets of our U.S. pension and other postretirement plans. The market-related value of plan assets, other than equity investments, is based upon fair values. The market-related value of equity investments is calculated by rolling forward the prior-year’s market-related value with contributions, disbursements and the expected return on plan assets. One third of the difference between the expected and the actual value is then added to or subtracted from the expected value to determine the new market-related value (see Note 8).
New Accounting Standard Adopted in Fiscal 2023	New Accounting Standard Adopted in Fiscal 2023 Debt and Derivatives and Hedging . Effective October 1, 2022, the Company adopted ASU 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40),” using the modified retrospective approach. The amendments in this ASU affect entities that issue convertible instruments and/or contracts indexed to and potentially settled in an entity’s own equity. This ASU reduces the number of accounting models for convertible debt instruments and convertible preferred stock, expands disclosure requirements for convertible instruments, and simplifies the related earnings per share guidance. The adoption of the new guidance did not have a material impact on our consolidated financial statements.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Sep. 30, 2023
Accounting Policies [Abstract]
Shares Used in Computing Basic and Diluted Earnings Per Share	Shares used in computing basic and diluted earnings per share are as follows: (Thousands of shares) 2023 2022 2021 Weighted-average common shares outstanding for basic computation 209,806 209,940 209,063 Incremental shares issuable for stock options, common stock awards and Equity Units (a) (b) — 5,881 3,063 Weighted-average common shares outstanding for diluted computation 209,806 215,821 212,126 (a) Includes the impact of common shares assumed to be outstanding under the if-converted method in connection with the May 2021 issuance of Equity Units (see Note 13).
Schedule of Cash and Cash Equivalents	The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Consolidated Balance Sheets to the corresponding amounts reported on the Consolidated Statements of Cash Flows. 2023 2022 2021 Cash and cash equivalents $ 241 $ 405 $ 855 Restricted cash 99 64 22 Cash, cash equivalents and restricted cash $ 340 $ 469 $ 877
Restrictions on Cash and Cash Equivalents	The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Consolidated Balance Sheets to the corresponding amounts reported on the Consolidated Statements of Cash Flows. 2023 2022 2021 Cash and cash equivalents $ 241 $ 405 $ 855 Restricted cash 99 64 22 Cash, cash equivalents and restricted cash $ 340 $ 469 $ 877

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Sep. 30, 2023
Revenue from Contract with Customer [Abstract]
Schedule of Disaggregated Revenues By Reportable Segment	The following tables present our disaggregated revenues by reportable segment during Fiscal 2023, Fiscal 2022 and Fiscal 2021: 2023 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 1,020 $ — $ — $ — $ — $ 1,020 $ — Commercial & Industrial 413 — — — — 413 — Large delivery service 177 — — — — 177 — Off-system sales and capacity releases 89 (73) — — — 162 — Other 43 (1) — — — 44 — Total Utility 1,742 (74) — — — 1,816 — Non-Utility: LPG: Retail 3,952 — 2,184 1,768 — — — Wholesale 325 — 118 207 — — — Energy Marketing 2,139 (143) — 872 1,410 — — Midstream: Pipeline 251 — — — 251 — — Peaking 31 (106) — — 137 — — Other 14 — — — 14 — — Electricity Generation 33 — — — 33 — — Other 274 — 194 80 — — — Total Non-Utility 7,019 (249) 2,496 2,927 1,845 — — Total revenues from contracts with customers 8,761 (323) 2,496 2,927 1,845 1,816 — Other revenues (b)(c) 167 (3) 85 38 2 38 7 Total revenues $ 8,928 $ (326) $ 2,581 $ 2,965 $ 1,847 $ 1,854 $ 7 2022 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 875 $ — $ — $ — $ — $ 875 $ — Commercial & Industrial 365 — — — — 365 — Large delivery service 171 — — — — 171 — Off-system sales and capacity releases 76 (104) — — — 180 — Other 23 (1) — — — 24 — Total Utility 1,510 (105) — — — 1,615 — Non-Utility: LPG: Retail 4,436 — 2,439 1,997 — — — Wholesale 496 — 218 278 — — — Energy Marketing 2,951 (264) — 1,298 1,917 — — Midstream: Pipeline 211 — — — 211 — — Peaking 48 (105) — — 153 — — Other 9 — — — 9 — — Electricity Generation 34 — — — 34 — — Other 286 — 207 79 — — — Total Non-Utility 8,471 (369) 2,864 3,652 2,324 — — Total revenues from contracts with customers 9,981 (474) 2,864 3,652 2,324 1,615 — Other revenues (b) 125 (3) 79 34 2 5 8 Total revenues $ 10,106 $ (477) $ 2,943 $ 3,686 $ 2,326 $ 1,620 $ 8 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 568 $ — $ — $ — $ — $ 568 $ — Commercial & Industrial 218 — — — — 218 — Large delivery service 148 — — — — 148 — Off-system sales and capacity releases 51 (62) — — — 113 — Other 21 (2) — — — 23 — Total Utility 1,006 (64) — — — 1,070 — Non-Utility: LPG: Retail 3,957 — 2,203 1,754 — — — Wholesale 328 — 139 189 — — — Energy Marketing 1,564 (126) — 605 1,085 — — Midstream: Pipeline 181 — — — 181 — — Peaking 16 (98) — — 114 — — Other 8 — — — 8 — — Electricity Generation 13 — — — 13 — — Other 275 — 206 69 — — — Total Non-Utility 6,342 (224) 2,548 2,617 1,401 — — Total revenues from contracts with customers 7,348 (288) 2,548 2,617 1,401 1,070 — Other revenues (b) 99 (3) 66 34 5 9 (12) Total revenues $ 7,447 $ (291) $ 2,614 $ 2,651 $ 1,406 $ 1,079 $ (12) (a) Includes intersegment revenues principally among Midstream & Marketing, Utilities and AmeriGas Propane. (b) Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, revenues from alternative revenue programs at Utilities and 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. (c) Includes the impact of the weather normalization adjustment rider, a five-year pilot program beginning on November 1, 2022 for PA Gas Utility. See Note 9 for additional information.

Acquisitions and Dispositions (

Acquisitions and Dispositions (Tables)	12 Months Ended
	Sep. 30, 2023
Business Combination and Asset Acquisition [Abstract]
Components of the Purchase Price Allocations	The Company has accounted for the Mountaineer Acquisition using the acquisition method. The components of the Mountaineer purchase accounting are as follows: Assets acquired: Cash and cash equivalents $ 3 Accounts receivable 14 Inventories 41 Other current assets 21 Property, plant and equipment 397 Other noncurrent assets 48 Total assets acquired $ 524 Liabilities assumed: Short-term borrowings $ 55 Accounts payable 20 Other current liabilities 52 Long-term debt 164 Pension and other postretirement benefit obligation 33 Deferred income taxes 21 Other noncurrent liabilities 29 Total liabilities assumed $ 374 Goodwill 250 Net consideration transferred $ 400

Debt (Tables)

Debt (Tables)	12 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
Schedule of Credit Facilities and Short-term Borrowings	Information about the Company’s principal credit agreements (excluding the Energy Services Receivables Facility, which is discussed below) as of September 30, 2023 and 2022, is presented in the following table. Borrowings on these credit agreements bear interest at rates indexed to short-term market rates. Borrowings outstanding under these agreements (other than the 2021 UGI Corporation Senior Credit Facility) are classified as “Short-term borrowings” on the Consolidated Balance Sheets. Expiration Date Total Capacity Borrowings Outstanding Letters of Credit and Guarantees Outstanding Available Borrowing Capacity Weighted Average Interest Rate - End of Year September 30, 2023 AmeriGas OLP (a) September 2026 $ 600 $ — $ 2 $ 598 N.A. UGI International, LLC (b) March 2028 € 500 € 202 € — € 298 5.17 % Energy Services (c) March 2025 $ 260 $ 57 $ — $ 203 7.67 % UGI Utilities (d) June 2024 $ 425 $ 248 $ — $ 177 6.30 % Mountaineer (e) November 2024 $ 150 $ 84 $ — $ 66 6.68 % UGI Corporation (f) May 2025 $ 300 $ 283 $ — $ 17 7.80 % September 30, 2022 AmeriGas OLP (a) September 2026 $ 600 $ 131 $ 2 $ 467 7.27 % UGI International, LLC (b) October 2023 € 300 € — € — € 300 N.A. Energy Services (c) March 2025 $ 260 $ — $ — $ 260 N.A. UGI Utilities (d) June 2024 $ 350 $ 151 $ — $ 199 4.37 % Mountaineer (e) November 2024 $ 100 $ 85 $ — $ 15 3.82 % UGI Corporation (f) August 2024 $ 300 $ 252 $ — $ 48 5.62 % (a) At September 30, 2023 and 2022 the 2022 AmeriGas OLP Credit Agreement includes a $100 sublimit for letters of credit. (b) The UGI International 2023 Credit Facilities Agreement and the previous UGI International Credit Facilities Agreement permits borrowings in euros or USD. (c) The Energy Services Credit Agreement includes a $50 sublimit for letters of credit and is guaranteed by certain subsidiaries of Energy Services. (d) The UGI Utilities Credit Agreement includes a $100 sublimit for letters of credit. On November 9, 2023, UGI Utilities entered into the UGI Utilities 2023 Credit Agreement and concurrently terminated the UGI Utilities Credit Agreement, a predecessor agreement. See Significant Financing Activities above and Note 6 for additional information. See Significant Financing Activities Since September 30, 2022 above for additional information. (e) The Mountaineer 2023 Credit Agreements includes a $20 sublimit for letters of credit. (f) At September 30, 2023 and 2022, management intended to maintain a substantial portion of amounts outstanding under the UGI Corporation Senior Credit Facility beyond twelve months from the respective balance sheet dates. As such, borrowings outstanding are classified as “Long-term debt” on the Consolidated Balance Sheets. Subsequent to September 30, 2022, the Company repaid $87 of such borrowings and classified these repayments as “Current maturities of long-term debt” on the Consolidated Balance Sheets. The UGI Corporation Senior Credit Facility includes a $10 sublimit for letters of credit. N.A. - Not applicable
Schedule of Receivables Facility	Information regarding the amounts of trade receivables transferred to ESFC and the amounts sold to the bank are as follows: 2023 2022 2021 Trade receivables transferred to ESFC during the year $ 1,946 $ 2,221 $ 1,353 ESFC trade receivables sold to the bank during the year $ 535 $ 152 $ 308 ESFC trade receivables - end of year (a) $ 62 $ 101 $ 61 (a) At September 30, 2023, the amounts of ESFC trade receivables sold to the bank was $46, and is reflected as “Short-term borrowings” on the Consolidated Balance Sheets. At September 30, 2022 there were no ESFC trade receivables sold to the bank.
Schedule of Long-term Debt Instruments	Long-term debt comprises the following at September 30: 2023 2022 AmeriGas Propane: AmeriGas Partners Senior Notes: 5.50% due May 2025 $ 700 $ 700 5.875% due August 2026 675 675 5.625% due May 2024 — 675 5.75% due May 2027 525 525 9.375% due May 2028 500 — Unamortized debt issuance costs (15) (12) Total AmeriGas Propane 2,385 2,563 UGI International: 2.50% Senior Notes due December 2029 424 392 UGI International, LLC variable-rate term loan due March 2028 (a) 317 — UGI International, LLC variable-rate term loan due October 2023 (b) — 294 Other 6 2 Unamortized debt issuance costs (8) (6) Total UGI International 739 682 Midstream & Marketing: Energy Services variable-rate term loan due through February 2030 (c) 794 677 Other 41 40 Unamortized discount and debt issuance costs (15) (7) Total Energy Services 820 710 Utilities: UGI Utilities Senior Notes: 4.12% due September 2046 200 200 4.98% due March 2044 175 175 3.12% due April 2050 150 150 4.55% due February 2049 150 150 4.12% due October 2046 100 100 6.21% due September 2036 100 100 2.95% due June 2026 100 100 1.59% due June 2026 100 100 1.64% due September 2026 75 75 4.75% due July 2032 90 90 4.99% due September 2052 85 85 UGI Utilities Medium-Term Notes: 6.13% due October 2034 20 20 6.50% due August 2033 20 20 Mountaineer senior notes (d) 199 201 UGI Utilities variable-rate term loan due through July 2027 (e) 89 95 Other 2 1 Unamortized debt issuance costs (6) (6) Total Utilities 1,649 1,656 UGI Corporation: UGI Corporation Credit Facilities: UGI Corporation revolving credit facility maturing May 2025 (f) 283 252 UGI Corporation variable-rate term loan due May 2025 (g) 300 300 UGI Corporation variable-rate term loan due through May 2025 (h) 212 250 UGI Corporation variable-rate term loan due May 2025 (i) 215 215 Unamortized debt issuance costs (3) (2) Total UGI Corporation 1,007 1,015 Other — 6 Total long-term debt 6,600 6,632 Less: current maturities (57) (149) Total long-term debt due after one year $ 6,543 $ 6,483 (a) At September 30, 2023, the effective interest rate on the term loan was 4.95%. We have entered into pay-fixed, receive-variable interest rate swaps that fix the underlying variable rate at 3.10% through March 2026. (b) At September 30, 2022, the effective interest rate on the term loan was 1.89%. The term loan was repaid in full and terminated concurrently with the execution of the UGI International 2023 Credit Facilities Agreement. (c) At September 30, 2023 and 2022, the effective interest rates on the term loan were 7.82% and 5.13%, respectively. We have entered into a pay-fixed, receive-variable interest rate swap to effectively fix the underlying variable rate at 4.53% on these borrowings through September 2026. Term loan borrowings are due in equal quarterly installments of $2, with the balance of the principal being due in full at maturity. Under certain circumstances, Energy Services is required to make additional principal payments if the consolidated total leverage ratio, as defined, is greater than defined thresholds. This term loan is collateralized by substantially all of the assets of Energy Services, subject to certain exceptions and carveouts including, but not limited to, accounts receivable and certain real property. (d) Total long-term debt at September 30, 2023 and 2022, comprises $180 principal amount of Mountaineer senior secured notes plus unamortized premium of $19 and $21 for September 30, 2023 and 2022, respectively. The face interest rates on the Mountaineer senior notes range from 3.50% to 4.49%, with maturities ranging from 2027 to 2052. (e) At September 30, 2023 and 2022, the effective interest rate on this term loan was 3.92%. We have entered into a pay-fixed, receive-variable interest rate swap to effectively fix the underlying variable rate at approximately 2.82% on a portion of these borrowings through June 2026. Term loan borrowings are due in equal quarterly installments of $2, with the balance of the principal being due in full at maturity. (f) At September 30, 2023 and 2022, the effective interest rates on credit facility borrowings were 7.80% and 5.61%, respectively. (g) At September 30, 2023 and 2022, the effective interest rates on the term loan were 2.77% and 2.67%, respectively. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate at approximately 0.70% on these borrowings through September 2024. (h) At September 30, 2023 and 2022, the effective interest rates on the term loan were 7.79% and 4.15%, respectively. Term loan borrowings are due in equal quarterly installments of $9, commencing December 2022, which the balance of the principal being due in full at maturity. (i) At September 30, 2023 and 2022, the effective interest rates on the term loan were 4.73% and 3.53%, respectively. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate at approximately 0.70% on a portion of these borrowings through September 2024.
Schedule of Principal Repayments of Long-term Debt	Scheduled principal repayments of long-term debt for each of the next five fiscal years ending September 30 are as follows: 2024 2025 2026 2027 2028 AmeriGas Propane $ — $ 700 $ 675 $ 525 $ 500 UGI International 1 — — — 317 Midstream & Marketing 12 8 8 8 8 Utilities 6 6 281 70 40 UGI Corporation 38 973 — — — Total $ 57 $ 1,687 $ 964 $ 603 $ 865

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Sep. 30, 2023
Income Tax Disclosure [Abstract]
(Loss) Income Before Income Taxes	(Loss) income before income taxes comprises the following: 2023 2022 2021 Domestic $ (346) $ 362 $ 647 Foreign (1,491) 1,025 1,342 Total (loss) income before income taxes $ (1,837) $ 1,387 $ 1,989
Provisions for Income Taxes	The provisions for income taxes consist of the following: 2023 2022 2021 Current expense (benefit): Federal $ (1) $ 24 $ (48) State 37 18 7 Foreign 49 50 85 Total current expense 85 92 44 Deferred expense (benefit): Federal 34 45 168 State (21) (17) 48 Foreign (433) 193 262 Total deferred (benefit) expense (420) 221 478 Total income tax (benefit) expense $ (335) $ 313 $ 522
Reconciliation of U.S. Federal Statutory Tax Rate to Effective Tax Rate	A reconciliation from the U.S. federal statutory tax rate to our effective tax rate is as follows: 2023 2022 2021 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % Difference in tax rate due to: Goodwill impairment not deductible for tax (7.3) — — Effects of foreign operations 3.9 4.4 4.6 State income taxes, net of federal benefit (1.1) 1.5 1.9 Valuation allowance adjustments 1.1 (0.5) 1.0 Effects of tax rate changes – State, net of federal benefit 0.2 (1.4) — Effects of tax rate changes - International — (2.3) (1.3) Effects of U.S. tax legislation — — (0.8) Other, net 0.4 (0.1) (0.2) Effective tax rate 18.2 % 22.6 % 26.2 %
Deferred Tax Liabilities (Assets)	Deferred tax liabilities (assets) comprise the following at September 30: 2023 2022 Excess book basis over tax basis of property, plant and equipment $ 966 $ 867 Utility regulatory assets 84 106 Intangible assets and goodwill 81 75 Derivative instrument assets 19 514 Other 37 33 Gross deferred tax liabilities 1,187 1,595 Investment in AmeriGas Partners (28) (79) Pension plan liabilities (14) (21) Employee-related benefits (37) (38) Operating loss carryforwards (75) (48) Foreign tax credit carryforwards (64) (76) Utility regulatory liabilities (83) (85) Utility environmental liabilities (15) (15) Interest expense (83) (51) Other (58) (74) Gross deferred tax assets (457) (487) Deferred tax assets valuation allowance 141 141 Net deferred tax liabilities $ 871 $ 1,249
Reconciliation of Unrecognized Tax Benefits	A reconciliation of the beginning and ending amounts of unrecognized tax benefits is as follows: 2023 2022 2021 Unrecognized tax benefits — beginning of year $ 5 $ 3 $ 4 Additions for tax positions of the current year 3 2 — Decreases for tax positions taken in prior years — — (2) Increases for tax positions taken in prior years 19 1 1 Settlements with tax authorities/statute lapses (1) (1) — Unrecognized tax benefits — end of year $ 26 $ 5 $ 3

Employee Retirement Plans (Tabl

Employee Retirement Plans (Tables)	12 Months Ended
	Sep. 30, 2023
Retirement Benefits [Abstract]
Change in Pension Benefits and Other Postretirement Benefits Obligations	The following table provides a reconciliation of the PBOs of our pension plans (the U.S. Pension Plans and the UGI International pension plans), plan assets, and the related funded status of our pension plans as of September 30, 2023 and 2022. ABO is the present value of benefits earned to date with benefits based upon current compensation levels. PBO is ABO increased to reflect estimated future compensation. Pension Benefits 2023 2022 Change in benefit obligations: Benefit obligations — beginning of year $ 633 $ 870 Service cost 9 16 Interest cost 35 26 Actuarial gain (20) (240) Plan amendments — 1 Foreign currency 2 (6) Benefits paid (36) (34) Benefit obligations — end of year (a) $ 623 $ 633 Pension Benefits 2023 2022 Change in plan assets: Fair value of plan assets — beginning of year $ 541 $ 736 Actual gain (loss) on plan assets 31 (173) Foreign currency 1 (3) Employer contributions 19 15 Benefits paid (36) (34) Fair value of plan assets — end of year $ 556 $ 541 Funded status of the plans — end of year (b) $ (67) $ (92) Amounts recorded in UGI Corporation stockholders’ equity (pre-tax): Prior service cost $ 3 $ 3 Net actuarial gain (17) (17) Total $ (14) $ (14) Amounts recorded in regulatory assets and liabilities (pre-tax): Net actuarial loss 110 114 Total $ 110 $ 114 (a) The ABO for the U.S. Pension Plans was $558 and $570 as of September 30, 2023 and 2022, respectively. (b) Amounts are reflected in “Other noncurrent liabilities” and “Other assets” on the Consolidated Balance Sheets. Amounts reflected in “Other assets” are not material.
Actuarial Assumptions for U.S. Plans	The expected rate of return on assets assumption is based on current and expected asset allocations as well as historical and expected returns on various categories of plan assets (as further described below). Pension Plans 2023 2022 2021 Weighted-average assumptions: Discount rate – benefit obligations 6.09 % 5.70 % 3.13 % Discount rate – benefit cost 5.70 % 3.13 % 2.90 % Expected return on plan assets 7.50 % 7.10 % 7.10 % Rate of increase in salary levels 3.25 % 3.25 % 3.25 %
Net periodic pension (income) cost	Net periodic pension (income) cost includes the following components: Pension Benefits 2023 2022 2021 Service cost $ 9 $ 16 $ 12 Interest cost 35 26 22 Expected return on assets (45) (50) (40) Amortization of: Actuarial (gain) loss (3) 7 14 Net benefit (income) cost $ (4) $ (1) $ 8
Expected Payments for Pension Benefits and Other Postretirement Welfare Benefits	Expected payments for pension benefits are as follows: Pension Fiscal 2024 $ 39 Fiscal 2025 $ 39 Fiscal 2026 $ 41 Fiscal 2027 $ 43 Fiscal 2028 $ 44 Fiscal 2029 - 2033 $ 238
Pension Plans	The targets and actual allocations for the U.S. Pension Plans’ trust assets at September 30 are as follows: Actual Target Asset Allocation (b) 2023 2022 2023 2022 Equity investments: U.S. equities 25.8 % 26.5 % 27.6 % 24.7 % Non-U.S. equities 21.7 % 20.9 % 23.3 % 20.9 % Global equities (a) 13.9 % 13.8 % 10.7 % 13.1 % Total 61.4 % 61.2 % 61.6 % 58.7 % Fixed income funds & cash equivalents 35.5 % 35.5 % 35.0 % 35.0 % Alternative investments 3.1 % 3.3 % 3.4 % 6.3 % Total 100.0 % 100.0 % 100.0 % 100.0 % (a) Comprises investment funds that consist of a mix of U.S. and Non-U.S. equity securities. (b) There is a permitted range for the allocation of the trust assets for the U.S. Pension Plans, excluding the defined benefit pension plan for Mountaineer employees, which is 5% less than and greater than the target allocation.
Fair Value of U.S. Pension Plan and VEBA Trust Assets	The fair values of the U.S. Pension Plans trust assets by asset class as of September 30, 2023 and 2022 are as follows: 2023 2022 U.S. Pension Plans: Domestic equity investments: UGI Corporation Common Stock $ 19 $ 26 Total domestic equity investments (a) 19 26 Common collective trust funds: U.S. equity index investments 120 113 Non-U.S. equity index investments 117 110 Global equity index investments 75 72 Bond index investments 183 177 Cash equivalents 8 10 Total common collective trust funds (b) 503 482 Alternative investments (b) 17 17 Total $ 539 $ 525 (a) Level 1 investments within the fair value hierarchy. (b) Assets measured at NAV and therefore excluded from the fair value hierarchy.

Utility Regulatory Assets and_2

Utility Regulatory Assets and Liabilities and Regulatory Matters (Tables)	12 Months Ended
	Sep. 30, 2023
Regulated Operations [Abstract]
Schedule of Regulatory Assets	The following regulatory assets and liabilities associated with our Utilities reportable segment are included in our Consolidated Balance Sheets at September 30: 2023 2022 Regulatory assets (a): Income taxes recoverable $ 94 $ 83 Underfunded pension plans 111 114 Environmental costs 28 37 Deferred fuel and power costs 27 32 Removal costs, net 23 22 Other 64 52 Total regulatory assets $ 347 $ 340 Regulatory liabilities (a): Postretirement benefits $ 12 $ 11 Deferred fuel and power refunds 55 3 State income tax benefits — distribution system repairs 43 38 Excess federal deferred income taxes 254 279 Other 2 4 Total regulatory liabilities $ 366 $ 335 (a) Current regulatory assets are recorded in “Other current assets” on the Consolidated Balance Sheets. Regulatory liabilities are recorded in “Other current liabilities” and “Other noncurrent liabilities” on the Consolidated Balance Sheets.
Schedule of Regulatory Liabilities	The following regulatory assets and liabilities associated with our Utilities reportable segment are included in our Consolidated Balance Sheets at September 30: 2023 2022 Regulatory assets (a): Income taxes recoverable $ 94 $ 83 Underfunded pension plans 111 114 Environmental costs 28 37 Deferred fuel and power costs 27 32 Removal costs, net 23 22 Other 64 52 Total regulatory assets $ 347 $ 340 Regulatory liabilities (a): Postretirement benefits $ 12 $ 11 Deferred fuel and power refunds 55 3 State income tax benefits — distribution system repairs 43 38 Excess federal deferred income taxes 254 279 Other 2 4 Total regulatory liabilities $ 366 $ 335 (a) Current regulatory assets are recorded in “Other current assets” on the Consolidated Balance Sheets. Regulatory liabilities are recorded in “Other current liabilities” and “Other noncurrent liabilities” on the Consolidated Balance Sheets.

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Sep. 30, 2023
Inventory Disclosure [Abstract]
Components of Inventories	Inventories comprise the following at September 30: 2023 2022 Non-utility LPG and natural gas $ 212 $ 335 Gas Utility natural gas 55 166 Energy certificates 64 70 Materials, supplies and other 102 94 Total inventories $ 433 $ 665

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Sep. 30, 2023
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment comprise the following at September 30: 2023 2022 Estimated Useful Life Utility: Distribution $ 5,204 $ 4,746 Transmission 123 123 General and other 660 557 Work in process 95 124 Total Utility 6,082 5,550 Non-utility: Land 174 179 Buildings and improvements 418 426 10 - 40 years Transportation equipment 238 234 3 - 10 years Equipment, primarily cylinders and tanks 3,903 3,645 5 - 30 years Electric generation 190 216 25 - 40 years Pipeline and related assets 1,577 1,523 25 - 40 years Other 390 380 1 - 12 years Work in process 156 53 Total non-utility 7,046 6,656 Total property, plant and equipment $ 13,128 $ 12,206
Average Composite Depreciation Rates	The average composite depreciation rates at our Gas Utility and Electric Utility were as follows: 2023 2022 2021 Regulated natural gas utilities 2.4 % 2.6 % 2.6 % Electric Utility 2.3 % 2.4 % 2.3 %

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Sep. 30, 2023
Goodwill and Intangible Assets Disclosure [Abstract]
Changes in the Carrying Amount of Goodwill	Changes in the carrying amount of goodwill by reportable segment are as follows: AmeriGas UGI International Midstream & Marketing Utilities Total Balance September 30, 2021 $ 2,004 $ 993 $ 336 $ 437 $ 3,770 Purchase accounting adjustments — — — (5) (5) Foreign currency translation — (153) — — (153) Balance September 30, 2022 2,004 840 336 432 3,612 Impairment of goodwill (656) — — — (656) Acquisitions — 3 — — 3 Foreign currency translation — 68 — — 68 Balance September 30, 2023 $ 1,348 $ 911 $ 336 $ 432 $ 3,027
Schedule of Finite-Lived Intangible Assets	Intangible assets comprise the following at September 30: 2023 2022 Customer relationships $ 977 $ 1,006 Trademarks and tradenames 4 3 Noncompete agreements and other 26 71 Accumulated amortization (602) (621) Intangible assets, net (definite-lived) 405 459 Trademarks and tradenames (indefinite-lived) 38 41 Total intangible assets, net $ 443 $ 500
Schedule of Indefinite-Lived Intangible Assets	Intangible assets comprise the following at September 30: 2023 2022 Customer relationships $ 977 $ 1,006 Trademarks and tradenames 4 3 Noncompete agreements and other 26 71 Accumulated amortization (602) (621) Intangible assets, net (definite-lived) 405 459 Trademarks and tradenames (indefinite-lived) 38 41 Total intangible assets, net $ 443 $ 500

Equity (Tables)

Equity (Tables)	12 Months Ended
	Sep. 30, 2023
Equity [Abstract]
Common Stock Share Activity	UGI Preferred Stock and Common Stock share activity for Fiscal 2023, Fiscal 2022 and Fiscal 2021 is as follows: Preferred Stock Common Stock Issued/Outstanding Issued Treasury Outstanding Balance at September 30, 2020 — 209,514,044 (1,159,606) 208,354,438 Issued: Equity Unit Offering 220,000 — — — Employee and director plans — 329,252 554,315 883,567 Reacquired common stock – employee and director plans — — (21,870) (21,870) Balance at September 30, 2021 220,000 209,843,296 (627,161) 209,216,135 Issued: Employee and director plans — 717,198 799,152 1,516,350 Repurchases of common stock — — (900,000) (900,000) Reacquired common stock – employee and director plans — — (250,273) (250,273) Balance at September 30, 2022 220,000 210,560,494 (978,282) 209,582,212 Issued: Employee and director plans — 345,558 167,313 512,871 Repurchases of common stock — — (600,000) (600,000) Balance at September 30, 2023 220,000 210,906,052 (1,410,969) 209,495,083

Leases (Tables)

Leases (Tables)	12 Months Ended
	Sep. 30, 2023
Leases [Abstract]
ROU Assets and Lease Liabilities	ROU assets and lease liabilities recorded in the Consolidated Balance Sheets as of September 30 are as follows: 2023 2022 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 420 $ 368 Other assets Finance lease ROU assets 50 48 Property, plant and equipment Total ROU assets $ 470 $ 416 Lease liabilities: Operating lease liabilities — current $ 87 $ 82 Other current liabilities Operating lease liabilities — noncurrent 340 294 Other noncurrent liabilities Finance lease liabilities — current 5 4 Current maturities of long-term debt Finance lease liabilities — noncurrent 45 41 Long-term debt Total lease liabilities $ 477 $ 421
Components of Lease Cost, Cash and Non-cash Lease Liability Activity, Weighted-average Remaining Lease Term and Discount Rate	The components of lease cost for Fiscal 2023, Fiscal 2022 and Fiscal 2021 are as follows: 2023 2022 2021 Operating lease cost $ 104 $ 96 $ 101 Finance lease cost: Amortization of ROU assets 3 4 4 Interest on lease liabilities 3 3 3 Variable lease cost 2 6 4 Short-term lease cost 4 2 2 Total lease cost $ 116 $ 111 $ 114 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statements of Cash Flows during Fiscal 2023, Fiscal 2022 and Fiscal 2021: 2023 2022 2021 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 103 $ 95 $ 99 Operating cash flows — finance leases $ 3 $ 3 $ 3 Financing cash flows — finance leases $ 1 $ 2 $ 3 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities $ 136 $ 72 $ 85 ROU assets obtained in exchange for finance lease liabilities $ 6 $ 2 $ 1 The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2023 2022 Operating leases 7.1 6.0 Finance leases 5.3 3.7 Weighted-average discount rate (%) 2023 2022 Operating leases 4.5% 3.6% Finance leases 2.2% 1.8%
Schedule of Expected Annual Lease Payments Based on Maturities of Operating Leases	Expected annual lease payments based on maturities of operating and finance leases, as well as a reconciliation to the lease liabilities on the Consolidated Balance Sheet, as of September 30, 2023, were as follows: 2024 2025 2026 2027 2028 After 2028 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 104 $ 86 $ 72 $ 61 $ 49 $ 130 $ 502 $ (75) $ 427 Finance leases $ 5 $ 5 $ 5 $ 4 $ 4 $ 76 $ 99 $ (49) $ 50
Schedule of Expected Annual Lease Payments Based on Maturities of Finance Leases	Expected annual lease payments based on maturities of operating and finance leases, as well as a reconciliation to the lease liabilities on the Consolidated Balance Sheet, as of September 30, 2023, were as follows: 2024 2025 2026 2027 2028 After 2028 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 104 $ 86 $ 72 $ 61 $ 49 $ 130 $ 502 $ (75) $ 427 Finance leases $ 5 $ 5 $ 5 $ 4 $ 4 $ 76 $ 99 $ (49) $ 50

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Sep. 30, 2023
Fair Value Disclosures [Abstract]
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 as described in Note 2: Asset (Liability) Level 1 Level 2 Level 3 Total September 30, 2023: Derivative instruments: Assets: Commodity contracts (c) $ 117 $ 115 $ — $ 232 Foreign currency contracts $ — $ 38 $ — $ 38 Interest rate contracts $ — $ 28 $ — $ 28 Liabilities: Commodity contracts (c) $ (193) $ (81) $ — $ (274) Foreign currency contracts $ — $ (2) $ — $ (2) Non-qualified supplemental postretirement grantor trust investments (a) $ 39 $ — $ — $ 39 September 30, 2022 Derivative instruments: Assets: Commodity contracts (b) $ 938 $ 1,268 $ 27 $ 2,233 Foreign currency contracts $ — $ 119 $ — $ 119 Interest rate contracts $ — $ 66 $ — $ 66 Liabilities: Commodity contracts (b) $ (377) $ (136) $ — $ (513) Foreign currency contracts $ — $ (2) $ — $ (2) Non-qualified supplemental postretirement grantor trust investments (a) $ 43 $ — $ — $ 43 (a) Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans (see Note 8). (b) Includes derivative assets and liabilities associated with the October 2022 sale of UGI International energy marketing business located in the U.K., classified as held for sale (see Note 5). (c) 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: 2023 2022 Carrying amount $ 6,647 $ 6,665 Estimated fair value $ 6,238 $ 6,189

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Sep. 30, 2023
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 September 30, 2023 and 2022 and the final settlement dates of the Company's open derivative contracts as of September 30, 2023, but excluding those derivatives that qualified for the NPNS exception: Notional Amounts September 30, Type Units Settlements Extending Through 2023 2022 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms September 2024 38 19 Non-utility Operations LPG swaps Gallons February 2026 727 874 Natural gas futures, forward, basis swap, options and pipeline contracts (a) Dekatherms December 2027 338 363 Electricity forward and futures contracts Kilowatt hours December 2026 1,260 2,446 Interest Rate Risk: Interest rate swaps Euro March 2026 € 300 € 300 Interest rate swaps USD September 2026 $ 1,270 $ 1,358 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD September 2026 $ 425 $ 465 Net investment hedge forward foreign exchange contracts Euro December 2026 € 256 € 411 (a) Amounts at September 30, 2023 and 2022 include contracts associated with certain UGI International energy marketing business transactions (see Note 5).
Schedule of Derivative Assets, Liabilities and the Effects of Offsetting	The following table presents the Company’s derivative assets and liabilities by type, as well as the effects of offsetting, as of September 30: 2023 2022 Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 14 $ 57 Interest rate contracts 28 66 42 123 Derivatives subject to PGC and DS mechanisms: Commodity contracts 6 31 Derivatives not designated as hedging instruments: Commodity contracts (a) 226 2,202 Foreign currency contracts 24 62 250 2,264 Total derivative assets – gross 298 2,418 Gross amounts offset in the balance sheet (124) (295) Cash collateral received (40) (398) Total derivative assets – net $ 134 $ 1,725 Derivative liabilities: Derivatives subject to PGC and DS mechanisms: Commodity contracts $ (8) $ (26) Derivatives not designated as hedging instruments: Commodity contracts (a) (266) (487) Foreign currency contracts (2) (2) (268) (489) Total derivative liabilities – gross (276) (515) Gross amounts offset in the balance sheet 124 295 Cash collateral pledged 53 7 Total derivative liabilities – net $ (99) $ (213)
Effects of Derivative Instruments on Condensed Consolidated Statements of Income and Changes in AOCI and Noncontrolling Interest	The following tables provide information on the effects of derivative instruments on the Consolidated Statements of Income and changes in AOCI for Fiscal 2023, Fiscal 2022 and Fiscal 2021: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from 2023 2022 2021 2023 2022 2021 Cash Flow Hedges: Interest rate contracts $ 25 $ 91 $ 4 $ 40 $ (7) $ (25) Interest expense Net Investment Hedges: Foreign currency contracts $ (21) $ 69 $ 4 Gain (Loss) Location of 2023 2022 2021 Derivatives Not Designated as Hedging Instruments: Commodity contracts $ 11 $ (9) $ (17) Revenues Commodity contracts (1,771) 1,181 1,545 Cost of sales Commodity contracts 2 1 5 Other operating income, net Foreign currency contracts (23) 63 9 Other non-operating (expense) income, net Total $ (1,781) $ 1,236 $ 1,542

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Sep. 30, 2023
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	The tables below present changes in AOCI, net of tax, during Fiscal 2023, Fiscal 2022 and Fiscal 2021: Postretirement Derivative Foreign Total AOCI - September 30, 2020 $ (26) $ (54) $ (67) $ (147) Other comprehensive income (loss) before reclassification adjustments 7 3 (23) (13) Amounts reclassified from AOCI 2 18 — 20 Other comprehensive income (loss) attributable to UGI 9 21 (23) 7 AOCI - September 30, 2021 $ (17) $ (33) $ (90) $ (140) Other comprehensive income (loss) before reclassification adjustments 28 64 (341) (249) Amounts reclassified from AOCI 3 6 — 9 Other comprehensive income (loss) attributable to UGI 31 70 (341) (240) AOCI - September 30, 2022 $ 14 $ 37 $ (431) $ (380) Other comprehensive income (loss) before reclassification adjustments 5 16 132 153 Amounts reclassified from AOCI (2) (27) — (29) Other comprehensive income (loss) attributable to UGI 3 (11) 132 124 AOCI - September 30, 2023 $ 17 $ 26 $ (299) $ (256)

Other Operating Income, Net a_2

Other Operating Income, Net and Other Non-Operating Income (Expense), Net (Tables)	12 Months Ended
	Sep. 30, 2023
Component of Operating Income [Abstract]
Other Operating Income, Net	Other operating income, net, comprises the following: 2023 2022 2021 Finance charges $ 17 $ 18 $ 17 Gains on sales of fixed assets, net (a) 61 33 11 Gain on early derivative termination — — 5 Foreign currency transaction gains (losses) 7 (5) — Cylinder deposit income 23 18 9 Interest and interest-related income 6 1 — Other, net 18 14 (9) Total other operating income, net $ 132 $ 79 $ 33
Schedule of Other Non-Operating (Expense) Income, Net	Other non-operating (expense) income, net comprises the following: 2023 2022 2021 (Losses) gains on foreign currency contracts, net $ (23) $ 63 $ 9 Amortization of excluded components of certain net investment hedges 7 7 2 Pension and other postretirement plans non-service income, net 9 5 1 Total other non-operating (expense) income, net $ (7) $ 75 $ 12

Equity Method Investments (Tabl

Equity Method Investments (Tables)	12 Months Ended
	Sep. 30, 2023
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Equity Method Investments	Equity method investments which are included within “Other assets” on the Consolidated Balance Sheets, comprises the following as of September 30: Carrying Value Ownership Interest Investees 2023 2022 2023 2022 Midstream & Marketing Aurum Renewables $ 45 $ — 40% N/A Pine Run 77 68 49% 49% MBL Bioenergy 122 23 99.99% 99.99% Other 20 18 various various Total Midstream & Marketing 264 109 UGI International 35 21 various various Total investments in equity method investees $ 299 $ 130

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Sep. 30, 2023
Segment Reporting [Abstract]
Schedule of Segment Reporting Information	Total Elim- AmeriGas UGI International Midstream Utilities Corporate & 2023 Revenues from external customers $ 8,928 $ — $ 2,581 $ 2,965 $ 1,596 $ 1,780 $ 6 Intersegment revenues $ — $ (326) (b) $ — $ — $ 251 $ 74 $ 1 Cost of sales $ 6,937 $ (325) (b) $ 1,250 $ 2,045 $ 1,360 $ 953 $ 1,654 Operating (loss) income $ (1,444) $ — $ 268 $ 215 $ 285 $ 357 $ (2,569) Income (loss) from equity investees 2 — — (4) 6 — — Loss on extinguishments of debt (9) — — — — — (9) Other non-operating (loss) income, net (7) — — 23 — 8 (38) (Loss) earnings before interest expense and income taxes (1,458) — 268 234 291 365 (2,616) Interest expense (379) — (163) (37) (45) (82) (52) Income tax benefit (expense) 335 — (34) (25) (53) (64) 511 Net (loss) income attributable to UGI $ (1,502) $ — $ 71 $ 172 $ 193 $ 219 $ (2,157) Depreciation and amortization $ 532 $ — $ 177 $ 116 $ 86 $ 152 $ 1 Total assets $ 15,401 $ (173) $ 3,415 $ 3,105 $ 3,160 $ 5,691 $ 203 Short-term borrowings $ 649 $ — $ — $ 214 $ 103 $ 332 $ — Capital expenditures (including the effects of accruals) $ 956 $ 134 $ 129 $ 130 $ 563 $ — Investments in equity investees $ 299 $ — $ — $ 35 $ 264 $ — $ — Total Elim- AmeriGas UGI International Midstream Utilities Corporate & 2022 Revenues from external customers $ 10,106 $ — $ 2,943 $ 3,686 $ 1,957 $ 1,515 $ 5 Intersegment revenues $ — $ (477) (b) $ — $ — $ 369 $ 105 $ 3 Cost of sales $ 5,973 $ (474) (b) $ 1,613 $ 2,751 $ 1,876 $ 798 $ (591) Operating income $ 1,666 $ — $ 307 $ 237 $ 246 $ 327 $ 549 (Loss) income from equity investees (14) — — (2) 23 — (35) Loss on extinguishments of debt (11) — — — — — (11) Other non-operating income, net 75 — — 19 — 9 47 Earnings before interest expense and income taxes 1,716 — 307 254 269 336 550 Interest expense (329) — (160) (28) (41) (65) (35) Income tax expense (313) — (35) (50) (65) (65) (98) Noncontrolling interests’ net (income) loss (1) — — (1) — — — Net income attributable to UGI $ 1,073 $ — $ 112 $ 175 $ 163 $ 206 $ 417 Depreciation and amortization $ 518 $ — $ 177 $ 116 $ 79 $ 144 $ 2 Total assets $ 17,575 $ (203) $ 4,332 $ 4,610 $ 3,286 $ 5,354 $ 196 Short-term borrowings $ 368 $ — $ 131 $ 1 $ — $ 236 $ — Capital expenditures (including the effects of accruals) $ 835 $ — $ 128 $ 107 $ 38 $ 562 $ — Investments in equity investees $ 130 $ — $ — $ 20 $ 109 $ — $ 1 2021 Revenues from external customers $ 7,447 $ — $ 2,614 $ 2,651 $ 1,182 $ 1,015 $ (15) Intersegment revenues $ — $ (291) (b) $ — $ — $ 224 $ 64 $ 3 Cost of sales $ 2,614 $ (288) (b) $ 1,217 $ 1,598 $ 1,033 $ 458 $ (1,404) Operating income $ 2,350 $ — $ 385 $ 314 $ 160 $ 241 $ 1,250 (Loss) income from equity investees (63) — — — 30 — (93) Other non-operating income, net 12 — — 3 — 1 8 Earnings before interest expense and income taxes 2,299 — 385 317 190 242 1,165 Interest expense (310) — (159) (27) (42) (56) (26) Income tax expense (522) — (58) (69) (41) (42) (312) Net income attributable to UGI $ 1,467 $ — $ 168 $ 221 $ 107 $ 144 $ 827 Depreciation and amortization $ 502 $ — $ 173 $ 134 $ 76 $ 119 $ — Total assets $ 16,723 $ (241) $ 4,485 $ 4,421 $ 3,010 $ 4,859 $ 189 Short-term borrowings $ 367 $ — $ 170 $ — $ — $ 197 $ — Capital expenditures (including the effects of accruals) $ 674 $ — $ 130 $ 107 $ 43 $ 394 $ — Investments in equity investees $ 174 $ — $ — $ 11 $ 163 $ — $ — (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, for Fiscal 2023, Fiscal 2022 and Fiscal 2021: Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing 2023 Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 4 $ 6 Net losses on commodity derivative instruments not associated with current-period transactions Cost of Sales $ (16) $ (1,402) $ (236) AmeriGas performance enhancement Operating and administrative expenses $ (24) $ — $ — Loss on extinguishment of debt Loss on extinguishments of debt $ (9) $ — $ — Unrealized losses on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ (38) $ — Loss associated with impairment of AmeriGas Propane goodwill Impairment of goodwill $ (656) $ — $ — Costs associated with exit of the UGI International energy marketing business Revenues/Operating and administrative expenses $ — $ (27) $ — Costs associated with exit of the UGI International energy marketing business Loss on disposal of UGI International energy marketing business $ — $ (221) $ — 2022 Net gains (losses) on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 9 $ (4) Net (losses) gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ (185) $ 797 $ (21) Net gains on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ 2 $ — Restructuring costs Operating and administrative expenses $ (16) $ (9) $ (1) Loss on extinguishment of debt Loss on extinguishments of debt $ — $ (11) $ — Unrealized gains on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 50 $ — AmeriGas performance enhancement Operating and administrative expenses $ (5) $ — $ — Costs associated with exit of the UGI International energy marketing business Operating and administrative expenses $ — $ (5) $ — Impairments associated with certain equity method investments Income (loss) from equity investees $ — $ — $ (35) 2021 Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (15) Net gains on commodity derivative instruments not associated with current-period transactions Cost of Sales $ 167 $ 1,065 $ 173 Unrealized gains on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 8 $ — Business transformation expenses Operating and administrative expenses $ (54) $ (33) $ — Impairment of customer relationship intangible Operating and administrative expenses $ — $ (20) $ — Impairments associated with certain equity method investments Income (loss) from equity investees $ — $ — $ (93) (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, Utilities and AmeriGas Propane.

SCHEDULE I _ CONDENSED FINANC_2

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) (Tables)	12 Months Ended
	Sep. 30, 2023
Condensed Financial Information Disclosure [Abstract]
Balance Sheets	BALANCE SHEETS (Millions of dollars) September 30, 2023 2022 ASSETS Current assets: Cash and cash equivalents $ 7 $ 20 Accounts receivable – related parties 11 24 Prepaid expenses and other current assets 23 20 Total current assets 41 64 Property, plant and equipment, net — 1 Investments in subsidiaries 5,343 7,035 Other assets 143 97 Total assets $ 5,527 $ 7,197 LIABILITIES AND COMMON STOCKHOLDERS’ EQUITY Current liabilities: Current maturities of long-term debt $ 38 $ 125 Accounts and notes payable 28 20 Accrued liabilities 39 51 Total current liabilities 105 196 Long-term debt 969 889 Other noncurrent liabilities 67 46 Total liabilities 1,141 1,131 Commitments and contingencies (Note 1) Equity: Preferred Stock, without par value (authorized - 5,000,000; issued - 220,000 and 220,000, respectively) 167 162 Common Stock, without par value (authorized – 450,000,000 shares; issued – 210,906,052 and 210,560,494 shares, respectively) 1,503 1,483 Retained earnings 3,027 4,841 Accumulated other comprehensive loss (256) (380) Treasury stock, at cost (55) (40) Total common stockholders’ equity 4,386 6,066 Total liabilities and common stockholders’ equity $ 5,527 $ 7,197
Statements of Income	STATEMENTS OF INCOME (Millions of dollars, except per share amounts) Year Ended September 30, 2023 2022 2021 Revenues $ — $ — $ — Costs and expenses: Operating and administrative expenses 95 74 94 Other operating income, net (a) (83) (63) (65) 12 11 29 Operating loss (12) (11) (29) Pension and other postretirement plans non-service expense — (3) — Interest expense (52) (35) (27) Loss before income taxes (64) (49) (56) Income tax (benefit) expense (13) — 9 Loss before equity in income of unconsolidated subsidiaries (51) (49) (65) Equity in (loss) income of unconsolidated subsidiaries (1,451) 1,122 1,532 Net (loss) income attributable to UGI Corporation $ (1,502) $ 1,073 $ 1,467 Other comprehensive (loss) income (8) 34 7 Equity in other comprehensive income (loss) of unconsolidated subsidiaries 132 (274) — Comprehensive (loss) income attributable to UGI Corporation $ (1,378) $ 833 $ 1,474 (Loss) earnings per common share attributable to UGI Corporation stockholders: Basic $ (7.16) $ 5.11 $ 7.02 Diluted $ (7.16) $ 4.97 $ 6.92 Weighted - average common shares outstanding (thousands): Basic 209,806 209,940 209,063 Diluted 209,806 215,821 212,126 (a) UGI provides certain financial and administrative services to certain of its subsidiaries. UGI bills these subsidiaries monthly for all direct expenses incurred by UGI on behalf of its subsidiaries as well as allocated shares of indirect corporate expense incurred or paid with respect to services provided by UGI. The allocation of indirect UGI corporate expenses to certain of its subsidiaries utilizes a weighted, three-component formula comprising revenues, operating expenses, and net assets employed and considers the relative percentage of such items for each subsidiary to the total of such items for all UGI operating subsidiaries for which general and administrative services are provided. Management believes that this allocation method is reasonable and equitable to its subsidiaries. These billed expenses are classified as “Other operating income, net” in the Statements of Income above.
Statements of Cash Flows	STATEMENTS OF CASH FLOWS (Millions of dollars) Year Ended September 30, 2023 2022 2021 NET CASH PROVIDED BY OPERATING ACTIVITIES (a) $ 636 $ 485 $ 300 CASH FLOWS FROM INVESTING ACTIVITIES: Return of capital distributions — 175 — Net investments in unconsolidated subsidiaries (309) (390) (401) Net cash used by investing activities (309) (215) (401) CASH FLOWS FROM FINANCING ACTIVITIES: Dividends on UGI Common Stock (308) (296) (282) Issuances of debt, net of issuance costs 327 597 483 Repayments of long-term debt (333) (530) (385) Issuance of Preferred Stock, net of issuance costs — — 213 Issuances of UGI Common Stock 12 19 19 Repurchases of UGI Common Stock (22) (38) — Payments on Purchase Contracts (16) (16) — Net cash (used) provided by financing activities (340) (264) 48 Cash and cash equivalents (decrease) increase $ (13) $ 6 $ (53) Cash and cash equivalents: End of year $ 7 $ 20 $ 14 Beginning of year 20 14 67 Cash and cash equivalents (decrease) increase $ (13) $ 6 $ (53) (a) Includes dividends received from unconsolidated subsidiaries of $680, $506 and $354 for the years ended September 30, 2023, 2022 and 2021, respectively.

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Revenue Recognition (Details)	12 Months Ended
	Sep. 30, 2023
Accounting Policies [Abstract]
Contract length (less than)	one year

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	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Accounting Policies [Abstract]
Weighted-average common shares outstanding for basic computation (in shares)	209,806	209,940	209,063
Incremental shares issuable for stock options, common stock awards and Equity Units (in shares)	0	5,881	3,063
Weighted-average common shares outstanding for diluted computation (in shares)	209,806	215,821	212,126
Antidilutive securities excluded from computation of earnings per share (in shares)	6,132	8,138	5,267

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Reconciliation of the total cash, cash equivalents and restricted cash (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Accounting Policies [Abstract]
Cash and cash equivalents	$ 241	$ 405	$ 855
Restricted cash	99	64	22
Cash, cash equivalents and restricted cash	$ 340	$ 469	$ 877	$ 357

Summary of Significant Accoun_7

Summary of Significant Accounting Policies- Property, Plant and Equipment and Related Depreciation (Details) - USD ($)	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation expense included in cost of sales	$ 0	$ 0	$ 0
Utilities
Public Utility, Property, Plant and Equipment [Line Items]
Amortization period	5 years

Summary of Significant Accoun_8

Summary of Significant Accounting Policies - Goodwill and Intangible Assets (Details) - USD ($)	3 Months Ended		12 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Goodwill [Line Items]
Impairment of goodwill			$ 656,000,000	$ 0	$ 0
Goodwill	$ 3,027,000,000		3,027,000,000	3,612,000,000	3,770,000,000
Accumulated impairment losses	656,000,000		656,000,000	0
AmeriGas Propane
Goodwill [Line Items]
Impairment of goodwill	656,000,000	$ 656,000,000	656,000,000
Goodwill	1,348,000,000		1,348,000,000	$ 2,004,000,000	$ 2,004,000,000
Accumulated impairment losses	$ 656,000,000		$ 656,000,000
UGI International
Goodwill [Line Items]
Fair value in excess of carrying value	10%		10%
Goodwill	$ 911,000,000		$ 911,000,000

Summary of Significant Accoun_9

Summary of Significant Accounting Policies - Refundable Tank and Cylinder Deposits and Environmental Matters (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Accounting Policies [Abstract]
Customer paid deposits primarily on owned tanks and cylinders	$ 249	$ 243

Accounting Changes (Details)

Accounting Changes (Details) - USD ($) $ in Millions	Sep. 30, 2023	Oct. 01, 2022	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Equity	$ 4,394		$ 6,074	$ 5,531
Common Stock, without par value | Cumulative effect of change in accounting - ASU 2020-06 (Note 3)
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Equity		$ 6
Preferred Stock
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Equity	167		162	213
Preferred Stock | Cumulative effect of change in accounting - ASU 2020-06 (Note 3)
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Equity		6	5
Retained earnings
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Equity	$ 3,027		4,841	$ 4,081	$ 2,908
Retained earnings | Cumulative effect of change in accounting - ASU 2020-06 (Note 3)
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Equity		$ 1	$ 1

Revenue from Contracts with C_3

Revenue from Contracts with Customers - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue [Line Items]
Contract liabilities	$ 158	$ 164
Contract liabilities, recognized revenue	$ 127	$ 119	$ 138
Natural Gas Transportation and Gathering Services
Disaggregation of Revenue [Line Items]
Term of contract with customer (up to)	30 years
Storage Services
Disaggregation of Revenue [Line Items]
Term of contract with customer (up to)	1 year
Natural Gas
Disaggregation of Revenue [Line Items]
Term of contract with customer (up to)	15 years
Midstream & Marketing
Disaggregation of Revenue [Line Items]
Remaining performance obligations	$ 2,200
Utilities
Disaggregation of Revenue [Line Items]
Remaining performance obligations	$ 200

Revenue from Contracts with C_4

Revenue from Contracts with Customers - Schedule of Disaggregated Revenues By Reportable Segment (Details) - USD ($) $ in Millions		12 Months Ended
	Nov. 01, 2022	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		$ 8,761	$ 9,981	$ 7,348
Other revenues		167	125	99
Total revenues		8,928	10,106	7,447
Weather Normalization Adjustment Rider | Pennsylvania Public Utility Commission | Regulated natural gas utilities
Disaggregation of Revenue [Line Items]
Public utilities, rate period	5 years
Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,742	1,510	1,006
Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,020	875	568
Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		413	365	218
Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		177	171	148
Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		89	76	51
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		43	23	21
Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		7,019	8,471	6,342
Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		3,952	4,436	3,957
Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		325	496	328
Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		2,139	2,951	1,564
Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		251	211	181
Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		31	48	16
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		14	9	8
Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		33	34	13
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		274	286	275
Elim- inations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(323)	(474)	(288)
Other revenues		(3)	(3)	(3)
Total revenues		(326)	(477)	(291)
Elim- inations | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(74)	(105)	(64)
Elim- inations | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Elim- inations | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Elim- inations | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Elim- inations | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(73)	(104)	(62)
Elim- inations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(1)	(1)	(2)
Elim- inations | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(249)	(369)	(224)
Elim- inations | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Elim- inations | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Elim- inations | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(143)	(264)	(126)
Elim- inations | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Elim- inations | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(106)	(105)	(98)
Elim- inations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Elim- inations | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Elim- inations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Elim- inations | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues		0	0	0
Elim- inations | UGI International
Disaggregation of Revenue [Line Items]
Total revenues		0	0	0
Elim- inations | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues		251	369	224
Elim- inations | Utilities
Disaggregation of Revenue [Line Items]
Total revenues		74	105	64
Operating Segments | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		2,496	2,864	2,548
Other revenues		85	79	66
Total revenues		2,581	2,943	2,614
Operating Segments | AmeriGas Propane | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | AmeriGas Propane | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | AmeriGas Propane | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | AmeriGas Propane | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		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
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | AmeriGas Propane | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		2,496	2,864	2,548
Operating Segments | AmeriGas Propane | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		2,184	2,439	2,203
Operating Segments | AmeriGas Propane | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		118	218	139
Operating Segments | AmeriGas Propane | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | AmeriGas Propane | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | AmeriGas Propane | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | AmeriGas Propane | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		194	207	206
Operating Segments | UGI International
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		2,927	3,652	2,617
Other revenues		38	34	34
Total revenues		2,965	3,686	2,651
Operating Segments | UGI International | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | UGI International | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | UGI International | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | UGI International | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		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
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | UGI International | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		2,927	3,652	2,617
Operating Segments | UGI International | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,768	1,997	1,754
Operating Segments | UGI International | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		207	278	189
Operating Segments | UGI International | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		872	1,298	605
Operating Segments | UGI International | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | UGI International | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | UGI International | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		80	79	69
Operating Segments | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,845	2,324	1,401
Other revenues		2	2	5
Total revenues		1,847	2,326	1,406
Operating Segments | Midstream & Marketing | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Midstream & Marketing | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Midstream & Marketing | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Midstream & Marketing | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		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
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Midstream & Marketing | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,845	2,324	1,401
Operating Segments | Midstream & Marketing | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Midstream & Marketing | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Midstream & Marketing | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,410	1,917	1,085
Operating Segments | Midstream & Marketing | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		251	211	181
Operating Segments | Midstream & Marketing | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		137	153	114
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		14	9	8
Operating Segments | Midstream & Marketing | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		33	34	13
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Utilities
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,816	1,615	1,070
Other revenues		38	5	9
Total revenues		1,854	1,620	1,079
Operating Segments | Utilities | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,816	1,615	1,070
Operating Segments | Utilities | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,020	875	568
Operating Segments | Utilities | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		413	365	218
Operating Segments | Utilities | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		177	171	148
Operating Segments | Utilities | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		162	180	113
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		44	24	23
Operating Segments | Utilities | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Utilities | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Utilities | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Utilities | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Utilities | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Utilities | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Utilities | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Other revenues		7	8	(12)
Total revenues		7	8	(12)
Corporate & Other | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		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
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		$ 0	$ 0	$ 0

Acquisitions and Dispositions -

Acquisitions and Dispositions - Narrative (Details) - USD ($) $ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Sep. 01, 2021

Sep. 30, 2023

Oct. 31, 2022

Jan. 31, 2022

Sep. 30, 2023

Dec. 31, 2022

Sep. 30, 2022

Dec. 31, 2021

Sep. 30, 2023

Sep. 30, 2022

Sep. 30, 2021

Oct. 31, 2023

Jul. 31, 2023

Oct. 21, 2022

Business Acquisition [Line Items]

Purchase accounting adjustments

$ (5)

Investments in equity method investees

$ 146

47

$ 65

Discontinued Operation, Gain (Loss) on Disposal, Statement of Income or Comprehensive Income [Extensible Enumeration]

Costs associated with exit of the UGI International energy marketing business

2021 UGI Corporation Senior Credit Facility

Business Acquisition [Line Items]

Proceeds from issuance of debt

$ 215

Sale | U.K. Energy Marketing Business

Business Acquisition [Line Items]

Net cash payment

$ 19

Pre-tax loss

$ 215

After tax loss

$ 151

Net carrying value

$ 276

$ 276

$ 206

Sale | France Energy Marketing Business | Subsequent Event

Business Acquisition [Line Items]

Net cash payment

$ 25

Sale | Belgium Energy Marketing Business

Business Acquisition [Line Items]

Net cash payment

$ 3

$ 3

3

Pre-tax loss

6

After tax loss

5

Sale | Netherland Energy Marketing Business

Business Acquisition [Line Items]

Net carrying value

$ 44

44

$ 44

Reduction in revenue

$ 4

Held-for-Sale, Not Discontinued Operations | Netherland Energy Marketing Business

Business Acquisition [Line Items]

Net cash payment

$ 6

Pre-tax impairment charges

$ 19

Mountaineer

Business Acquisition [Line Items]

Total purchase price

540

Liabilities incurred

$ 140

Transaction costs

$ 13

Pennant

Business Acquisition [Line Items]

Total purchase price

$ 61

Percentage of voting interests acquired

53%

53%

Pennant | Energy Services

Business Acquisition [Line Items]

Percentage of voting interests acquired

53%

53%

Investments in equity method investees

$ 61

Stonehenge | Energy Services

Business Acquisition [Line Items]

Total purchase price

$ 190

Acquisitions and Dispositions_2

Acquisitions and Dispositions - Components of the Preliminary Mountaineer Purchase Price Allocation (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021	Sep. 01, 2021
Liabilities assumed:
Goodwill	$ 3,027	$ 3,612	$ 3,770
Mountaineer
Assets acquired:
Cash and cash equivalents				$ 3
Accounts receivable				14
Inventories				41
Other current assets				21
Property, plant and equipment				397
Other noncurrent assets				48
Total assets acquired				524
Liabilities assumed:
Short-term borrowings				55
Accounts payable				20
Other current liabilities				52
Long-term debt				164
Pension and other postretirement benefit obligation				33
Deferred income taxes				21
Other noncurrent liabilities				29
Total liabilities assumed				374
Goodwill				250
Net consideration transferred				$ 400

Debt - Narrative (Details)

Debt - Narrative (Details)

1 Months Ended

6 Months Ended

12 Months Ended

Nov. 09, 2023 USD ($)

Sep. 20, 2023 USD ($)

May 31, 2023 USD ($)

May 12, 2023

Apr. 24, 2023 USD ($)

Mar. 31, 2023 USD ($) cure

Mar. 07, 2023 EUR (€)

Feb. 23, 2023 USD ($)

Dec. 13, 2022 USD ($)

Oct. 20, 2022 USD ($)

Jun. 30, 2023 USD ($)

May 31, 2023 USD ($)

Mar. 31, 2023 USD ($)

Oct. 20, 2024 USD ($)

Apr. 30, 2024 USD ($)

Sep. 30, 2023 USD ($)

Sep. 30, 2022 USD ($)

Sep. 30, 2021 USD ($)

Nov. 15, 2023 USD ($)

Nov. 14, 2023 USD ($)

Debt Instrument [Line Items]

Loss on extinguishments of debt

$ 9,000,000

$ 11,000,000

$ 0

Settlement of Energy Services interest rate swap, net of amortization

(19,000,000)

0

$ 0

Restricted net assets

3,600,000,000

Interest rate swaps

Debt Instrument [Line Items]

Fixed rate

3.10%

3.10%

AmeriGas OLP

Debt Instrument [Line Items]

Maximum borrowing capacity

600,000,000

600,000,000

Capital contributions

$ 11,000,000

$ 20,000,000

$ 52,000,000

Mountaineer

Debt Instrument [Line Items]

Maximum borrowing capacity

150,000,000

100,000,000

Energy Services

Debt Instrument [Line Items]

Maximum borrowing capacity

260,000,000

260,000,000

AmeriGas OLP Credit Agreement | AmeriGas OLP

Debt Instrument [Line Items]

Number of equity cure | cure

1

Energy Services Receivables Facility | Energy Services | Receivables Facility | Subsequent Event

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 100,000,000

$ 200,000,000

Line of Credit | Mountaineer | Letter of Credit

Debt Instrument [Line Items]

Maximum borrowing capacity

20,000,000

Line of Credit | UGI Utilities Credit Agreement | Utilities | Revolver

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 425,000,000

Line of Credit | UGI Utilities Credit Agreement | Utilities | Revolver | Subsequent Event

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 375,000,000

Increase to limit

$ 125,000,000

Additional automatic extension

5 years

Line of Credit | UGI Utilities Credit Agreement | Utilities | Revolver | SOFR

Debt Instrument [Line Items]

Basis spread on variable rate

0.10%

Line of Credit | UGI Utilities Credit Agreement | Utilities | Bridge Loan | Subsequent Event

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 38,000,000

Line of Credit | UGI Utilities Credit Agreement | Utilities | Letter of Credit | Subsequent Event

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 50,000,000

Line of Credit | AmeriGas OLP Credit Agreement | AmeriGas OLP | Revolver | Subsequent Event

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 400,000,000

$ 600,000,000

Line of Credit | AmeriGas OLP Credit Agreement | AmeriGas OLP | Letter of Credit

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 100,000,000

$ 100,000,000

Line of Credit | UGI International Credit Facilities Agreement

Debt Instrument [Line Items]

Principal amount

$ 250,000,000

Debt term

5 years

Line of Credit | UGI International Credit Facilities Agreement | Unsecured Debt

Debt Instrument [Line Items]

Principal amount | €

€ 300,000,000

Debt term

5 years

Line of Credit | UGI International Credit Facilities Agreement | Revolver

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 300,000,000

€ 500,000,000

Debt term

5 years

Line of Credit | UGI International Credit Facilities Agreement | Revolver | Euro Interbank Offered Rate | Maximum

Debt Instrument [Line Items]

Basis spread on variable rate

3.35%

Line of Credit | UGI International Credit Facilities Agreement | Revolver | Euro Interbank Offered Rate | Minimum

Debt Instrument [Line Items]

Basis spread on variable rate

1.70%

Line of Credit | UGI International Credit Facilities Agreement | Revolver | SOFR

Debt Instrument [Line Items]

Basis spread on variable rate

0.125%

0.10%

Line of Credit | UGI International Credit Facilities Agreement | Bridge Loan

Debt Instrument [Line Items]

Maximum borrowing capacity | €

€ 100,000,000

Line of Credit | UGI International Credit Facilities Agreement | Bridge Loan | Daily Non-cumulative Compounded Reference Rate | Maximum

Debt Instrument [Line Items]

Basis spread on variable rate

3.35%

Line of Credit | UGI International Credit Facilities Agreement | Bridge Loan | Daily Non-cumulative Compounded Reference Rate | Minimum

Debt Instrument [Line Items]

Basis spread on variable rate

1.35%

Line of Credit | UGI Energy Services Credit Agreement | SOFR

Debt Instrument [Line Items]

Basis spread on variable rate

0.10%

Line of Credit | Energy Services Term Loan Credit Agreement | Revolver

Debt Instrument [Line Items]

Increase to limit

$ 125,000,000

Principal amount

800,000,000

Fixed rate

4.53%

4.53%

Quarterly Installments

$ 2,000,000

Settlement of Energy Services interest rate swap, net of amortization

$ 32,000,000

Line of Credit | Energy Services Term Loan Credit Agreement | Revolver | SOFR

Debt Instrument [Line Items]

Basis spread on variable rate

3.25%

Line of Credit | Energy Services Term Loan Credit Agreement | Revolver | SOFR adjustment rate

Debt Instrument [Line Items]

Basis spread on variable rate

0.10%

Line of Credit | Energy Services Term Loan Credit Agreement | Revolver | SOFR base rate

Debt Instrument [Line Items]

Basis spread on variable rate

2.25%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolver

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 150,000,000

Option to increase capacity

$ 250,000,000

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolver | SOFR

Debt Instrument [Line Items]

Basis spread on variable rate

1%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolver | SOFR | Maximum

Debt Instrument [Line Items]

Basis spread on variable rate

2.25%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolver | SOFR | Minimum

Debt Instrument [Line Items]

Basis spread on variable rate

1%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolver | Federal Funds Rate

Debt Instrument [Line Items]

Basis spread on variable rate

0.50%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolver | Base Rate Margin | Maximum

Debt Instrument [Line Items]

Basis spread on variable rate

1.25%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolver | Base Rate Margin | Minimum

Debt Instrument [Line Items]

Basis spread on variable rate

0%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolver | One-Month Interest Period (SOFR)

Debt Instrument [Line Items]

Basis spread on variable rate

0.10%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolver | Three-Month Interest Period (SOFR)

Debt Instrument [Line Items]

Basis spread on variable rate

0.15%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolver | Six-Month Interest Period (SOFR)

Debt Instrument [Line Items]

Basis spread on variable rate

0.25%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Letter of Credit

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 20,000,000

UGI Utilities Senior Notes: | Senior Notes Due 2028 | AmeriGas Partners And AmeriGas Finance Corp.

Debt Instrument [Line Items]

Principal amount

$ 500,000,000

$ 500,000,000

Interest rate

9.375%

9.375%

UGI Utilities Senior Notes: | Senior Notes Due 2028 | AmeriGas Partners And AmeriGas Finance Corp. | Maximum

Debt Instrument [Line Items]

Call premium

4.688%

UGI Utilities Senior Notes: | Senior Notes Due 2028 | AmeriGas Partners And AmeriGas Finance Corp. | Minimum

Debt Instrument [Line Items]

Call premium

0%

UGI Utilities Senior Notes: | AmeriGas Partners Senior Notes | AmeriGas Partners And AmeriGas Finance Corp.

Debt Instrument [Line Items]

Principal amount

$ 675,000,000

$ 675,000,000

Interest rate

5.625%

5.625%

Repayment of debt

$ 150,000,000

Loss on extinguishments of debt

$ 9,000,000

Debt - Schedule of Credit Facil

Debt - Schedule of Credit Facilities and Short-term Borrowings (Details)	Sep. 30, 2023 USD ($)	Sep. 30, 2023 EUR (€)	Sep. 30, 2022 USD ($)	Sep. 30, 2022 EUR (€)
AmeriGas OLP
Short-term Debt [Line Items]
Total Capacity	$ 600,000,000		$ 600,000,000
Borrowings Outstanding	0		131,000,000
Letters of Credit and Guarantees Outstanding	2,000,000		2,000,000
Available Borrowing Capacity	$ 598,000,000		$ 467,000,000
Weighted Average Interest Rate - End of Year			7.27%	7.27%
UGI International LLC
Short-term Debt [Line Items]
Total Capacity | €		€ 500,000,000		€ 300,000,000
Borrowings Outstanding | €		202,000,000		0
Letters of Credit and Guarantees Outstanding | €		0		0
Available Borrowing Capacity | €		€ 298,000,000		€ 300,000,000
Weighted Average Interest Rate - End of Year	5.17%	5.17%
Energy Services
Short-term Debt [Line Items]
Total Capacity	$ 260,000,000		$ 260,000,000
Borrowings Outstanding	57,000,000		0
Letters of Credit and Guarantees Outstanding	0		0
Available Borrowing Capacity	$ 203,000,000		260,000,000
Weighted Average Interest Rate - End of Year	7.67%	7.67%
UGI Utilities
Short-term Debt [Line Items]
Total Capacity	$ 425,000,000		350,000,000
Borrowings Outstanding	248,000,000		151,000,000
Letters of Credit and Guarantees Outstanding	0		0
Available Borrowing Capacity	$ 177,000,000		$ 199,000,000
Weighted Average Interest Rate - End of Year	6.30%	6.30%	4.37%	4.37%
Mountaineer
Short-term Debt [Line Items]
Total Capacity	$ 150,000,000		$ 100,000,000
Borrowings Outstanding	84,000,000		85,000,000
Letters of Credit and Guarantees Outstanding	0		0
Available Borrowing Capacity	$ 66,000,000		$ 15,000,000
Weighted Average Interest Rate - End of Year	6.68%	6.68%	3.82%	3.82%
UGI Corporation
Short-term Debt [Line Items]
Total Capacity	$ 300,000,000		$ 300,000,000
Borrowings Outstanding	283,000,000		252,000,000
Letters of Credit and Guarantees Outstanding	0		0
Available Borrowing Capacity	$ 17,000,000		$ 48,000,000
Weighted Average Interest Rate - End of Year	7.80%	7.80%	5.62%	5.62%

Debt - Schedule of Short-term D

Debt - Schedule of Short-term Debt (Footnotes) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
AmeriGas OLP
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 600,000,000	$ 600,000,000
Energy Services
Short-term Debt [Line Items]
Maximum borrowing capacity	260,000,000	260,000,000
UGI Utilities
Short-term Debt [Line Items]
Maximum borrowing capacity	425,000,000	350,000,000
Mountaineer
Short-term Debt [Line Items]
Maximum borrowing capacity	150,000,000	100,000,000
UGI Corporation
Short-term Debt [Line Items]
Maximum borrowing capacity	300,000,000	300,000,000
Line of Credit | AmeriGas OLP | Letter of Credit | AmeriGas OLP Credit Agreement
Short-term Debt [Line Items]
Maximum borrowing capacity	100,000,000	$ 100,000,000
Line of Credit | Energy Services | Letter of Credit | Energy Services Credit Agreement
Short-term Debt [Line Items]
Maximum borrowing capacity	50,000,000
Line of Credit | UGI Utilities | Letter of Credit | UGI Utilities, Inc. Credit Agreement
Short-term Debt [Line Items]
Maximum borrowing capacity	100,000,000
Line of Credit | Mountaineer | Letter of Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	20,000,000
Line of Credit | UGI Corporation | 2021 UGI Corporation Senior Credit Facility
Short-term Debt [Line Items]
Repayment of debt	87,000,000
Line of Credit | UGI Corporation | Letter of Credit | 2021 UGI Corporation Senior Credit Facility
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 10,000,000

Debt - Schedule of Receivables

Debt - Schedule of Receivables Facility (Details) - Energy Services - Receivables Facility - Energy Services Receivables Facility - USD ($)	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Short-term Debt [Line Items]
Trade receivables transferred to ESFC during the year	$ 1,946,000,000	$ 2,221,000,000	$ 1,353,000,000
ESFC trade receivables sold to the bank during the year	535,000,000	152,000,000	308,000,000
ESFC trade receivables - end of year	62,000,000	101,000,000	$ 61,000,000
Outstanding balance of trade receivables sold	$ 46,000,000	$ 0

Debt - Schedule of Long-term De

Debt - Schedule of Long-term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Debt Instrument [Line Items]
Total long-term debt	$ 6,600	$ 6,632
Less: current maturities	(57)	(149)
Total long-term debt due after one year	6,543	6,483
AmeriGas Propane
Debt Instrument [Line Items]
Unamortized debt issuance costs	(15)	(12)
Total long-term debt	$ 2,385	2,563
AmeriGas Propane | UGI Utilities Senior Notes: | 5.50% due May 2025
Debt Instrument [Line Items]
Interest rate	5.50%
Long-term debt, gross	$ 700	700
AmeriGas Propane | UGI Utilities Senior Notes: | 5.875% due August 2026
Debt Instrument [Line Items]
Interest rate	5.875%
Long-term debt, gross	$ 675	675
AmeriGas Propane | UGI Utilities Senior Notes: | 5.625% due May 2024
Debt Instrument [Line Items]
Interest rate	5.625%
Long-term debt, gross	$ 0	675
AmeriGas Propane | UGI Utilities Senior Notes: | 5.75% due May 2027
Debt Instrument [Line Items]
Interest rate	5.75%
Long-term debt, gross	$ 525	525
AmeriGas Propane | UGI Utilities Senior Notes: | 9.375% due May 2028
Debt Instrument [Line Items]
Interest rate	9.375%
Long-term debt, gross	$ 500	0
UGI International
Debt Instrument [Line Items]
Unamortized debt issuance costs	(8)	(6)
Total long-term debt	$ 739	682
UGI International | UGI Utilities Senior Notes: | 2.50% Senior Notes due December 2029
Debt Instrument [Line Items]
Interest rate	2.50%
Long-term debt, gross	$ 424	392
UGI International | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	6	2
UGI International | Term Loan Due March 2028 | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	317	0
UGI International | Term Loan Due October 2023 | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	0	294
Midstream & Marketing
Debt Instrument [Line Items]
Unamortized debt issuance costs	(15)	(7)
Total long-term debt	820	710
Midstream & Marketing | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	41	40
Midstream & Marketing | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	794	677
Utilities
Debt Instrument [Line Items]
Unamortized debt issuance costs	(6)	(6)
Total long-term debt	1,649	1,656
Utilities | Mountaineer senior notes
Debt Instrument [Line Items]
Long-term debt, gross	$ 199	201
Utilities | UGI Utilities Senior Notes: | 4.12% due September 2046
Debt Instrument [Line Items]
Interest rate	4.12%
Long-term debt, gross	$ 200	200
Utilities | UGI Utilities Senior Notes: | 4.98% due March 2044
Debt Instrument [Line Items]
Interest rate	4.98%
Long-term debt, gross	$ 175	175
Utilities | UGI Utilities Senior Notes: | 3.12% due April 2050
Debt Instrument [Line Items]
Interest rate	3.12%
Long-term debt, gross	$ 150	150
Utilities | UGI Utilities Senior Notes: | 4.55% due February 2049
Debt Instrument [Line Items]
Interest rate	4.55%
Long-term debt, gross	$ 150	150
Utilities | UGI Utilities Senior Notes: | 4.12% due October 2046
Debt Instrument [Line Items]
Interest rate	4.12%
Long-term debt, gross	$ 100	100
Utilities | UGI Utilities Senior Notes: | 6.21% due September 2036
Debt Instrument [Line Items]
Interest rate	6.21%
Long-term debt, gross	$ 100	100
Utilities | UGI Utilities Senior Notes: | 2.95% due June 2026
Debt Instrument [Line Items]
Interest rate	2.95%
Long-term debt, gross	$ 100	100
Utilities | UGI Utilities Senior Notes: | 1.59% due June 2026
Debt Instrument [Line Items]
Interest rate	1.59%
Long-term debt, gross	$ 100	100
Utilities | UGI Utilities Senior Notes: | 1.64% due September 2026
Debt Instrument [Line Items]
Interest rate	1.64%
Long-term debt, gross	$ 75	75
Utilities | UGI Utilities Senior Notes: | 4.75% due July 2032
Debt Instrument [Line Items]
Interest rate	4.75%
Long-term debt, gross	$ 90	90
Utilities | UGI Utilities Senior Notes: | 4.99% due September 2052
Debt Instrument [Line Items]
Interest rate	4.99%
Long-term debt, gross	$ 85	85
Utilities | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	2	1
Utilities | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	$ 89	95
Utilities | UGI Utilities Medium-Term Notes: | 6.13% due October 2034
Debt Instrument [Line Items]
Interest rate	6.13%
Long-term debt, gross	$ 20	20
Utilities | UGI Utilities Medium-Term Notes: | 6.50% due August 2033
Debt Instrument [Line Items]
Interest rate	6.50%
Long-term debt, gross	$ 20	20
UGI Corporation
Debt Instrument [Line Items]
Unamortized debt issuance costs	(3)	(2)
Total long-term debt	1,007	1,015
UGI Corporation | Term Loan | 3-year Term loan
Debt Instrument [Line Items]
Long-term debt, gross	300	300
UGI Corporation | Term Loan | 5-year Term Loan
Debt Instrument [Line Items]
Long-term debt, gross	212	250
UGI Corporation | Term Loan | 7-Year Term Loan
Debt Instrument [Line Items]
Long-term debt, gross	215	215
UGI Corporation | Line of Credit
Debt Instrument [Line Items]
Long-term debt, gross	283	252
Other
Debt Instrument [Line Items]
Total long-term debt	$ 0	$ 6

Debt - Schedule of Long-term _2

Debt - Schedule of Long-term Debt (Footnotes) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Debt Instrument [Line Items]
Long-term debt	$ 6,600,000,000	$ 6,632,000,000
Senior Secured Notes | Mountaineer senior notes
Debt Instrument [Line Items]
Long-term debt		180,000,000
Unamortized premium	$ 19,000,000	21,000,000
Senior Secured Notes | Mountaineer senior notes | Minimum
Debt Instrument [Line Items]
Interest rate	3.50%
Senior Secured Notes | Mountaineer senior notes | Maximum
Debt Instrument [Line Items]
Interest rate	4.49%
UGI International
Debt Instrument [Line Items]
Fixed rate	3.10%
Long-term debt	$ 739,000,000	$ 682,000,000
UGI International | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)		1.89%
UGI International | UGI Utilities Senior Notes: | 2.50% Senior Notes due December 2029
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	4.95%
Interest rate	2.50%
Midstream & Marketing
Debt Instrument [Line Items]
Fixed rate	4.53%
Long-term debt	$ 820,000,000	$ 710,000,000
Midstream & Marketing | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	7.82%	5.13%
Quarterly Installments	$ 2,000,000
Utilities
Debt Instrument [Line Items]
Long-term debt	$ 1,649,000,000	$ 1,656,000,000
Utilities | Variable-rate term loan
Debt Instrument [Line Items]
Fixed rate	2.82%
Utilities | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	3.92%	3.92%
Quarterly Installments	$ 2,000,000
UGI Corporation
Debt Instrument [Line Items]
Long-term debt	$ 1,007,000,000	$ 1,015,000,000
UGI Corporation | 3-year Term loan
Debt Instrument [Line Items]
Fixed rate	0.70%
UGI Corporation | 7-Year Term Loan
Debt Instrument [Line Items]
Fixed rate	0.70%
UGI Corporation | Term Loan | 3-year Term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	2.77%	2.67%
UGI Corporation | Term Loan | 5-year Term Loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	7.79%	4.15%
Quarterly Installments	$ 9,000,000
UGI Corporation | Term Loan | 7-Year Term Loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	4.73%	3.53%
UGI Corporation | Line of Credit
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	7.80%	5.61%

Debt - Schedule of Principal Re

Debt - Schedule of Principal Repayments of Long-term Debt (Details) $ in Millions	Sep. 30, 2023 USD ($)
Debt Instrument [Line Items]
2024	$ 57
2025	1,687
2026	964
2027	603
2028	865
AmeriGas Propane
Debt Instrument [Line Items]
2024	0
2025	700
2026	675
2027	525
2028	500
UGI International
Debt Instrument [Line Items]
2024	1
2025	0
2026	0
2027	0
2028	317
Midstream & Marketing
Debt Instrument [Line Items]
2024	12
2025	8
2026	8
2027	8
2028	8
Utilities
Debt Instrument [Line Items]
2024	6
2025	6
2026	281
2027	70
2028	40
UGI Corporation
Debt Instrument [Line Items]
2024	38
2025	973
2026	0
2027	0
2028	$ 0

Income Taxes - (Loss) Income Be

Income Taxes - (Loss) Income Before Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Income Tax Disclosure [Abstract]
Domestic	$ (346)	$ 362	$ 647
Foreign	(1,491)	1,025	1,342
(Loss) income before income taxes	$ (1,837)	$ 1,387	$ 1,989

Income Taxes - Provisions for I

Income Taxes - Provisions for Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Current expense (benefit):
Federal	$ (1)	$ 24	$ (48)
State	37	18	7
Foreign	49	50	85
Total current expense	85	92	44
Deferred expense (benefit):
Federal	34	45	168
State	(21)	(17)	48
Foreign	(433)	193	262
Total deferred (benefit) expense	(420)	221	478
Total income tax (benefit) expense	$ (335)	$ 313	$ 522

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($)	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Income Tax Examination [Line Items]
Foreign tax credits	$ 25,000,000	$ 5,000,000	$ 0
Foreign tax credit carryforwards	64,000,000	76,000,000
Net operating loss carryback			15,000,000
Income taxes receivable	36,000,000	128,000,000
GILTI taxes	13,000,000	3,000,000	8,000,000
Deferred tax assets relating to operating loss carryforwards	75,000,000	48,000,000
Increase (decrease) in valuation allowance		3,000,000
Unrecognized tax benefits if recognized would impact the reported effective tax rate	26,000,000	5,000,000	3,000,000
Notional interest deduction carryover
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance	(5,000,000)	17,000,000
State Tax Rate Changes
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance	(3,000,000)	4,000,000
Future FTC's realizable
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance	(16,000,000)	6,000,000
Foreign Net Operating Loss Carry Forwards
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance	11,000,000	4,000,000
Capital Losses
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance	(22,000,000)
Disallowed Interest
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance	19,000,000
AmeriGas Propane
Income Tax Examination [Line Items]
Operating loss carryforwards	9,000,000
Other Subsidiaries
Income Tax Examination [Line Items]
Deferred tax assets relating to operating loss carryforwards	75,000,000
Fiscal 2021
Income Tax Examination [Line Items]
Income taxes receivable	37,000,000	37,000,000
Effects of tax rate changes – State, net of federal benefit
Income Tax Examination [Line Items]
Benefit from legislation	4,000,000	20,000,000
Decrease in income tax expense due to state tax flow through of accelerated depreciation	11,000,000	$ 10,000,000	9,000,000
Operating loss carryforwards	1,071,000,000
Foreign | Flaga
Income Tax Examination [Line Items]
Operating loss carryforwards	6,000,000
Foreign | UGI France
Income Tax Examination [Line Items]
Operating loss carryforwards	23,000,000
Foreign | Italy
Income Tax Examination [Line Items]
Foreign tax credit carryforwards			$ 23,000,000
Foreign | Tax and Customs Administration, Netherlands
Income Tax Examination [Line Items]
Operating loss carryforwards	44,000,000
Foreign | Administration of the Treasury, Belgium
Income Tax Examination [Line Items]
Operating loss carryforwards	10,000,000
Foreign | Her Majesty's Revenue and Customs (HMRC)
Income Tax Examination [Line Items]
Operating loss carryforwards	$ 5,000,000

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of U.S. Federal Statutory Tax Rate to Effective Tax Rate (Details)	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Operating Loss Carryforwards [Line Items]
U.S. federal statutory tax rate	21%	21%	21%
Difference in tax rate due to:
Goodwill impairment not deductible for tax	(7.30%)	0%	0%
Effects of foreign operations	3.90%	4.40%	4.60%
State income taxes, net of federal benefit	(1.10%)	1.50%	1.90%
Valuation allowance adjustments	1.10%	(0.50%)	1%
Other, net	0.40%	(0.10%)	(0.20%)
Effective tax rate	18.20%	22.60%	26.20%
Effects of U.S. tax legislation
Difference in tax rate due to:
Effects of tax rate changes	0%	0%	(0.80%)
Effects of tax rate changes - International
Difference in tax rate due to:
Effects of tax rate changes	0%	(2.30%)	(1.30%)
Effects of tax rate changes – State, net of federal benefit
Difference in tax rate due to:
Effects of tax rate changes	0.20%	(1.40%)	0%

Income Taxes - Deferred Tax Lia

Income Taxes - Deferred Tax Liabilities (Assets) (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Excess book basis over tax basis of property, plant and equipment	$ 966	$ 867
Utility regulatory assets	84	106
Intangible assets and goodwill	81	75
Derivative instrument assets	19	514
Other	37	33
Gross deferred tax liabilities	1,187	1,595
Investment in AmeriGas Partners	(28)	(79)
Pension plan liabilities	(14)	(21)
Employee-related benefits	(37)	(38)
Operating loss carryforwards	(75)	(48)
Foreign tax credit carryforwards	(64)	(76)
Utility regulatory liabilities	(83)	(85)
Utility environmental liabilities	(15)	(15)
Interest expense	(83)	(51)
Other	(58)	(74)
Gross deferred tax assets	(457)	(487)
Deferred tax assets valuation allowance	141	141
Net deferred tax liabilities	$ 871	$ 1,249

Income Taxes - Reconciliation_2

Income Taxes - Reconciliation of Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Reconciliation of Unrecognized Tax Benefits
Unrecognized tax benefits — beginning of year	$ 5	$ 3	$ 4
Additions for tax positions of the current year	3	2	0
Increases for tax positions taken in prior years	0	0	(2)
Increases for tax positions taken in prior years	19	1	1
Settlements with tax authorities/statute lapses	(1)	(1)	0
Unrecognized tax benefits — end of year	$ 26	$ 5	$ 3

Employee Retirement Plans - Nar

Employee Retirement Plans - Narrative (Details) - USD ($)	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Defined Benefit Plan Disclosure [Line Items]
ABO	$ 21,000,000	$ 22,000,000
Fair value of plan assets	18,000,000	16,000,000
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Contribution made to Pension Plan	19,000,000	15,000,000
Projected benefit obligations of unfunded and non qualified supplemental executive retirement plans	623,000,000	633,000,000	$ 870,000,000
Costs associated with the plans	(4,000,000)	(1,000,000)	8,000,000
Payments for defined benefit retirement plan	36,000,000	34,000,000
Supplemental Employee Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligations of unfunded and non qualified supplemental executive retirement plans	34,000,000	44,000,000
Costs associated with the plans	0	0
Payments for defined benefit retirement plan	0	0	12,000,000
Fair value of pension and other postretirement benefit contributions	26,000,000	31,000,000
U.S. | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Contribution made to Pension Plan	18,000,000	$ 14,000,000	$ 13,000,000
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year	$ 22,000,000

Employee Retirement Plans - Cha

Employee Retirement Plans - Change in Pension Benefits and Other Postretirement Benefits Obligations (Details) - Pension Benefits - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Change in benefit obligations:
Benefit obligations — beginning of year	$ 633	$ 870
Service cost	9	16	$ 12
Interest cost	35	26	22
Actuarial gain	(20)	(240)
Plan amendments	0	1
Foreign currency	2	(6)
Benefits paid	(36)	(34)
Benefit obligations — end of year	623	633	870
Change in plan assets:
Fair value of plan assets — beginning of year	541	736
Actual gain (loss) on plan assets	31	(173)
Foreign currency	1	(3)
Employer contributions	19	15
Benefits paid	(36)	(34)
Fair value of plan assets — end of year	556	541	$ 736
Funded status of the plans — end of year	(67)	(92)
Amounts recorded in UGI Corporation stockholders’ equity (pre-tax):
Prior service cost	3	3
Net actuarial gain	(17)	(17)
Total	(14)	(14)
Amounts recorded in regulatory assets and liabilities (pre-tax):
Net actuarial loss	110	114
Total	110	114
ABO for the pension plans	$ 558	$ 570

Employee Retirement Plans - Act

Employee Retirement Plans - Actuarial Assumptions for Domestic Plans (Details) - Pension Benefits	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Weighted-average assumptions:
Discount rate – benefit obligations	6.09%	5.70%	3.13%
Discount rate – benefit cost	5.70%	3.13%	2.90%
Expected return on plan assets	7.50%	7.10%	7.10%
Rate of increase in salary levels	3.25%	3.25%	3.25%

Employee Retirement Plans - Net

Employee Retirement Plans - Net periodic pension (income) cost (Details) - Pension Benefits - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 9	$ 16	$ 12
Interest cost	35	26	22
Expected return on assets	(45)	(50)	(40)
Amortization of:
Actuarial (gain) loss	(3)	7	14
Net benefit (income) cost	(4)	(1)	$ 8
Contribution made to Pension Plan	$ 19	$ 15

Employee Retirement Plans - Exp

Employee Retirement Plans - Expected Payments for Pension Benefits and Other Postretirement Welfare Benefits (Details) - Pension Benefits $ in Millions	Sep. 30, 2023 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Fiscal 2024	$ 39
Fiscal 2025	39
Fiscal 2026	41
Fiscal 2027	43
Fiscal 2028	44
Fiscal 2029 - 2033	$ 238

Employee Retirement Plans - Pen

Employee Retirement Plans - Pension Plans Assets (Details) - Pension Benefits - U.S.	Sep. 30, 2023	Sep. 30, 2022
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	100%	100%
Target Asset Allocation	100%	100%
Target allocation range	5%
Equity investments
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	61.40%	61.20%
Target Asset Allocation	61.60%	58.70%
U.S. equities
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	25.80%	26.50%
Target Asset Allocation	27.60%	24.70%
Non-U.S. equities
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	21.70%	20.90%
Target Asset Allocation	23.30%	20.90%
Global equities
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	13.90%	13.80%
Target Asset Allocation	10.70%	13.10%
Fixed income funds & cash equivalents
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	35.50%	35.50%
Target Asset Allocation	35%	35%
Alternative investments
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	3.10%	3.30%
Target Asset Allocation	3.40%	6.30%

Employee Retirement Plans - Fai

Employee Retirement Plans - Fair Value of U.S. Pension Plan and VEBA Trust Assets (Details) - Pension Benefits - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 556	$ 541	$ 736
U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	539	525
U.S. | U.S. equities
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	19	26
U.S. | UGI Corporation Common Stock
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	19	26
U.S. | Total common collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	503	482
U.S. | U.S. equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	120	113
U.S. | Non-U.S. equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	117	110
U.S. | Global equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	75	72
U.S. | Bond index mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	183	177
U.S. | Cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	10
U.S. | Alternative investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 17	$ 17

Employee Retirement Plans - Def

Employee Retirement Plans - Defined Contribution Plans (Details) - Other Pension, Postretirement and Supplemental Plans - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Defined Contribution Plan Disclosure [Line Items]
Costs of benefits under savings plans	$ 22	$ 21	$ 21
Total fair values of grantor trust investment assets	$ 9	$ 7

Utility Regulatory Assets and_3

Utility Regulatory Assets and Liabilities and Regulatory Matters - Regulatory Assets and Liabilities Associated with Utilities (Details) - Utilities - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Regulatory Assets [Line Items]
Regulatory assets	$ 347	$ 340
Regulatory Liabilities [Line Items]
Regulatory liabilities	366	335
Postretirement benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities	12	11
Deferred fuel and power refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities	55	3
State income tax benefits — distribution system repairs
Regulatory Liabilities [Line Items]
Regulatory liabilities	43	38
Excess federal deferred income taxes
Regulatory Liabilities [Line Items]
Regulatory liabilities	254	279
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities	2	4
Income taxes recoverable
Regulatory Assets [Line Items]
Regulatory assets	94	83
Underfunded pension plans
Regulatory Assets [Line Items]
Regulatory assets	111	114
Environmental costs
Regulatory Assets [Line Items]
Regulatory assets	28	37
Deferred fuel and power costs
Regulatory Assets [Line Items]
Regulatory assets	27	32
Removal costs, net
Regulatory Assets [Line Items]
Regulatory assets	23	22
Other
Regulatory Assets [Line Items]
Regulatory assets	$ 64	$ 52

Utility Regulatory Assets and_4

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

12 Months Ended

Oct. 06, 2023

Oct. 01, 2023

Sep. 21, 2023

Jul. 31, 2023

Mar. 06, 2023

Jan. 27, 2023

Nov. 16, 2022

Nov. 01, 2022

Oct. 29, 2022

Sep. 15, 2022

Jul. 29, 2022

Jan. 28, 2022

Nov. 09, 2021

Feb. 08, 2021

Sep. 30, 2023

Sep. 30, 2022

Sep. 30, 2021

Dec. 01, 2022

Oct. 19, 2016

Regulatory Assets [Line Items]

Regulatory asset, amortization period

20 years

Unrealized gain (loss) on derivatives

$ (1,682)

$ 648

$ 1,398

Public Service Commission of West Virginia

Regulatory Assets [Line Items]

Under-recovery of gas cost

$ 12

Public Service Commission of West Virginia | Mountaineer | 2023 Infrastructure Replacement and Expansion Plan

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ 10

Public Service Commission of West Virginia | Mountaineer | 2023 Infrastructure Replacement and Expansion Plan, Capital Improvement 2023

Regulatory Assets [Line Items]

Requested rate increase (decrease)

131

Public Service Commission of West Virginia | Mountaineer | 2023 Infrastructure Replacement and Expansion Plan, Capital Improvements 2024

Regulatory Assets [Line Items]

Requested rate increase (decrease)

67

Public Service Commission of West Virginia | Mountaineer | Net Revenue Increase

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ 20

Public Service Commission of West Virginia | Mountaineer | Net Revenue Increase | Subsequent Event

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ 14

Public Service Commission of West Virginia | Mountaineer | Base Rate Case, Base Rate

Regulatory Assets [Line Items]

Requested rate increase (decrease)

38

Public Service Commission of West Virginia | Mountaineer | Base Rate Case, Infrastructure Rider

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ (18)

Public Service Commission of West Virginia | Mountaineer | 2022 IREP For 2023 - 2027

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ 354

Public Service Commission of West Virginia | Mountaineer | 2022 IREP For 2023

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ 64

Public Service Commission of West Virginia | Mountaineer | 2023 IREP Revenue

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ 22

Public Service Commission of West Virginia | Mountaineer | 2021 IREP Recovery

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ 1

Public Service Commission of West Virginia | Mountaineer | 2023 Infrastructure Replacement and Expansion Plan, Capital Investments

Regulatory Assets [Line Items]

Requested rate increase (decrease)

383

Public Service Commission of West Virginia | Mountaineer | 2023 Infrastructure Replacement and Expansion Plan, Requested Recovery

Regulatory Assets [Line Items]

Requested rate increase (decrease)

6

Public Service Commission of West Virginia | Mountaineer | 2023 Infrastructure Replacement and Expansion Plan, Expected

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ (12)

Pennsylvania Public Utility Commission | Utilities

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ 11

Approved rate increase, amount

$ 9

Pennsylvania Public Utility Commission | Regulated natural gas utilities

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ 83

Pennsylvania Public Utility Commission | Regulated natural gas utilities | Joint Petition for Approval of Settlement

Regulatory Assets [Line Items]

Approved rate increase, amount

$ 49

Public utilities, rate period

5 years

Approved rate increase

3%

Property, plant and equipment, net threshold

$ 3,368

Pennsylvania Public Utility Commission | Regulated natural gas utilities | Joint Petition for Approval of Settlement, Phase I

Regulatory Assets [Line Items]

Approved rate increase, amount

$ 38

Pennsylvania Public Utility Commission | Regulated natural gas utilities | Joint Petition for Approval of Settlement, Phase II | Forecast

Regulatory Assets [Line Items]

Approved rate increase, amount

$ 11

Pennsylvania Public Utility Commission | Regulated natural gas utilities | Weather Normalization Adjustment Rider

Regulatory Assets [Line Items]

Public utilities, rate period

5 years

Approved rate increase

3%

Pennsylvania Public Utility Commission | UGI Gas

Regulatory Assets [Line Items]

Requested rate increase (decrease)

$ 9

Approved rate increase, amount

$ 6

Postretirement benefits

Regulatory Assets [Line Items]

Regulatory liability, amortization period

10 years

Regulated natural gas utilities

Regulatory Assets [Line Items]

Unrealized gain (loss) on derivatives

$ (2)

$ 5

Minimum

Regulatory Assets [Line Items]

Average remaining depreciable lives of the associated property

1 year

Maximum

Regulatory Assets [Line Items]

Average remaining depreciable lives of the associated property

65 years

Maximum | Removal Costs, Net

Regulatory Assets [Line Items]

Regulatory asset, amortization period

5 years

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Public Utilities, Inventory
Total inventories	$ 433	$ 665
Non-utility LPG and natural gas
Public Utilities, Inventory
Total inventories	212	335
Gas Utility natural gas
Public Utilities, Inventory
Total inventories	55	166
Energy certificates
Public Utilities, Inventory
Total inventories	64	70
Materials, supplies and other
Public Utilities, Inventory
Total inventories	$ 102	$ 94

Property, Plant and Equipment -

Property, Plant and Equipment - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Property, Plant and Equipment
Utility	$ 6,082	$ 5,550
Non-utility	7,046	6,656
Total property, plant and equipment	13,128	12,206
Distribution
Property, Plant and Equipment
Utility	5,204	4,746
Transmission
Property, Plant and Equipment
Utility	123	123
General and other
Property, Plant and Equipment
Utility	660	557
Work in process
Property, Plant and Equipment
Utility	95	124
Non-utility	156	53
Land
Property, Plant and Equipment
Non-utility	174	179
Buildings and improvements
Property, Plant and Equipment
Non-utility	$ 418	426
Buildings and improvements | Minimum
Property, Plant and Equipment
Estimated Useful Life	10 years
Buildings and improvements | Maximum
Property, Plant and Equipment
Estimated Useful Life	40 years
Transportation equipment
Property, Plant and Equipment
Non-utility	$ 238	234
Transportation equipment | Minimum
Property, Plant and Equipment
Estimated Useful Life	3 years
Transportation equipment | Maximum
Property, Plant and Equipment
Estimated Useful Life	10 years
Equipment, primarily cylinders and tanks
Property, Plant and Equipment
Non-utility	$ 3,903	3,645
Equipment, primarily cylinders and tanks | Minimum
Property, Plant and Equipment
Estimated Useful Life	5 years
Equipment, primarily cylinders and tanks | Maximum
Property, Plant and Equipment
Estimated Useful Life	30 years
Electric generation
Property, Plant and Equipment
Non-utility	$ 190	216
Electric generation | Minimum
Property, Plant and Equipment
Estimated Useful Life	25 years
Electric generation | Maximum
Property, Plant and Equipment
Estimated Useful Life	40 years
Pipeline and related assets
Property, Plant and Equipment
Non-utility	$ 1,577	1,523
Pipeline and related assets | Minimum
Property, Plant and Equipment
Estimated Useful Life	25 years
Pipeline and related assets | Maximum
Property, Plant and Equipment
Estimated Useful Life	40 years
Other
Property, Plant and Equipment
Non-utility	$ 390	$ 380
Other | Minimum
Property, Plant and Equipment
Estimated Useful Life	1 year
Other | Maximum
Property, Plant and Equipment
Estimated Useful Life	12 years

Property, Plant and Equipment_2

Property, Plant and Equipment - Average Composite Depreciation Rates (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Property, Plant and Equipment
Depreciation	$ 476	$ 460	$ 437
Regulated natural gas utilities
Property, Plant and Equipment
Average composite depreciation rates (as a percentage)	2.40%	2.60%	2.60%
Electric Utility
Property, Plant and Equipment
Average composite depreciation rates (as a percentage)	2.30%	2.40%	2.30%

Goodwill and Intangible Asset_2

Goodwill and Intangible Assets - Changes in the Carrying Amount of Goodwill (Details) - USD ($)	3 Months Ended		12 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Goodwill
Balance at beginning of period			$ 3,612,000,000	$ 3,770,000,000
Purchase accounting adjustments				(5,000,000)
Foreign currency translation			68,000,000	(153,000,000)
Impairment of goodwill			(656,000,000)	0	$ 0
Acquisitions			3,000,000
Balance at end of period	$ 3,027,000,000		3,027,000,000	3,612,000,000	3,770,000,000
AmeriGas Propane
Goodwill
Balance at beginning of period			2,004,000,000	2,004,000,000
Purchase accounting adjustments				0
Foreign currency translation			0	0
Impairment of goodwill	(656,000,000)	$ (656,000,000)	(656,000,000)
Acquisitions			0
Balance at end of period	1,348,000,000		1,348,000,000	2,004,000,000	2,004,000,000
UGI International
Goodwill
Balance at beginning of period			840,000,000	993,000,000
Purchase accounting adjustments				0
Foreign currency translation			68,000,000	(153,000,000)
Impairment of goodwill			0
Acquisitions			3,000,000
Balance at end of period	911,000,000		911,000,000	840,000,000	993,000,000
Midstream & Marketing
Goodwill
Balance at beginning of period			336,000,000	336,000,000
Purchase accounting adjustments				0
Foreign currency translation			0	0
Impairment of goodwill			0
Acquisitions			0
Balance at end of period	336,000,000		336,000,000	336,000,000	336,000,000
Utilities
Goodwill
Balance at beginning of period			432,000,000	437,000,000
Purchase accounting adjustments				(5,000,000)
Foreign currency translation			0	0
Impairment of goodwill			0
Acquisitions			0
Balance at end of period	$ 432,000,000		$ 432,000,000	$ 432,000,000	$ 437,000,000

Goodwill and Intangible Asset_3

Goodwill and Intangible Assets - Narrative (Details) - USD ($)	3 Months Ended		12 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021	May 31, 2023
Goodwill [Line Items]
Impairment of goodwill			$ 656,000,000	$ 0	$ 0
Goodwill	$ 3,027,000,000		3,027,000,000	3,612,000,000	3,770,000,000
Impairment of customer relationship intangible					20,000,000
Amortization expense of intangible assets			56,000,000	61,000,000	76,000,000
Fiscal 2024	53,000,000		53,000,000
Fiscal 2025	51,000,000		51,000,000
Fiscal 2026	50,000,000		50,000,000
Fiscal 2027	27,000,000		27,000,000
Fiscal 2028	18,000,000		18,000,000
Customer relationships
Goodwill [Line Items]
Impairment of customer relationship intangible			10,000,000
AmeriGas Propane
Goodwill [Line Items]
Impairment of goodwill	656,000,000	$ 656,000,000	656,000,000
Goodwill	$ 1,348,000,000		$ 1,348,000,000	$ 2,004,000,000	$ 2,004,000,000
Senior Notes Due 2028 | UGI Utilities Senior Notes: | AmeriGas Partners And AmeriGas Finance Corp.
Goodwill [Line Items]
Principal amount						$ 500,000,000
Interest rate						9.375%

Goodwill and Intangible Asset_4

Goodwill and Intangible Assets - Components of Intangible Assets (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Goodwill and Intangible Assets Disclosure [Abstract]
Customer relationships	$ 977	$ 1,006
Trademarks and tradenames	4	3
Noncompete agreements and other	26	71
Accumulated amortization	(602)	(621)
Intangible assets, net (definite-lived)	405	459
Trademarks and tradenames (indefinite-lived)	38	41
Total intangible assets, net	$ 443	$ 500

Equity - Narrative (Details)

Equity - Narrative (Details) - USD ($)				12 Months Ended
	Jun. 01, 2024	Feb. 02, 2022	May 25, 2021	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021	May 17, 2021
Class of Stock [Line Items]
Repurchases of common stock						$ 0
Preferred Stock, shares authorized (in shares)				5,000,000	5,000,000
UGI Series Preference Stock outstanding (in shares)				0
Shares issued on conversion settlement (in shares)			1
Sale price (in dollars per share)							$ 43.81
Quarterly contract adjustment payments liability			$ 45,000,000
2024 Purchase Contracts
Class of Stock [Line Items]
Contract redemption obligation			$ 100,000,000
Maximum settlement rate			2.2826
Number of common stock deliverable percentage			85%
Quarterly contract adjustment payments percentage			7.125%
2024 Purchase Contracts | Forecast
Class of Stock [Line Items]
Contract redemption obligation	$ 100,000,000
Common Stock
Class of Stock [Line Items]
Maximum number of shares authorized for repurchase (up to) (in shares)		8,000,000
Stock repurchase program period		4 years
Repurchases of common stock (in shares)				600,000	900,000	0
Repurchases of common stock				$ 22,000,000	$ 38,000,000
Corporate Units | Preferred stock, without par value
Class of Stock [Line Items]
Units and shares sold (in shares)			2,200,000
Notional value			$ 220,000,000
Stated value (in dollars per share)			$ 100
Undivided beneficial ownership interest			10%
Liquidation preference (in dollars per share)			$ 1,000
Issuance of Preferred Stock, net of issuance costs			$ 213,000,000
Convertible Preferred Stock
Class of Stock [Line Items]
Liquidation preference (in dollars per share)			$ 1,000
Dividend rate			0.125%
Shares issued on conversion (in shares)			19.0215
Stock conversion price (in dollars per share)			$ 52.57
Convertible Preferred Stock | Preferred stock, without par value
Class of Stock [Line Items]
Units and shares sold (in shares)			220,000
Series B preferred stock
Class of Stock [Line Items]
Preferred Stock, shares authorized (in shares)				220,000	220,000	220,000

Equity - Common Stock Share Act

Equity - Common Stock Share Activity (Details) - shares	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance - shares Issued (in shares)	220,000	220,000	0
UGI Series Preference Stock outstanding (in shares)	0
Shares issued - beginning balance (in shares)	210,560,494
Ending balance - shares Issued (in shares)	220,000	220,000	220,000
Ending balance - shares outstanding (in shares)	0	0
Shares issued - ending balance (in shares)	210,906,052	210,560,494
Preferred Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
UGI Series Preference Stock outstanding (in shares)	220,000	220,000	0
Equity Unit offering (in shares)			220,000
Ending balance - shares Issued (in shares)	220,000
Ending balance - shares outstanding (in shares)	220,000	220,000	220,000
Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - beginning balance (in shares)	210,560,494	209,843,296	209,514,044
Beginning balance - shares Outstanding (in shares)	209,582,212	209,216,135	208,354,438
Employee and director plans - shares Issued/Treasury (in shares)	345,558	717,198	329,252
Employee and director plans - shares Outstanding (in shares)	512,871	1,516,350	883,567
Repurchases of common stock - Treasury (in shares)	(600,000)	(900,000)	0
Reacquired common stock – employee and director plans (in shares)		(250,273)	(21,870)
Shares issued - ending balance (in shares)	210,906,052	210,560,494	209,843,296
Ending balance - shares Outstanding (in shares)	209,495,083	209,582,212	209,216,135
Common Stock | Treasury stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance - treasury shares (in shares)	(978,282)	(627,161)	(1,159,606)
Employee and director plans - shares Issued/Treasury (in shares)	167,313	799,152	554,315
Repurchases of common stock - Treasury (in shares)	(600,000)	(900,000)
Reacquired common stock – employee and director plans (in shares)		(250,273)	(21,870)
Ending balance - treasury shares (in shares)	(1,410,969)	(978,282)	(627,161)

Equity-Based Compensation - Nar

Equity-Based Compensation - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions		1 Months Ended	12 Months Ended
	Jan. 29, 2021	Jan. 31, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Share-based Compensation Arrangement by Share-based Payment Award
Pre-tax equity-based compensation expense			$ 17	$ 15	$ 21
After tax equity-based compensation expense			$ 13	$ 11	$ 15
Weighted-average fair value of stock option granted under stock plans (in dollars per share)			$ 9.31	$ 8.47	$ 6.05
Options outstanding (in shares)			8,358,125
Options exercisable (in shares)			7,122,824
Weighted average exercise price (in dollars per share)			$ 42.79
UGI Stock Option Awards
Share-based Compensation Arrangement by Share-based Payment Award
Unrecognized compensation cost associated with unvested unit awards			$ 5
Weighted-average period of recognition for unvested unit awards			1 year 10 months 24 days
UGI Performance Units
Share-based Compensation Arrangement by Share-based Payment Award
Weighted-average fair value of stock option granted under stock plans (in dollars per share)			$ 44.62	$ 51.24	$ 41.41
UGI Performance Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted (as a percentage)			0%
UGI Performance Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted (as a percentage)			200%
UGI EPS Performance Unit
Share-based Compensation Arrangement by Share-based Payment Award
Unrecognized compensation cost associated with unvested unit awards			$ 25
Weighted-average period of recognition for unvested unit awards			2 years
UGI Unit awards outstanding (in shares)			1,502,253
Weighted average grant date fair value, outstanding (in dollars per share)			$ 43.09
UGI EPS Performance Unit | Minimum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted (as a percentage)		0%
UGI EPS Performance Unit | Maximum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted (as a percentage)		200%
Common Stock | 2021 IAP
Share-based Compensation Arrangement by Share-based Payment Award
Common Stock awards granted (up to) (in shares)	20,500,000
Expiration period	10 years
Number of common unit awards available for future grant (in shares)			16,014,039

Leases - Additional Information

Leases - Additional Information (Details)	3 Months Ended	12 Months Ended
	Sep. 30, 2023 USD ($)	Sep. 30, 2023 USD ($)
Lessor, Lease, Description [Line Items]
Operating leases not yet commenced	$ 0	$ 0
Finance leases not yet commenced	$ 0	$ 0
Renewal term (up to)	9 years	9 years
AmeriGas OLP
Lessor, Lease, Description [Line Items]
Sale-leaseback transaction term	6 years
Cash proceeds	$ 32,000,000
Pre tax gain	$ 29,000,000
AmeriGas Propane | Lease Liability Total | Segment Concentration Risk
Lessor, Lease, Description [Line Items]
Risk percent		80%
Minimum | Vehicles
Lessor, Lease, Description [Line Items]
Operating lease remaining lease term	1 year	1 year
Maximum | Vehicles
Lessor, Lease, Description [Line Items]
Operating lease remaining lease term	10 years	10 years

Leases - Assets and Liabilities

Leases - Assets and Liabilities Lessee (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
ROU assets:
Operating lease ROU assets	$ 420	$ 368
Finance lease ROU assets	50	48
Total ROU assets	$ 470	$ 416
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Other Assets, Noncurrent	Other Assets, Noncurrent
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Property, Plant, and Equipment and Finance Lease Right-of-Use Asset, after Accumulated Depreciation and Amortization	Property, Plant, and Equipment and Finance Lease Right-of-Use Asset, after Accumulated Depreciation and Amortization
Lease liabilities:
Operating lease liabilities — current	$ 87	$ 82
Operating lease liabilities — noncurrent	340	294
Finance lease liabilities — current	5	4
Finance lease liabilities — noncurrent	45	41
Total lease liabilities	$ 477	$ 421
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Other Liabilities, Current	Other Liabilities, Current
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other noncurrent liabilities	Other noncurrent liabilities
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	Current maturities of long-term debt	Current maturities of long-term debt
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Long-Term Debt and Lease Obligation	Long-Term Debt and Lease Obligation

Leases - Component of Lease Exp

Leases - Component of Lease Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Leases [Abstract]
Operating lease cost	$ 104	$ 96	$ 101
Finance lease cost:
Amortization of ROU assets	3	4	4
Interest on lease liabilities	3	3	3
Variable lease cost	2	6	4
Short-term lease cost	4	2	2
Total lease cost	116	111	114
Cash paid related to lease liabilities:
Operating cash flows — operating leases	103	95	99
Operating cash flows — finance leases	3	3	3
Financing cash flows — finance leases	1	2	3
Non-cash lease liability activities:
ROU assets obtained in exchange for operating lease liabilities	136	72	85
ROU assets obtained in exchange for finance lease liabilities	$ 6	$ 2	$ 1
Weighted-average remaining lease term (in years)
Operating leases	7 years 1 month 6 days	6 years
Finance leases	5 years 3 months 18 days	3 years 8 months 12 days
Weighted-average discount rate (%)
Operating leases	4.50%	3.60%
Finance leases	2.20%	1.80%

Leases - Operating and Finance

Leases - Operating and Finance Leases, Liability, Maturity (Details) $ in Millions	Sep. 30, 2023 USD ($)
Operating leases
2024	$ 104
2025	86
2026	72
2027	61
2028	49
After 2028	130
Total Lease Payments	502
Imputed Interest	(75)
Lease Liabilities	427
Finance leases
2024	5
2025	5
2026	5
2027	4
2028	4
After 2028	76
Total Lease Payments	99
Imputed Interest	(49)
Lease Liabilities	$ 50

Commitments and Contingencies -

Commitments and Contingencies - Contingencies (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($) record_of_decision	Sep. 30, 2023 USD ($) subsidiary	Mar. 24, 2023 person	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)
Loss Contingencies [Line Items]
Environmental expenditures cap during year		$ 5
Damage from Fire, Explosion or Other Hazard
Loss Contingencies [Line Items]
Number of fatalities | person			7
Number of injuries | person			11
CPG, PNG and UGI Gas COAs
Loss Contingencies [Line Items]
Accrued liabilities for environmental investigation and remediation costs related to CPG-COA and PNG-COA		$ 52		$ 53
UGI Utilities, Inc. | CPG and PNG
Loss Contingencies [Line Items]
Number of subsidiaries acquired with similar histories | subsidiary		2
AmeriGas OLP | Saranac Lake, New York | New York State Department of Environment Conservation Remediation Plan
Loss Contingencies [Line Items]
Accrued liabilities for environmental investigation and remediation costs related to CPG-COA and PNG-COA				$ 8	$ 8
Number of records of decisions drafted | record_of_decision	3
Estimated remediation plan cost	$ 28

Fair Value Measurements - Finan

Fair Value Measurements - Financial Assets and Liabilities Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	$ 298	$ 2,418
Derivative instruments, Liabilities	(276)	(515)
Non-qualified supplemental postretirement grantor trust investments	39	43
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-qualified supplemental postretirement grantor trust investments	39	43
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-qualified supplemental postretirement grantor trust investments	0	0
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-qualified supplemental postretirement grantor trust investments	0	0
Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	232	2,233
Derivative instruments, Liabilities	(274)	(513)
Commodity contracts | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	117	938
Derivative instruments, Liabilities	(193)	(377)
Commodity contracts | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	115	1,268
Derivative instruments, Liabilities	(81)	(136)
Commodity contracts | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	0	27
Derivative instruments, Liabilities	0	0
Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	38	119
Derivative instruments, Liabilities	(2)	(2)
Foreign currency contracts | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	0	0
Derivative instruments, Liabilities	0	0
Foreign currency contracts | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	38	119
Derivative instruments, Liabilities	(2)	(2)
Foreign currency contracts | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	0	0
Derivative instruments, Liabilities	0	0
Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	28	66
Interest rate contracts | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	0	0
Interest rate contracts | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	28	66
Interest rate contracts | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	$ 0	$ 0

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($)	3 Months Ended		12 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Impairment of goodwill			$ 656,000,000	$ 0	$ 0
AmeriGas Propane
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Impairment of goodwill	$ 656,000,000	$ 656,000,000	656,000,000
Level 3 | Commodity contracts | Minimum
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Unobservable inputs reconciliation	7,000,000		7,000,000
Level 3 | Commodity contracts | Maximum
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Unobservable inputs reconciliation	$ 27,000,000		$ 27,000,000

Fair Value Measurements - Long-

Fair Value Measurements - Long-term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,647	$ 6,665
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,238	$ 6,189

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Narrative (Details)	12 Months Ended
	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2023 EUR (€)	Sep. 30, 2022 EUR (€)	Dec. 07, 2021 EUR (€)
Derivative [Line Items]
Pre-tax net losses associated with interest rate hedges	$ 46,000,000
Pre-tax (losses) gains associated with net investment hedges	(57,000,000)	$ 123,000,000	$ 9,000,000
Maximum amount of loss	298,000,000
Cash collateral received	40,000,000	398,000,000
3.25% Senior Notes Due November 2025 | UGI Utilities Senior Notes: | UGI International LLC
Derivative [Line Items]
Interest rate						3.25%
IRPA
Derivative [Line Items]
Notional amount	$ 0	0
Foreign Exchange Forward
Derivative [Line Items]
Potential exposure coverage, percent (as a percentage)	90%			90%
Foreign currency contracts
Derivative [Line Items]
Notional amount	$ 425,000,000	$ 465,000,000		€ 256,000,000	€ 411,000,000
Foreign currency contracts | UGI International LLC | Net Investment Hedging
Derivative [Line Items]
Notional amount | €						€ 93,000,000

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	12 Months Ended
	Sep. 30, 2023 USD ($) DTH kWh gal	Sep. 30, 2022 USD ($) DTH kWh gal	Sep. 30, 2023 EUR (€) DTH	Sep. 30, 2022 EUR (€) DTH
Commodity contracts | Propane
Derivative [Line Items]
Notional Amounts (in millions) | gal	727	874
Commodity contracts | Electricity
Derivative [Line Items]
Notional Amounts (in millions) | kWh	1,260	2,446
Natural gas futures, forward, basis swap, options and pipeline contracts | Natural Gas
Derivative [Line Items]
Notional amount (in units)	338	363	338	363
Interest rate swaps
Derivative [Line Items]
Notional amount	$ 1,270	$ 1,358	€ 300	€ 300
Forward foreign currency exchange contracts
Derivative [Line Items]
Notional amount	$ 425	$ 465	€ 256	€ 411
Regulated Utility Operations | Commodity contracts | Natural Gas
Derivative [Line Items]
Notional amount (in units)	38	19	38	19

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Schedule of Derivative Assets, Liabilities and the Effects of Offsetting (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022
Derivative assets:
Fair value of derivative instruments	$ 298	$ 2,418
Gross amounts offset in the balance sheet	(124)	(295)
Cash collateral received	(40)	(398)
Total derivative assets – net	134	1,725
Derivative liabilities:
Derivative instrument, Liabilities	276	515
Gross amounts offset in the balance sheet	124	295
Cash collateral pledged	53	7
Total derivative liabilities – net	(99)	(213)
Foreign currency contracts
Derivative assets:
Fair value of derivative instruments	38	119
Derivative liabilities:
Derivative instrument, Liabilities	2	2
Interest rate contracts
Derivative assets:
Fair value of derivative instruments	28	66
Commodity contract - subject to PGC and DS mechanisms
Derivative assets:
Fair value of derivative instruments	6	31
Derivative liabilities:
Derivative instrument, Liabilities	8	26
Commodity contracts
Derivative assets:
Fair value of derivative instruments	232	2,233
Derivative liabilities:
Derivative instrument, Liabilities	274	513
Derivatives designated as hedging instruments
Derivative assets:
Fair value of derivative instruments	42	123
Derivatives designated as hedging instruments | Foreign currency contracts
Derivative assets:
Fair value of derivative instruments	14	57
Derivatives designated as hedging instruments | Interest rate contracts
Derivative assets:
Fair value of derivative instruments	28	66
Derivatives not designated as hedging instruments
Derivative assets:
Fair value of derivative instruments	250	2,264
Derivative liabilities:
Derivative instrument, Liabilities	268	489
Derivatives not designated as hedging instruments | Foreign currency contracts
Derivative assets:
Fair value of derivative instruments	24	62
Derivative liabilities:
Derivative instrument, Liabilities	2	2
Derivatives not designated as hedging instruments | Commodity contracts
Derivative assets:
Fair value of derivative instruments	226	2,202
Derivative liabilities:
Derivative instrument, Liabilities	266	487
Derivatives not designated as hedging instruments | Commodity contracts | Held for sale assets
Derivative assets:
Fair value of derivative instruments	10	295
Derivatives not designated as hedging instruments | Commodity contracts | Held for sale liabilities
Derivative liabilities:
Derivative instrument, Liabilities	$ 12	$ 19

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Effects of Derivative Instruments on Condensed Consolidated Statements of Income and Changes in AOCI and Noncontrolling Interest (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Derivatives Not Designated as Hedging Instruments:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ (1,781)	$ 1,236	$ 1,542
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Revenues
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	11	(9)	(17)
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(1,771)	1,181	1,545
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Other operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	2	1	5
Derivatives Not Designated as Hedging Instruments: | Foreign currency contracts | Other non-operating (expense) income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(23)	63	9
Cash Flow Hedges: | Interest rate contracts
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	25	91	4
Cash Flow Hedges: | Interest rate contracts | Interest expense
Derivative Instruments, Gain (Loss)
Gain (Loss) Reclassified from AOCI into Income	40	(7)	(25)
Net Investment Hedges: | Foreign currency contracts
Derivative Instruments, Gain (Loss)
Foreign currency contracts	$ (21)	$ 69	$ 4

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	$ 6,074	$ 5,531
Other comprehensive income (loss) before reclassification adjustments	153	(249)	$ (13)
Amounts reclassified from AOCI	(29)	9	20
Other comprehensive income (loss) attributable to UGI	124	(240)	7
Balance, end of year	4,394	6,074	5,531
Accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(380)	(140)	(147)
Balance, end of year	(256)	(380)	(140)
Postretirement Benefit Plans
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	14	(17)	(26)
Other comprehensive income (loss) before reclassification adjustments	5	28	7
Amounts reclassified from AOCI	(2)	3	2
Other comprehensive income (loss) attributable to UGI	3	31	9
Balance, end of year	17	14	(17)
Derivative Instruments
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	37	(33)	(54)
Other comprehensive income (loss) before reclassification adjustments	16	64	3
Amounts reclassified from AOCI	(27)	6	18
Other comprehensive income (loss) attributable to UGI	(11)	70	21
Balance, end of year	26	37	(33)
Foreign Currency
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(431)	(90)	(67)
Other comprehensive income (loss) before reclassification adjustments	132	(341)	(23)
Amounts reclassified from AOCI	0	0	0
Other comprehensive income (loss) attributable to UGI	132	(341)	(23)
Balance, end of year	$ (299)	$ (431)	$ (90)

Other Operating Income, Net a_3

Other Operating Income, Net and Other Non-Operating Income (Expense), Net - Other Operating Income, Net (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Property, Plant and Equipment
Finance charges	$ 17	$ 18	$ 17
Gains on sales of fixed assets, net	61	33	11
Gain on early derivative termination	0	0	5
Foreign currency transaction gains (losses)	7	(5)	0
Cylinder deposit income	23	18	9
Interest and interest-related income	6	1	0
Other, net	18	14	(9)
Total other operating income, net	132	$ 79	$ 33
Building
Property, Plant and Equipment
Gains on sales of fixed assets, net	$ 15

Other Operating Income, Net a_4

Other Operating Income, Net and Other Non-Operating Income (Expense), Net - Schedule of Other Non-Operating (Expense) Income, Net (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Component of Operating Income [Abstract]
(Losses) gains on foreign currency contracts, net	$ (23)	$ 63	$ 9
Amortization of excluded components of certain net investment hedges	7	7	2
Pension and other postretirement plans non-service income, net	9	5	1
Total other non-operating (expense) income, net	$ (7)	$ 75	$ 12

Equity Method Investments - Sch

Equity Method Investments - Schedule of Equity Method Investments (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 299	$ 130	$ 174
Aurum Renewables
Schedule of Equity Method Investments [Line Items]
Ownership Interest	40%
Midstream & Marketing
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 264	109
Midstream & Marketing | Aurum Renewables
Schedule of Equity Method Investments [Line Items]
Carrying Value	45	0
Midstream & Marketing | Pine Run
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 77	$ 68
Ownership Interest	49%	49%
Midstream & Marketing | MBL Bioenergy
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 122	$ 23
Ownership Interest	99.99%	99.99%
Midstream & Marketing | Other
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 20	$ 18
UGI International
Schedule of Equity Method Investments [Line Items]
Carrying Value	$ 35	$ 21

Equity Method Investments - Nar

Equity Method Investments - Narrative (Details) $ in Millions	1 Months Ended			3 Months Ended	12 Months Ended
	Jan. 31, 2023 MMBTU MW	Jun. 30, 2021 USD ($)	Feb. 28, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) owner mi	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)
Schedule of Equity Method Investments [Line Items]
Carrying Value				$ 130	$ 299	$ 130	$ 174
Equity in (loss) income of unconsolidated subsidiaries					2	$ (14)	$ (63)
Pine Run
Schedule of Equity Method Investments [Line Items]
Total purchase price			$ 205
Total cash paid			115
Liabilities incurred			$ 90
Pennant
Schedule of Equity Method Investments [Line Items]
Effective ownership interest in AmeriGas OLP (as a percentage)				47%		47%
Total purchase price				$ 61
Percentage of voting interests acquired				53%		53%
Other-than-temporary pre-tax impairment charge				$ 44
Aurum Renewables
Schedule of Equity Method Investments [Line Items]
Landfill gas units | MW	11
Effective ownership interest in AmeriGas OLP (as a percentage)	40%
Expected production capacity per day | MMBTU	5,000
Energy Services | Pennant
Schedule of Equity Method Investments [Line Items]
Percentage of voting interests acquired				53%		53%
PennEast Pipeline Company, LLC
Schedule of Equity Method Investments [Line Items]
Pretax impairment charge		$ 93
Equity in (loss) income of unconsolidated subsidiaries						$ 9
PennEast Pipeline Company, LLC | Level 2
Schedule of Equity Method Investments [Line Items]
Carrying Value				$ 0	$ 0	0
PennEast Pipeline Company, LLC | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Area of natural gas pipeline to be constructed (in miles) | mi					120
Pennant | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Ownership Interest					20%
Number of other members | owner					4
Other
Schedule of Equity Method Investments [Line Items]
Pretax impairment charge					$ 55	$ 39

Segment Information - Narrative

Segment Information - Narrative (Details)	12 Months Ended
	Sep. 30, 2023 segment state
Segment Reporting [Abstract]
Number of reportable segments | segment	4
Number of states to which product sale with propane revenue | state	50
France | Geographic Concentration Risk | Revenues
Segment Reporting Information [Line Items]
Concentration risk, percentage (as a percentage)	20%
France | Geographic Concentration Risk | Long-lived Assets
Segment Reporting Information [Line Items]
Concentration risk, percentage (as a percentage)	10%

Segment Information - Schedule

Segment Information - Schedule of Segment Reporting (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Segment Reporting Information [Line Items]
Revenues	$ 8,928	$ 10,106	$ 7,447
Cost of sales	6,937	5,973	2,614
Operating income	(1,444)	1,666	2,350
Income (loss) from equity investees	2	(14)	(63)
Loss on extinguishment of debt	(9)	(11)	0
Other non-operating (loss) income, net	(7)	75	12
Earnings before interest expense and income taxes	(1,458)	1,716	2,299
Interest expense	(379)	(329)	(310)
Income tax expense	335	(313)	(522)
Noncontrolling interests’ net (income) loss	0	(1)	0
Net (loss) income attributable to UGI Corporation	(1,502)	1,073	1,467
Depreciation and amortization	532	518	502
Total assets	15,401	17,575	16,723
Short-term borrowings	649	368	367
Capital expenditures (including the effects of accruals)	956	835	674
Investments in equity investees	299	130	174
UGI International
Segment Reporting Information [Line Items]
Investments in equity investees	35	21
Midstream & Marketing
Segment Reporting Information [Line Items]
Investments in equity investees	264	109
Elim- inations
Segment Reporting Information [Line Items]
Revenues	(326)	(477)	(291)
Cost of sales	(325)	(474)	(288)
Operating income	0	0	0
Income (loss) from equity investees	0	0	0
Loss on extinguishment of debt	0	0
Other non-operating (loss) income, net	0	0	0
Earnings before interest expense and income taxes	0	0	0
Interest expense	0	0	0
Income tax expense	0	0	0
Noncontrolling interests’ net (income) loss		0
Net (loss) income attributable to UGI Corporation	0	0	0
Depreciation and amortization	0	0	0
Total assets	(173)	(203)	(241)
Short-term borrowings	0	0	0
Capital expenditures (including the effects of accruals)		0	0
Investments in equity investees	0	0	0
Elim- inations | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	0	0	0
Elim- inations | UGI International
Segment Reporting Information [Line Items]
Revenues	0	0	0
Elim- inations | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	251	369	224
Elim- inations | Utilities
Segment Reporting Information [Line Items]
Revenues	74	105	64
Operating Segments | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	2,581	2,943	2,614
Cost of sales	1,250	1,613	1,217
Operating income	268	307	385
Income (loss) from equity investees	0	0	0
Loss on extinguishment of debt	0	0
Other non-operating (loss) income, net	0	0	0
Earnings before interest expense and income taxes	268	307	385
Interest expense	(163)	(160)	(159)
Income tax expense	(34)	(35)	(58)
Noncontrolling interests’ net (income) loss		0
Net (loss) income attributable to UGI Corporation	71	112	168
Depreciation and amortization	177	177	173
Total assets	3,415	4,332	4,485
Short-term borrowings	0	131	170
Capital expenditures (including the effects of accruals)	134	128	130
Investments in equity investees	0	0	0
Operating Segments | UGI International
Segment Reporting Information [Line Items]
Revenues	2,965	3,686	2,651
Cost of sales	2,045	2,751	1,598
Operating income	215	237	314
Income (loss) from equity investees	(4)	(2)	0
Loss on extinguishment of debt	0	0
Other non-operating (loss) income, net	23	19	3
Earnings before interest expense and income taxes	234	254	317
Interest expense	(37)	(28)	(27)
Income tax expense	(25)	(50)	(69)
Noncontrolling interests’ net (income) loss		(1)
Net (loss) income attributable to UGI Corporation	172	175	221
Depreciation and amortization	116	116	134
Total assets	3,105	4,610	4,421
Short-term borrowings	214	1	0
Capital expenditures (including the effects of accruals)	129	107	107
Investments in equity investees	35	20	11
Operating Segments | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	1,847	2,326	1,406
Revenues from external customers	1,596	1,957	1,182
Cost of sales	1,360	1,876	1,033
Operating income	285	246	160
Income (loss) from equity investees	6	23	30
Loss on extinguishment of debt	0	0
Other non-operating (loss) income, net	0	0	0
Earnings before interest expense and income taxes	291	269	190
Interest expense	(45)	(41)	(42)
Income tax expense	(53)	(65)	(41)
Noncontrolling interests’ net (income) loss		0
Net (loss) income attributable to UGI Corporation	193	163	107
Depreciation and amortization	86	79	76
Total assets	3,160	3,286	3,010
Short-term borrowings	103	0	0
Capital expenditures (including the effects of accruals)	130	38	43
Investments in equity investees	264	109	163
Operating Segments | Utilities
Segment Reporting Information [Line Items]
Revenues	1,854	1,620	1,079
Revenues from external customers	1,780	1,515	1,015
Cost of sales	953	798	458
Operating income	357	327	241
Income (loss) from equity investees	0	0	0
Loss on extinguishment of debt	0	0
Other non-operating (loss) income, net	8	9	1
Earnings before interest expense and income taxes	365	336	242
Interest expense	(82)	(65)	(56)
Income tax expense	(64)	(65)	(42)
Noncontrolling interests’ net (income) loss		0
Net (loss) income attributable to UGI Corporation	219	206	144
Depreciation and amortization	152	144	119
Total assets	5,691	5,354	4,859
Short-term borrowings	332	236	197
Capital expenditures (including the effects of accruals)	563	562	394
Investments in equity investees	0	0	0
Corporate & Other
Segment Reporting Information [Line Items]
Revenues	7	8	(12)
Revenues from external customers	6	5	(15)
Cost of sales	1,654	(591)	(1,404)
Operating income	(2,569)	549	1,250
Income (loss) from equity investees	0	(35)	(93)
Loss on extinguishment of debt	(9)	(11)
Other non-operating (loss) income, net	(38)	47	8
Earnings before interest expense and income taxes	(2,616)	550	1,165
Interest expense	(52)	(35)	(26)
Income tax expense	511	(98)	(312)
Noncontrolling interests’ net (income) loss		0
Net (loss) income attributable to UGI Corporation	(2,157)	417	827
Depreciation and amortization	1	2	0
Total assets	203	196	189
Short-term borrowings	0	0	0
Capital expenditures (including the effects of accruals)	0	0	0
Investments in equity investees	0	1	0
Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishment of debt	(9)	0
Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Loss on extinguishment of debt	0	(11)
Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishment of debt	0	0
Corporate, Intersegment Eliminations & Other
Segment Reporting Information [Line Items]
Revenues	$ 1	$ 3	$ 3

Segment Information - Corporate

Segment Information - Corporate and Other segment information (Details) - USD ($)	3 Months Ended		12 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			$ (1,682,000,000)	$ 648,000,000	$ 1,398,000,000
Loss on extinguishment of debt			(9,000,000)	(11,000,000)	0
Loss associated with impairment of AmeriGas Propane goodwill			(656,000,000)	0	0
Impairment of customer relationship intangible					(20,000,000)
Costs associated with exit of the UGI International energy marketing business			(221,000,000)	0	$ 0
Restructuring, Incurred Cost, Statement of Income or Comprehensive Income [Extensible Enumeration]
AmeriGas Propane
Segment Reporting Information [Line Items]
Loss associated with impairment of AmeriGas Propane goodwill	$ (656,000,000)	$ (656,000,000)	(656,000,000)
UGI International
Segment Reporting Information [Line Items]
Loss associated with impairment of AmeriGas Propane goodwill			0
Midstream & Marketing
Segment Reporting Information [Line Items]
Loss associated with impairment of AmeriGas Propane goodwill			0
Corporate & Other
Segment Reporting Information [Line Items]
Loss on extinguishment of debt			(9,000,000)	(11,000,000)
Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishment of debt			(9,000,000)	0
Loss associated with impairment of AmeriGas Propane goodwill			(656,000,000)
Corporate & Other | AmeriGas Propane | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			0	0	$ 0
Corporate & Other | AmeriGas Propane | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			(16,000,000)	(185,000,000)	167,000,000
Corporate & Other | AmeriGas Propane | Other operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions				0
Corporate & Other | AmeriGas Propane | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas performance enhancement			(24,000,000)	(5,000,000)
Restructuring costs				(16,000,000)	(54,000,000)
Impairment of customer relationship intangible					0
Costs associated with exit of the UGI International energy marketing business				0
Corporate & Other | AmeriGas Propane | Other non-operating (expense) income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			0	0	0
Corporate & Other | AmeriGas Propane | Income (loss) from equity investees
Segment Reporting Information [Line Items]
Impairments associated with certain equity method investments				0	0
Corporate & Other | AmeriGas Propane | Revenues/Operating and administrative expenses
Segment Reporting Information [Line Items]
Costs associated with exit of the UGI International energy marketing business			0
Corporate & Other | 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
Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Loss on extinguishment of debt			0	(11,000,000)
Loss associated with impairment of AmeriGas Propane goodwill			0
Corporate & Other | UGI International | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			4,000,000	9,000,000	0
Corporate & Other | UGI International | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			(1,402,000,000)	797,000,000	1,065,000,000
Corporate & Other | UGI International | Other operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions				2,000,000
Corporate & Other | UGI International | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas performance enhancement			0	0
Restructuring costs				(9,000,000)	(33,000,000)
Impairment of customer relationship intangible					(20,000,000)
Costs associated with exit of the UGI International energy marketing business				(5,000,000)
Corporate & Other | UGI International | Other non-operating (expense) income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			(38,000,000)	50,000,000	8,000,000
Corporate & Other | UGI International | Income (loss) from equity investees
Segment Reporting Information [Line Items]
Impairments associated with certain equity method investments				0	0
Corporate & Other | UGI International | Revenues/Operating and administrative expenses
Segment Reporting Information [Line Items]
Costs associated with exit of the UGI International energy marketing business			(27,000,000)
Corporate & Other | 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			(221,000,000)
Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishment of debt			0	0
Loss associated with impairment of AmeriGas Propane goodwill			0
Corporate & Other | Midstream & Marketing | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			6,000,000	(4,000,000)	(15,000,000)
Corporate & Other | Midstream & Marketing | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			(236,000,000)	(21,000,000)	173,000,000
Corporate & Other | Midstream & Marketing | Other operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions				0
Corporate & Other | Midstream & Marketing | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas performance enhancement			0	0
Restructuring costs				(1,000,000)	0
Impairment of customer relationship intangible					0
Costs associated with exit of the UGI International energy marketing business				0
Corporate & Other | Midstream & Marketing | Other non-operating (expense) income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			0	0	0
Corporate & Other | Midstream & Marketing | Income (loss) from equity investees
Segment Reporting Information [Line Items]
Impairments associated with certain equity method investments				$ (35,000,000)	$ (93,000,000)
Corporate & Other | Midstream & Marketing | Revenues/Operating and administrative expenses
Segment Reporting Information [Line Items]
Costs associated with exit of the UGI International energy marketing business			0
Corporate & Other | 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

Global LPG Business Transform_2

Global LPG Business Transformation Initiatives (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Restructuring Cost and Reserve [Line Items]
Costs principally comprising consulting, advisory and employee-related costs			$ 87
Corporate Services Member
Restructuring Cost and Reserve [Line Items]
Costs principally comprising consulting, advisory and employee-related costs	$ 10	$ 9	$ 14

SCHEDULE I _ CONDENSED FINANC_3

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) - BALANCE SHEETS (Details) - USD ($) $ in Millions	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Current assets
Cash and cash equivalents	$ 241	$ 405	$ 855
Prepaid expenses and other current assets	114	120
Total current assets	2,045	3,802
Other assets	988	755
Total assets	15,401	17,575	$ 16,723
Current liabilities
Current maturities of long-term debt	57	149
Total current liabilities	2,274	2,444
Long-term debt	6,543	6,483
Other noncurrent liabilities	1,235	1,219
Total liabilities	11,007	11,501
Commitments and contingencies (Note 1)
Equity:
Preferred Stock, without par value (authorized - 5,000,000; issued - 220,000 and 220,000, respectively)	167	162
Common Stock, without par value (authorized – 450,000,000 shares; issued – 210,906,052 and 210,560,494 shares, respectively)	1,503	1,483
Retained earnings	3,027	4,841
Accumulated other comprehensive loss	(256)	(380)
Treasury stock, at cost	(55)	(40)
Total UGI Corporation stockholders’ equity	4,386	6,066
Total liabilities and equity	$ 15,401	$ 17,575
Condensed Financial Information of Registrant [Abstract]
UGI Preferred Stock, without par value, shares authorized (in shares)	5,000,000	5,000,000
Preferred Stock, shares issued (in shares)	220,000	220,000	220,000	0
Common Stock, shares authorized (in shares)	450,000,000	450,000,000
Common Stock, shares issued (in shares)	210,906,052	210,560,494
Parent Company
Current assets
Cash and cash equivalents	$ 7	$ 20
Accounts receivable – related parties	11	24
Prepaid expenses and other current assets	23	20
Total current assets	41	64
Property, plant and equipment, net	0	1
Investments in subsidiaries	5,343	7,035
Other assets	143	97
Total assets	5,527	7,197
Current liabilities
Current maturities of long-term debt	38	125
Accounts and notes payable	28	20
Accrued liabilities	39	51
Total current liabilities	105	196
Long-term debt	969	889
Other noncurrent liabilities	67	46
Total liabilities	1,141	1,131
Commitments and contingencies (Note 1)
Equity:
Preferred Stock, without par value (authorized - 5,000,000; issued - 220,000 and 220,000, respectively)	167	162
Common Stock, without par value (authorized – 450,000,000 shares; issued – 210,906,052 and 210,560,494 shares, respectively)	1,503	1,483
Retained earnings	3,027	4,841
Accumulated other comprehensive loss	(256)	(380)
Treasury stock, at cost	(55)	(40)
Total UGI Corporation stockholders’ equity	4,386	6,066
Total liabilities and equity	$ 5,527	$ 7,197
Condensed Financial Information of Registrant [Abstract]
Common Stock, shares authorized (in shares)	450,000,000	450,000,000
Common Stock, shares issued (in shares)	210,906,052	210,560,494

SCHEDULE I _ CONDENSED FINANC_4

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) - Narrative (Details) $ in Millions	12 Months Ended
	Sep. 30, 2023 USD ($)
Guarantee Obligations [Line Items]
Debt repayment in year 2022	$ 57
Debt repayment in year 2023	1,687
Parent Company
Guarantee Obligations [Line Items]
Surety bonds indemnified	105
Maximum amount authorized to guarantee obligations to suppliers and customers (up to)	475
Current carrying value	$ 358

SCHEDULE I _ CONDENSED FINANC_5

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) - STATEMENTS OF INCOME (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 8,928	$ 10,106	$ 7,447
Costs and expenses:
Operating and administrative expenses	2,158	2,028	2,014
Other operating income, net	(132)	(79)	(33)
Total costs and expenses	10,372	8,440	5,097
Operating (loss) income	(1,444)	1,666	2,350
Pension and other postretirement plans non-service expense	9	5	1
Income tax (benefit) expense	(335)	313	522
Equity in (loss) income of unconsolidated subsidiaries	2	(14)	(63)
Net (loss) income attributable to UGI Corporation	(1,502)	1,073	1,467
Comprehensive (loss) income attributable to UGI Corporation	$ (1,378)	$ 833	$ 1,474
(Loss) earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ (7.16)	$ 5.11	$ 7.02
Diluted (in dollars per share)	$ (7.16)	$ 4.97	$ 6.92
Weighted - average common shares outstanding (thousands):
Basic (in shares)	209,806	209,940	209,063
Diluted (in shares)	209,806	215,821	212,126
Parent Company
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 0	$ 0	$ 0
Costs and expenses:
Operating and administrative expenses	95	74	94
Other operating income, net	(83)	(63)	(65)
Total costs and expenses	12	11	29
Operating (loss) income	(12)	(11)	(29)
Pension and other postretirement plans non-service expense	0	(3)	0
Interest expense	(52)	(35)	(27)
Loss before income taxes	(64)	(49)	(56)
Income tax (benefit) expense	(13)	0	9
Loss before equity in income of unconsolidated subsidiaries	(51)	(49)	(65)
Equity in (loss) income of unconsolidated subsidiaries	(1,451)	1,122	1,532
Net (loss) income attributable to UGI Corporation	(1,502)	1,073	1,467
Other comprehensive (loss) income	(8)	34	7
Equity in other comprehensive income (loss) of unconsolidated subsidiaries	132	(274)	0
Comprehensive (loss) income attributable to UGI Corporation	$ (1,378)	$ 833	$ 1,474
(Loss) earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ (7.16)	$ 5.11	$ 7.02
Diluted (in dollars per share)	$ (7.16)	$ 4.97	$ 6.92
Weighted - average common shares outstanding (thousands):
Basic (in shares)	209,806	209,940	209,063
Diluted (in shares)	209,806	215,821	212,126

SCHEDULE I _ CONDENSED FINANC_6

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) - STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Condensed Financial Statements, Captions [Line Items]
NET CASH PROVIDED BY OPERATING ACTIVITIES	$ 1,107	$ 716	$ 1,481
CASH FLOWS FROM INVESTING ACTIVITIES
Net cash used by investing activities	(1,077)	(1,012)	(1,113)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(308)	(296)	(282)
Issuances of debt, net of issuance costs	1,930	1,257	656
Issuances of UGI Common Stock	12	19	19
Repurchases of UGI Common Stock	(22)	(38)	0
Net cash (used) provided by financing activities	(168)	(51)	166
Cash, cash equivalents and restricted cash (decrease) increase	(129)	(408)	520
Cash and cash equivalents:
Cash, cash equivalents and restricted cash at end of year	340	469	877
Cash, cash equivalents and restricted cash at beginning of year	469	877	357
Cash and cash equivalents (decrease) increase	(129)	(408)	520
Parent Company
Condensed Financial Statements, Captions [Line Items]
NET CASH PROVIDED BY OPERATING ACTIVITIES	636	485	300
CASH FLOWS FROM INVESTING ACTIVITIES
Return of capital distributions	0	175	0
Net investments in unconsolidated subsidiaries	(309)	(390)	(401)
Net cash used by investing activities	(309)	(215)	(401)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(308)	(296)	(282)
Issuances of debt, net of issuance costs	327	597	483
Repayments of long-term debt	(333)	(530)	(385)
Issuance of Preferred Stock, net of issuance costs	0	0	213
Issuances of UGI Common Stock	12	19	19
Repurchases of UGI Common Stock	(22)	(38)	0
Payments on Purchase Contracts	(16)	(16)	0
Net cash (used) provided by financing activities	(340)	(264)	48
Cash, cash equivalents and restricted cash (decrease) increase	(13)	6	(53)
Cash and cash equivalents:
Cash, cash equivalents and restricted cash at end of year	7	20	14
Cash, cash equivalents and restricted cash at beginning of year	20	14	67
Cash and cash equivalents (decrease) increase	(13)	6	(53)
Dividends from unconsolidated subsidiaries	$ 680	$ 506	$ 354

SCHEDULE II _ VALUATION AND Q_2

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Allowance for doubtful accounts
Valuation and Qualifying Account
Balance at beginning of year	$ 64	$ 53	$ 42
Charged (credited) to costs and expenses	69	61	36
Other	(62)	(50)	(25)
Balance at end of year	71	64	53
Deferred tax assets valuation allowance
Valuation and Qualifying Account
Balance at beginning of year	141	138	105
Charged (credited) to costs and expenses	(38)	(14)	23
Other	38	17	10
Balance at end of year	$ 141	$ 141	$ 138