UGI (UGI) 10-K 21 Nov 22 2022 FY Annual report Financial data

Cover Page

Cover Page - USD ($)	12 Months Ended
	Sep. 30, 2022	Nov. 11, 2022	Mar. 31, 2022
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Sep. 30, 2022
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	460 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
Entity Shell Company	false
Entity Public Float			$ 7,563,617,921
Entity Common Stock, Shares Outstanding		209,690,320
Documents Incorporated by Reference	Portions of the Proxy Statement for the Annual Meeting of Shareholders to be held on January 27, 2023 are incorporated by reference into Part III of this Form 10-K.
Entity Central Index Key	0000884614
Amendment Flag	false
Document Fiscal Year Focus	2022
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, 2022
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, 2022	Sep. 30, 2021
Current assets
Cash and cash equivalents	$ 405	$ 855
Restricted cash	64	22
Accounts receivable (less allowances for doubtful accounts of $64 and $53, respectively)	1,127	880
Accrued utility revenues	23	15
Income taxes receivable	128	128
Inventories	665	469
Derivative instruments	865	665
Prepaid expenses	110	135
Held for sale assets (Note 25)	295	0
Other current assets	120	101
Total current assets	3,802	3,270
Property, plant and equipment
Non-utility	6,656	6,486
Utility	5,550	5,022
Total property, plant and equipment	12,206	11,508
Accumulated depreciation	(4,166)	(3,950)
Net property, plant, and equipment	8,040	7,558
Goodwill	3,612	3,770
Intangible assets, net	500	583
Utility regulatory assets	301	373
Derivative instruments	565	338
Other assets	755	831
Total assets	17,575	16,723
Current liabilities
Current maturities of long-term debt	149	110
Short-term borrowings	368	367
Accounts payable	891	837
Employee compensation and benefits accrued	147	181
Deposits and advances	225	208
Derivative instruments	144	60
Held for sale liabilities (Note 25)	19	0
Other current liabilities	501	534
Total current liabilities	2,444	2,297
Noncurrent liabilities
Long-term debt	6,483	6,339
Deferred income taxes	1,305	1,137
Derivative instruments	50	38
Other noncurrent liabilities	1,219	1,381
Total liabilities	11,501	11,192
Commitments and contingencies (Note 17)
UGI Corporation stockholders’ equity:
Preferred Stock, without par value (authorized 5,000,000 shares; issued 220,000 and 220,000 Series A shares, respectively)	162	213
UGI Common Stock, without par value (authorized – 450,000,000 shares; issued – 210,560,494 and 209,843,296 shares, respectively)	1,483	1,394
Retained earnings	4,841	4,081
Accumulated other comprehensive loss	(380)	(140)
Treasury stock, at cost	(40)	(26)
Total UGI Corporation stockholders’ equity	6,066	5,522
Noncontrolling interests	8	9
Total equity	6,074	5,531
Total liabilities and equity	$ 17,575	$ 16,723

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2022	Sep. 30, 2021
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 64	$ 53
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)	210,560,494	209,843,296

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Income Statement [Abstract]
Revenues	$ 10,106	$ 7,447	$ 6,559
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)	5,973	2,614	3,149
Operating and administrative expenses	2,028	2,014	1,911
Loss on disposals of Conemaugh and HVAC	0	0	54
Depreciation and amortization	518	502	484
Other operating income, net	(79)	(33)	(21)
Total costs and expenses	8,440	5,097	5,577
Operating income	1,666	2,350	982
(Loss) income from equity investees	(14)	(63)	27
Loss on extinguishment of debt	(11)	0	0
Other non-operating income (expense), net	75	12	(20)
Interest expense	(329)	(310)	(322)
Income before income taxes	1,387	1,989	667
Income tax expense	(313)	(522)	(135)
Net income including noncontrolling interests	1,074	1,467	532
Deduct net income attributable to noncontrolling interests	(1)	0	0
Net income attributable to UGI Corporation	$ 1,073	$ 1,467	$ 532
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ 5.11	$ 7.02	$ 2.55
Diluted (in dollars per share)	$ 4.97	$ 6.92	$ 2.54
Weighted-average common shares outstanding:
Basic (in shares)	209,940	209,063	208,928
Diluted (in shares)	215,821	212,126	209,869
Restructuring, Incurred Cost, Statement of Income or Comprehensive Income [Extensible Enumeration]	Operating and administrative expenses	Operating and administrative expenses

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Statement of Comprehensive Income [Abstract]
Net income attributable to UGI Corporation	$ 1,074	$ 1,467	$ 532
Net gains (losses) on derivative instruments (net of tax of $(27), $(1), and $15, respectively)	64	3	(38)
Reclassifications of net losses on derivative instruments (net of tax of $(1), $(7), and $(4), respectively)	6	18	9
Foreign currency translation adjustments (net of tax of $(55), $(4), and $12, respectively)	(193)	(11)	15
Foreign currency (losses) gains on long-term intra-company transactions	(148)	(12)	84
Benefit plans, principally actuarial gains (losses) (net of tax of $(10), $(3), and $1, respectively)	28	7	(3)
Reclassifications of benefit plans actuarial losses and net prior service benefit (net of tax of $(1), $(1), and $(1), respectively)	3	2	3
Other comprehensive (loss) income	(240)	7	70
Comprehensive income including noncontrolling interests	834	1,474	602
Deduct comprehensive income attributable to noncontrolling interests	(1)	0	0
Comprehensive income attributable to UGI Corporation	$ 833	$ 1,474	$ 602

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Statement of Comprehensive Income [Abstract]
Net (losses) gains on derivative instruments, tax	$ (27)	$ (1)	$ 15
Reclassifications of net losses on derivative instruments tax	(1)	(7)	(4)
Foreign currency translation adjustments, tax	(55)	(4)	12
Benefit plans, principally actuarial (losses) gains, tax	(10)	(3)	1
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 ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income attributable to UGI Corporation	$ 1,074	$ 1,467	$ 532
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization	518	502	484
Deferred income tax expense, net	221	478	146
Provision for uncollectible accounts	61	36	32
Changes in unrealized gains on derivative instruments	(648)	(1,398)	(81)
Loss on disposals of Conemaugh and HVAC	0	0	54
Equity-based compensation expense	15	21	15
Loss on extinguishments of debt	11	0	0
Loss (income) from equity investees	14	63	(27)
Other, net	3	31	21
Net change in:
Accounts receivable and accrued utility revenues	(431)	(233)	(18)
Income taxes receivable	0	(48)	(80)
Inventories	(224)	(231)	(5)
Utility deferred fuel costs, net of changes in unsettled derivatives	(24)	(22)	17
Accounts payable	85	366	3
Derivative instruments collateral (paid) received	(9)	472	22
Other current assets	54	(10)	38
Other current liabilities	(4)	(13)	(51)
Net cash provided by operating activities	716	1,481	1,102
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(804)	(690)	(655)
Acquisitions of businesses and assets, net of cash and restricted cash acquired	(242)	(397)	(16)
Investments in equity method investees	(47)	(65)	0
Settlements of net investment hedges	26	0	0
Other, net	55	39	22
Net cash used by investing activities	(1,012)	(1,113)	(649)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(296)	(282)	(273)
Issuances of debt, net of issuance costs	1,257	656	209
Repayments of debt and finance leases	(978)	(405)	(86)
Receivables Facility net repayments	0	(19)	(27)
Increase (decrease) in short-term borrowings	1	(16)	(422)
Issuances of preferred stock, net of issuance costs	0	213	0
Issuances of UGI Common Stock	19	19	2
Repurchases of UGI Common Stock	(38)	0	(38)
Payments on Purchase Contracts	(16)	0	0
Net cash (used) provided by financing activities	(51)	166	(635)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(61)	(14)	28
Cash, cash equivalents and restricted cash (decrease) increase	(408)	520	(154)
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of year	469	877	357
Cash, cash equivalents and restricted cash at beginning of year	877	357	511
Cash, cash equivalents and restricted cash (decrease) increase	(408)	520	(154)
Cash paid for:
Interest	320	297	311
Income taxes	$ 61	$ 96	$ 75

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Total UGI Corporation stockholders’ equity	Preferred stock, without par value	Common stock, without par value	Retained earnings	Accumulated other comprehensive income (loss)	Treasury stock	Noncontrolling interests
Balance, beginning of year at Sep. 30, 2019			$ 0	$ 1,397	$ 2,653	$ (217)	$ (16)	$ 10
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other								(1)
Common Stock issued in connection with employee and director plans, net of tax withheld				2
Equity-based compensation expense				17
Net income attributable	$ 532				532
Cash dividends on common stock ($1.41, $1.35, and $1.31 per share, respectively)					(273)
Losses on treasury stock transactions in connection with employee and director plans					(4)
Net gains (losses) on derivative instruments	(38)					(38)
Reclassification of net losses on derivative instruments	9					9
Benefit plans, principally actuarial gains (losses)	(3)					(3)
Reclassification of benefit plans actuarial losses and net prior service benefits	3					3
Foreign currency (losses) gains on long-term intra-company transactions	84					84
Foreign currency translation adjustments	15					15
Common Stock issued in connection with employee and director plans, net of tax withheld							8
Repurchases of common stock							(38)
Reacquired common stock – employee and director plans							(3)
Balance, end of year at Sep. 30, 2020	4,137	$ 4,128	0	1,416	2,908	(147)	(49)	9
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of preferred stock			213	(45)
Other				(2)
Common Stock issued in connection with employee and director plans, net of tax withheld				9
Equity-based compensation expense				16
Net income attributable	1,467				1,467
Cash dividends on common stock ($1.41, $1.35, and $1.31 per share, respectively)					(282)
Losses on treasury stock transactions in connection with employee and director plans					(12)
Net gains (losses) on derivative instruments	3					3
Reclassification of net losses on derivative instruments	18					18
Benefit plans, principally actuarial gains (losses)	7					7
Reclassification of benefit plans actuarial losses and net prior service benefits	2					2
Foreign currency (losses) gains on long-term intra-company transactions	(12)					(12)
Foreign currency translation adjustments	(11)					(11)
Common Stock issued in connection with employee and director plans, net of tax withheld							24
Reacquired common stock – employee and director plans							(1)
Balance, end of year at Sep. 30, 2021	5,531	5,522	213	1,394	4,081	(140)	(26)	9
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beneficial conversion feature			1
Other			(52)	53				(2)
Common Stock issued in connection with employee and director plans, net of tax withheld				19
Equity-based compensation expense				17
Net income attributable	1,074				1,073			1
Cash dividends on common stock ($1.41, $1.35, and $1.31 per share, respectively)					(296)
Losses on treasury stock transactions in connection with employee and director plans					(17)
Net gains (losses) on derivative instruments	64					64
Reclassification of net losses on derivative instruments	6					6
Benefit plans, principally actuarial gains (losses)	28					28
Reclassification of benefit plans actuarial losses and net prior service benefits	3					3
Foreign currency (losses) gains on long-term intra-company transactions	(148)					(148)
Foreign currency translation adjustments	(193)					(193)
Common Stock issued in connection with employee and director plans, net of tax withheld							34
Repurchases of common stock							(38)
Reacquired common stock – employee and director plans							(10)
Balance, end of year at Sep. 30, 2022	$ 6,074	$ 6,066	$ 162	$ 1,483	$ 4,841	$ (380)	$ (40)	$ 8

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Statement of Stockholders' Equity [Abstract]
Cash dividends on common stock (in dollars per share)	$ 1.41	$ 1.35	$ 1.31

Nature of Operations

Nature of Operations	12 Months Ended
	Sep. 30, 2022
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 a national propane distribution business through its principal operating subsidiary AmeriGas OLP. AmeriGas Partners and AmeriGas OLP are Delaware limited partnerships. UGI’s wholly owned second-tier subsidiary, AmeriGas Propane, Inc., serves as the general partner of AmeriGas Partners. UGI International, through subsidiaries and affiliates, conducts (1) an LPG distribution business throughout much of Europe and (2) an energy marketing business in France, Belgium, the Netherlands and the United Kingdom. These businesses are conducted principally through our subsidiaries, UGI France, Flaga, AvantiGas, DVEP and UniverGas. See Note 25 for additional information regarding the October 2022 sale of the United Kingdom energy marketing business and the November 2022 announcement related to the France 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

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Sep. 30, 2022
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. For purposes of comparability, certain prior-year amounts have been reclassified to conform to the current-year presentation. 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 issued in May 2021. 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 22 for more 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 cross-currency swaps and net investment hedges, if any, are included in cash flows from operating activities on the Consolidated Statements of Cash Flows. Cash flows from the interest portion of our cross-currency hedges, if any, are included in cash flows from operating activities while cash flows from the currency portion of such hedges, if any, are included in cash flows from financing activities. Cash flows from net investment hedges, if any, 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 19. 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 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 record interest on underpayments and overpayments of income taxes, and income tax penalties, in “Income tax expense” on the Consolidated Statements of Income. Interest income or expense recognized in “Income tax expense” on the Consolidated Statements of Income 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) 2022 2021 2020 Weighted-average common shares outstanding for basic computation 209,940 209,063 208,928 Incremental shares issuable for stock options, common stock awards and Equity Units (a) (b) 5,881 3,063 941 Weighted-average common shares outstanding for diluted computation 215,821 212,126 209,869 (a) Fiscal 2022 and 2021 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 2022, Fiscal 2021 and Fiscal 2020 there were 8,138 shares, 5,267 shares and 7,056 shares, respectively, associated with outstanding stock option awards that were not included in 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. 2022 2021 2020 Cash and cash equivalents $ 405 $ 855 $ 336 Restricted cash 64 22 21 Cash, cash equivalents and restricted cash $ 469 $ 877 $ 357 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 an intangible asset impairment recognized in 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. With respect to the AmeriGas Propane reporting unit’s Fiscal 2022 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. For the income approach we used management’s best estimates of future anticipated cash flow performance included in AmeriGas Propane’s latest budget and plan, discounted based upon AmeriGas Propane’s weighted average cost of debt and equity. We also used valuation multiples to determine an estimated fair value using recent transaction market multiples for retail propane distribution companies in the U.S. Based upon weighting the fair values estimated using the income and market approaches above, we determined that AmeriGas Propane’s fair value exceeded its carrying value by approximately 30%. While the Company believes that its judgments used in the quantitative assessment of AmeriGas Propane’s fair value are reasonable based upon currently available facts and circumstances, if AmeriGas Propane were not able to achieve its anticipated results and/or if its weighted average cost of capital were to increase, its fair value would be adversely affected, which may result in an impairment. There is approximately $2 billion of goodwill in this reporting unit as of September 30, 2022. The Company will continue to monitor its reporting units and related goodwill for any possible future non-cash impairment charges. There were no accumulated goodwill impairment losses at September 30, 2022 and 2021, and no provisions for goodwill impairments were recognized for all periods presented. For further information on our goodwill and intangible assets, see Note 12. 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. No material provisions for impairments of long-lived assets were recorded during Fiscal 2022. See Note 5 for further information on the losses associated with assets held for sale and the dispositions of Conemaugh and HVAC during Fiscal 2020. 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 $243 and $296 at September 30, 2022 and 2021, 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 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, 2022
Accounting Standards Update and Change in Accounting Principle [Abstract]
Accounting Changes	Note 3 — Accounting Changes New Accounting Standard Adopted in Fiscal 2022 Income Taxes. Effective October 1, 2021, the Company adopted ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes” prospectively and retrospectively where deemed applicable. This ASU simplifies the accounting for income taxes by eliminating certain exceptions within the existing guidance for recognizing deferred taxes for equity method investments, performing intraperiod allocations and calculating income taxes in interim periods. Further, this ASU clarifies existing guidance related to, among other things, recognizing deferred taxes for goodwill and allocated taxes to members of a consolidated group. The adoption of the new guidance did not have a material impact on our consolidated financial statements. New Accounting Standard Adopted Effective October 1, 2022

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
	Sep. 30, 2022
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. For contracts with retail customers that consume LPG from a metered tank, we recognize revenue as LPG is consumed, at which point we have the right to invoice, and generally invoice monthly based on consumption. 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. 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 services and products provided by Midstream & Marketing’s HVAC business, prior to its sale in September 2020, and AmeriGas Propane’s parts and services business. The performance obligations of these businesses include installation, repair and warranty agreements associated with HVAC equipment and installation services provided for combined heat and power and solar panel installations. For installation and repair goods and 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. For warranty services, revenue is recorded ratably over the warranty period. 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 2022, Fiscal 2021 and Fiscal 2020: 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) 2020 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 563 $ — $ — $ — $ — $ 563 $ — Commercial & Industrial 215 — — — — 215 — Large delivery service 142 — — — — 142 — Off-system sales and capacity releases 48 (45) — — — 93 — Other 14 (2) — — — 16 — Total Utility 982 (47) — — — 1,029 — Non-Utility: LPG: Retail 3,499 — 2,037 1,462 — — — Wholesale 211 — 63 148 — — — Energy Marketing 1,233 (79) — 434 878 — — Midstream: Pipeline 168 — — — 168 — — Peaking 6 (100) — — 106 — — Other 7 — — — 7 — — Electricity Generation 34 — — — 34 — — Other 312 (3) 215 60 40 — — Total Non-Utility 5,470 (182) 2,315 2,104 1,233 — — Total revenues from contracts with customers 6,452 (229) 2,315 2,104 1,233 1,029 — Other revenues (b) 107 (3) 66 23 14 1 6 Total revenues $ 6,559 $ (232) $ 2,381 $ 2,127 $ 1,247 $ 1,030 $ 6 (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, rental revenues from certain 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. 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, 2022 and 2021. 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 $164 and $149 at September 30, 2022 and 2021, respectively, and are primarily included in “Deposits and Advances” on the Consolidated Balance Sheets. Revenues recognized during Fiscal 2022, Fiscal 2021 and Fiscal 2020 from the amount included in contract liabilities at September 30, 2021, September 30, 2020 and September 30, 2019 was $119, $138 and $122, 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, 2022, Midstream & Marketing and Utilities expect to record approximately $2.4 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, 2022
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. During Fiscal 2022, the Company recorded an adjustment to decrease goodwill by $5 primarily reflecting an adjustment to a valuation allowance on certain deferred income taxes. The Consolidated Balance Sheet at September 30, 2022, reflects the final allocation of the purchase price to the assets acquired and liabilities assumed for the Mountaineer Acquisition. The components of the Mountaineer purchase price allocations 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 and Fiscal 2020 . Other Acquisitions During Fiscal 2021, UGI International acquired several LPG retail businesses and an energy marketing business in Europe. During Fiscal 2020, Energy Services acquired GHI, a Houston, Texas-based renewable natural gas company currently doing business in California. Total cash paid and liabilities incurred in connection with these acquisitions were as follows: 2021 2020 UGI International Midstream & Marketing Total cash paid $ 18 $ 16 Liabilities incurred — 7 Total purchase price $ 18 $ 23 Acquisitions of Assets Pennant . As of September 30, 2021, Energy Services held a 47% membership interest in Pennant, a natural gas gathering system located in northeast Ohio and western Pennsylvania. During Fiscal 2022, UGI through its wholly owned indirect subsidiary, Energy Services, completed the Pennant Acquisition in which Energy Services 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 22 for additional information related to the acquired interest in Pennant. Stonehenge . On January 27, 2022, UGI through its wholly owned indirect subsidiary, Energy Services, completed the Stonehenge Acquisition in which Energy Services 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 Conemaugh. In July 2020, Energy Services, through a wholly owned subsidiary, entered into an agreement to sell its approximate 5.97% ownership interest in Conemaugh. As a result, the Company reduced the carrying amount of these assets to their fair values during the third quarter of Fiscal 2020 and recognized a non-cash, pre-tax impairment charge of $52 which amount is reflected in “Loss on disposals of Conemaugh and HVAC” on the 2020 Consolidated Statement of Income. The fair value of such assets was based upon the agreed upon sales price, and was determined to be a Level 2 measurement within the fair value hierarchy. The sale was completed on September 30, 2020. HVAC. In September 2020, Enterprises entered into an agreement to sell its HVAC business. As a result, the Company reduced the carrying amount of these assets to their fair values during the fourth quarter of Fiscal 2020 and recognized a non-cash, pre-tax loss on disposal of $2 which amount is reflected in “Loss on disposals of Conemaugh and HVAC” on the 2020 Consolidated Statement of Income. The fair value of such assets was based upon the agreed upon sales price, and was determined to be a Level 2 measurement within the fair value hierarchy. The sale was completed on September 30, 2020.

Debt

Debt	12 Months Ended
	Sep. 30, 2022
Debt Disclosure [Abstract]
Debt	Note 6 — Debt Significant Financing Activities Since September 30, 2021 Mountaineer Credit Agreement. On October 20, 2022, Mountaineer entered into the Mountaineer 2023 Credit Agreement, as borrower, 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, with an option to extend the maturity date. AmeriGas Propane. On September 28, 2022, AmeriGas Propane entered into the 2022 AmeriGas OLP Credit Agreement, as borrower, with a group of lenders. In connection with the entering into of the 2022 AmeriGas OLP Credit Agreement, the borrower paid off in full and terminated the existing AmeriGas OLP Credit Agreement. The 2022 AmeriGas OLP Credit Agreement provides for borrowings up to $600, including a $100 sublimit for letters of credit. AmeriGas Propane may request an increase in the amount of loan commitments under the 2022 AmeriGas OLP Credit Agreement to a maximum aggregate amount of $900, subject to certain terms and conditions. Borrowings under the 2022 AmeriGas OLP Credit Agreement can be used to fund acquisitions and investments and for general corporate purposes. The 2022 AmeriGas OLP Credit Agreement is scheduled to expire in September 2026. UGI Utilities. On July 12, 2022, UGI Utilities amended the Utilities Term Loan. The amendment extended the maturity date of the loan from October 2022 to July 2027, among other things. The current amount outstanding under the Utilities Term Loan remains unchanged and is payable in quarterly installments of $2, with the balance of the principal being due and payable in full at maturity. We have entered into an interest rate swap that will generally fix the underlying market-based interest rate on this variable-rate loan through June 2026. On June 30, 2022, UGI Utilities entered into a note purchase agreement which provides for the private placement of (1) $90 aggregate principal amount of 4.75% Senior Notes due July 15, 2032 and (2) $85 aggregate principal amount of 4.99% Senior Notes due September 15, 2052. On July 15, 2022, UGI Utilities issued $90 aggregate principal amount of 4.75% Senior Notes pursuant to the note purchase agreement. On September 15, 2022, UGI Utilities issued $85 aggregate principal amount of 4.99% Senior Notes pursuant to the note purchase agreement. The net proceeds from the issuance of the 4.75% Senior Notes and 4.99% Senior Notes were used to reduce short-term borrowings and for general corporate purposes. Mountaineer. On June 30, 2022, Mountaineer entered into a note purchase agreement which provides for the private placement of $40 aggregate principal amount of 4.49% Senior Notes due August 16, 2052. On August 16, 2022, Mountaineer issued $40 aggregate principal amount of 4.49% Senior Notes pursuant to the note purchase agreement. The net proceeds from the issuance of the 4.49% Senior Notes were used to reduce short-term borrowings and for general corporate purposes . UGI International. On December 7, 2021, UGI International, LLC issued, in an underwritten private placement, €400 principal amount of the UGI International 2.50% Senior Notes due December 1, 2029. The UGI International 2.50% Senior Notes rank equal in right of payment with indebtedness issued under the UGI International Credit Facilities Agreement. The net proceeds from the UGI International 2.50% Senior Notes were used (1) to repay all of the UGI International 3.25% Senior Notes due November 1, 2025 and associated fees and expenses and (2) for general corporate purposes. We have designated the UGI International 2.50% Senior Notes as a net investment hedge. In connection with this early repayment of debt, UGI International recognized a pre-tax loss of $11, which is reflected in “Loss on extinguishment of debt” on the Consolidated Statements of Income, and primarily comprises the write-off of unamortized debt issuance costs and early redemption premiums. 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, 2022 and 2021, 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 and its predecessor agreement) 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, 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 % September 30, 2021 AmeriGas OLP (a) December 2022 $ 600 $ 170 $ 60 $ 370 2.58 % 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 $ 130 $ — $ 220 1.35 % Mountaineer (e) November 2024 $ 100 $ 67 $ — $ 33 N.M. UGI Corporation (f) August 2024 $ 300 $ 185 $ — $ 115 3.27 % (a) At September 30, 2022 the 2022 AmeriGas OLP Credit Agreement includes a $100 sublimit for letters of credit. At September 30, 2021 the AmeriGas OLP Credit Agreement included a $150 sublimit for letters of credit. (b) The UGI International Credit Facilities Agreement permits UGI International, LLC to borrow 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. (e) The Mountaineer Credit Agreement includes a $20 sublimit for letters of credit. (f) At September 30, 2022 and 2021, management intended to maintain a substantial portion of amounts outstanding under the 2021 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 and 2021, the Company repaid $87 and $70, respectively, of such borrowings and classified these repayments as “Current maturities of long-term debt” on the Consolidated Balance Sheets. The 2021 UGI Corporation Senior Credit Facility includes a $10 sublimit for letters of credit. N.A. - Not applicable N.M. - Not meaningful Energy Services Receivables Facility. Energy Services has a Receivables Facility with an issuer of receivables-backed commercial paper. On October 21, 2022, the expiration date of the Receivables Facility was extended to October 20, 2023. The Receivables Facility provides Energy Services with the ability to borrow up to $150 of eligible receivables during the period October 21, 2022 to April 30, 2023, and up to $75 of eligible receivables during the period May 1, 2023 to October 20, 2023. 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: 2022 2021 2020 Trade receivables transferred to ESFC during the year $ 2,221 $ 1,353 $ 1,046 ESFC trade receivables sold to the bank during the year $ 152 $ 308 $ 182 ESFC trade receivables - end of year (a) $ 101 $ 61 $ 50 (a) At September 30, 2022 and 2021, there were no ESFC trade receivables sold to the bank. Long-term Debt Long-term debt comprises the following at September 30: 2022 2021 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 675 675 5.75% due May 2027 525 525 Other — 1 Unamortized debt issuance costs (12) (16) Total AmeriGas Propane 2,563 2,560 UGI International: 3.25% Senior Notes due November 2025 — 405 2.50% Senior Notes due December 2029 392 — UGI International, LLC variable-rate term loan due October 2023 (a) 294 347 Other 2 23 Unamortized debt issuance costs (6) (5) Total UGI International 682 770 Midstream & Marketing: Energy Services variable-rate term loan due through August 2026 (b) 677 684 Other 40 42 Unamortized discount and debt issuance costs (7) (10) Total Energy Services 710 716 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 — 4.99% due September 2052 85 — Medium-Term Notes: 6.13% due October 2034 20 20 6.50% due August 2033 20 20 Mountaineer senior notes (c) 201 164 Variable-rate term loan due through July 2027 (d) 95 102 Other 1 1 Unamortized debt issuance costs (6) (6) Total UGI Utilities 1,656 1,451 UGI Corporation: UGI Corporation revolving credit facility maturing August 2024 (e) 252 185 UGI Corporation variable-rate term loan due May 2025 (f) 300 300 UGI Corporation variable-rate term loan due through August 2024 (g) 250 250 UGI Corporation variable-rate term loan due May 2025 (h) 215 215 Unamortized debt issuance costs (2) (5) Total UGI Corporation 1,015 945 Other 6 7 Total long-term debt 6,632 6,449 Less: current maturities (149) (110) Total long-term debt due after one year $ 6,483 $ 6,339 (a) The effective interest rate on the term loan was 1.89% at both September 30, 2022 and 2021. We have entered into pay- fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate on these borrowings. (b) At September 30, 2022 and 2021, the effective interest rates on the term loan were 5.13% and 5.23%, respectively. We have entered into a pay-fixed, receive-variable interest rate swap to effectively fix the underlying variable rate on these borrowings. 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. (c) Total long-term debt at September 30, 2022 and 2021, comprises $180 and $140 principal amount of Mountaineer senior secured notes plus unamortized premium of $21 and $24, respectively. The face interest rates on the Mountaineer senior notes range from 3.50% to 4.49%, with maturities ranging from 2027 to 2052. (d) At September 30, 2022 and 2021, the effective interest rate on this term loan was 3.92% and 4.00%, respectively. We have entered into a pay-fixed, receive-variable interest rate swap to effectively fix the underlying variable rate on these borrowings. Term loan borrowings are due in equal quarterly installments of $2, with the balance of the principal being due in full at maturity. (e) At September 30, 2022 and 2021, the effective interest rates on credit facility borrowings were 5.61% and 3.27%, respectively. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate on a portion of these borrowings. (f) At September 30, 2022 and 2021, the effective interest rates on the term loan was 2.67% and 3.26%, respectively. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate on these borrowings. (g) At September 30, 2022 and 2021, the effective interest rates on the term loan were 4.15% and 3.56%, respectively. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate on a portion of these borrowings. Term loan borrowings are due in equal quarterly installments of $9, commencing December 2022, with the balance of the principal being due in full at maturity. (h) At September 30, 2022 and 2021, the effective interest rates on the term loan were 3.53% and 1.88%. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate on these borrowings. Scheduled principal repayments of long-term debt for each of the next five fiscal years ending September 30 are as follows: 2023 2024 2025 2026 2027 AmeriGas Propane $ — $ 675 $ 700 $ 675 $ 525 UGI International 1 294 — — — Midstream & Marketing 10 7 7 656 — Utilities 7 6 6 281 70 UGI Corporation (a) 125 377 515 — — Other 6 — — — — Total $ 149 $ 1,359 $ 1,228 $ 1,612 $ 595 (a) Subsequent to September 30, 2022 and 2021, the Company repaid $87 and $70, respectively, of borrowings on the UGI Corporation revolving credit facility maturing August 2024. Such repayments are classified as “Current maturities of long-term debt” on the Consolidated Balance Sheets. 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. UGI and its subsidiaries were in compliance with all debt covenants as of September 30, 2022. Restricted Net Assets At September 30, 2022, 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 $2,900.

Income Taxes

Income Taxes	12 Months Ended
	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Income Taxes	Note 7 — Income Taxes Income before income taxes comprises the following: 2022 2021 2020 Domestic $ 362 $ 647 $ 424 Foreign 1,025 1,342 243 Total income before income taxes $ 1,387 $ 1,989 $ 667 The provisions for income taxes consist of the following: 2022 2021 2020 Current expense (benefit): Federal $ 24 $ (48) $ (85) State 18 7 4 Foreign 50 85 70 Total current expense (benefit) 92 44 (11) Deferred expense (benefit): Federal 45 168 135 State (17) 48 19 Foreign 193 262 (8) Total deferred expense 221 478 146 Total income tax expense $ 313 $ 522 $ 135 Federal income taxes for Fiscal 2022 are net of foreign tax credits of $5. There were none utilized in Fiscal 2021 or Fiscal 2020. A reconciliation from the U.S. federal statutory tax rate to our effective tax rate is as follows: 2022 2021 2020 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % Difference in tax rate due to: Effects of U.S. tax legislation — (0.8) (4.7) Effects of tax rate changes - International (2.3) (1.3) 0.3 Effects of tax rate changes – State, net of federal benefit (1.4) — — State income taxes, net of federal benefit 1.5 1.9 2.8 Valuation allowance adjustments (0.5) 1.0 — Effects of foreign operations 4.4 4.6 1.3 Excess tax benefits on share-based payments (0.3) (0.1) (0.2) Other, net 0.2 (0.1) (0.3) Effective tax rate 22.6 % 26.2 % 20.2 % 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 a $20 benefit being recorded in Fiscal 2022 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 and Fiscal 2020 to be carried back to Fiscal 2016 and Fiscal 2015. The carryback of our Fiscal 2021 and Fiscal 2020 U.S. federal tax losses from a 21% rate environment to offset taxable income in Fiscal 2016 and Fiscal 2015 in a 35% rate environment generated incremental benefits of $15 and $32, respectively. A $90 refund claim for the Fiscal 2020 carryback to Fiscal 2015 was filed and has been approved by the IRS, though the actual cash refund was not received in Fiscal 2022. Of the outstanding $90 refund, $75 was received subsequent to Fiscal 2022. A $37 refund claim for the Fiscal 2021 claim has been filed. Both are included in “Income taxes receivable” on the Consolidated Balance Sheet at September 30, 2022 and 2021. On July 20, 2020, the Treasury Department issued final regulations under IRC Section 951A permitting a taxpayer to elect to exclude, from its inclusion of GILTI, income subject to a high effective rate of foreign tax. The impact of these final regulations reduced U.S. tax of foreign source income in Fiscal 2022, Fiscal 2021, and Fiscal 2020. 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 2022, Fiscal 2021 and Fiscal 2020 includes $3, $8 and $0, 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 2022, Fiscal 2021 and Fiscal 2020, the beneficial effects of state tax flow through of accelerated depreciation reduced income tax expense by $10, $9, and $11, respectively. Deferred tax liabilities (assets) comprise the following at September 30: 2022 2021 Excess book basis over tax basis of property, plant and equipment $ 867 $ 937 Utility regulatory assets 106 105 Intangible assets and goodwill 75 77 Derivative instrument assets 514 322 Other 33 36 Gross deferred tax liabilities 1,595 1,477 Investment in AmeriGas Partners (79) (102) Pension plan liabilities (21) (29) Employee-related benefits (38) (45) Operating loss carryforwards (48) (53) Foreign tax credit carryforwards (76) (79) Utility regulatory liabilities (85) (102) Utility environmental liabilities (15) (16) Other (125) (107) Gross deferred tax assets (487) (533) Deferred tax assets valuation allowance 141 138 Net deferred tax liabilities $ 1,249 $ 1,082 At September 30, 2022, we carried foreign net operating loss carryforwards of $5 relating to Flaga, $30 at certain subsidiaries of UGI France, and $10 in the Netherlands with no expiration dates. We have state net operating loss carryforwards primarily relating to certain subsidiaries that approximate $787 and expire through 2042. We also have federal operating loss carryforwards of $16 for Mountaintop Energy Holdings, LLC and $6 for certain operations of AmeriGas Propane. At September 30, 2022, deferred tax assets relating to operating loss carryforwards amounted to $48 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 assets increased by $3 in Fiscal 2022, which included a $17 increase in a notional interest deduction carryover, a $4 decrease from state tax rate changes, offset by a release of $6 against FTCs, that will be realizable in the future and a $4 decrease related to foreign net operating loss carry forwards. The valuation allowance for all deferred tax assets increased by $33 in Fiscal 2021, which included a $30 increase related to future capital losses from the PennEast and Hudson investments, and a $10 increase in a notional interest deduction carryover, partially offset by the release of $10 against FTCs. We conduct business and file tax returns in the U.S., numerous states, local jurisdictions and in France and certain other European countries. Our U.S. federal income tax returns are settled through the 2018 tax year, our French tax returns are settled through the 2018 tax year, our Austrian tax returns are settled through 2017 and our other European tax returns are effectively settled for various years from 2014 to 2019. 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 $4, $4, and $4 at September 30, 2022, 2021 and 2020, respectively. Activity related to these unrecognized tax benefits was not material for all periods presented.

Employee Retirement Plans

Employee Retirement Plans	12 Months Ended
	Sep. 30, 2022
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 substantially all Mountaineer employees. 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 $22 and $31 as of September 30, 2022 and 2021, respectively. The fair value of the plan assets of our other postretirement benefit plans was $16 and $19 as of September 30, 2022 and 2021, 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, 2022 and 2021. 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 2022 2021 Change in benefit obligations: Benefit obligations — beginning of year $ 870 $ 782 Service cost 16 12 Interest cost 26 22 Actuarial gain (240) (30) Plan amendments 1 2 Acquisitions — 114 Foreign currency (6) (1) Benefits paid (34) (31) Pension Benefits 2022 2021 Benefit obligations — end of year (a) $ 633 $ 870 Change in plan assets: Fair value of plan assets — beginning of year $ 736 $ 585 Actual (loss) gain on plan assets (173) 75 Foreign currency (3) — Employer contributions 15 14 Acquisitions — 92 Benefits paid (34) (30) Fair value of plan assets — end of year $ 541 $ 736 Funded status of the plans — end of year (b) $ (92) $ (134) Amounts recorded in UGI Corporation stockholders’ equity (pre-tax): Prior service cost $ 3 $ 3 Net actuarial (gain) loss (17) 13 Total $ (14) $ 16 Amounts recorded in regulatory assets and liabilities (pre-tax): Net actuarial loss 114 108 Total $ 114 $ 108 (a) The ABO for the U.S. Pension Plans was $570 and $756 as of September 30, 2022 and 2021, 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 2022 and Fiscal 2021, the change in the pension plans’ PBO due to actuarial gains and losses 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 2022 2021 2020 Weighted-average assumptions: Discount rate – benefit obligations 5.70 % 3.13 % 2.90 % Discount rate – benefit cost 3.13 % 2.90 % 3.30 % Expected return on plan assets 7.10 % 7.10 % 7.20 % 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 income (expense), net” on the Consolidated Statements of Income. Other postretirement benefit cost was not material for all periods presented. Net periodic pension cost includes the following components: Pension Benefits 2022 2021 2020 Service cost $ 16 $ 12 $ 11 Interest cost 26 22 23 Expected return on assets (50) (40) (38) Curtailment gain — — (1) Amortization of: Prior service cost — — 1 Actuarial loss 7 14 15 Net benefit (income) cost $ (1) $ 8 $ 11 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 2022, Fiscal 2021 and Fiscal 2020, we made cash contributions to the U.S. Pension Plans of $14, $13 and $13, respectively. The minimum required contributions in Fiscal 2023 are not expected to be material. 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 2023. Expected payments for postretirement benefits over the next 10 years are not material. Expected payments for pension benefits are as follows: Pension Fiscal 2023 $ 37 Fiscal 2024 $ 38 Fiscal 2025 $ 40 Fiscal 2026 $ 41 Fiscal 2027 $ 43 Fiscal 2028 - 2032 $ 229 We also sponsor unfunded and non-qualified supplemental executive defined benefit retirement plans. At September 30, 2022 and 2021, the PBOs of these plans, including obligations for amounts held in grantor trusts, totaled $44 and $57, respectively. Costs associated with these plans were not material for all periods presented and are excluded from the tables above. Amounts recorded in UGI’s stockholders’ equity for these plans include pre-tax losses of $1 and $10 at September 30, 2022 and 2021, respectively, principally representing unrecognized actuarial losses. In Fiscal 2023, the estimated amount that will be amortized from such pre-tax actuarial losses into retiree benefit cost is not material. During Fiscal 2021, the Company made $12 of payments for the supplemental executive defined benefit retirement plans. During Fiscal 2022 and Fiscal 2020, the payments the Company made with respect to the supplemental executive defined benefit retirement plans were not material. 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 $31 and $44 at September 30, 2022 and 2021, 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) 2022 2021 2022 2021 Equity investments: U.S. equities 26.5 % 22.2 % 24.7 % 25.3 % Non-U.S. equities 20.9 % 21.7 % 20.9 % 21.4 % Global equities (a) 13.8 % 16.0 % 13.1 % 13.1 % Total 61.2 % 59.9 % 58.7 % 59.8 % Fixed income funds & cash equivalents 35.5 % 36.4 % 35.0 % 34.4 % Alternative investments 3.3 % 3.7 % 6.3 % 5.8 % 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, 2022 and 2021 are as follows: 2022 2021 U.S. Pension Plans: Domestic equity investments: UGI Corporation Common Stock $ 26 $ 35 Total domestic equity investments (a) 26 35 Common collective trust funds: U.S. equity index investments 113 124 Non-U.S. equity index investments 110 155 Global equity index investments 72 115 Bond index investments 177 254 Cash equivalents 10 7 Total common collective trust funds (b) 482 655 Alternative investments (b) 17 27 Total $ 525 $ 717 (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 $21 in Fiscal 2022, $21 in Fiscal 2021 and $21 in Fiscal 2020. 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 2022, Fiscal 2021 and Fiscal 2020 were not material. At September 30, 2022 and 2021, the total fair values of these grantor trust investment assets, which amounts are included in “Other assets” on the Consolidated Balance Sheets, were $7 and $9, respectively.

Utility Regulatory Assets and L

Utility Regulatory Assets and Liabilities and Regulatory Matters	12 Months Ended
	Sep. 30, 2022
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: 2022 2021 Regulatory assets (a): Income taxes recoverable $ 83 $ 143 Underfunded pension plans 114 108 Environmental costs 37 58 Deferred fuel and power costs 32 11 Removal costs, net 22 24 Other 52 53 Total regulatory assets $ 340 $ 397 Regulatory liabilities (a): Postretirement benefits $ 11 $ 13 Deferred fuel and power refunds 3 36 State income tax benefits — distribution system repairs 38 32 Excess federal deferred income taxes 279 287 Other 4 20 Total regulatory liabilities $ 335 $ 388 (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. The decrease in income taxes recoverable at September 30, 2022 reflects the impact on deferred Pennsylvania corporate income taxes resulting from changes in Pennsylvania corporate income tax rates for future years signed into law on July 8, 2022 (See Note 7). 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 17. 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. PA Gas Utility uses derivative instruments to reduce volatility in the cost of gas it purchases for retail core-market customers. Realized and unrealized gains or losses on natural gas derivative instruments are included in deferred fuel and power costs or refunds. Net unrealized gains on such contracts at September 30, 2022 and 2021 were $5 and $35, 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, incremental expenses attributable to the COVID-19 pandemic, certain information technology costs, energy efficiency conservation costs and rate case expenses. Other Regulatory Matters Base Rate Filings. 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 is authorized to implement a weather normalization adjustment rider as a 5-year pilot program beginning on the effective date of the new rates. Under this rider, customer billings for distribution services will be adjusted monthly to reflect normal weather conditions if weather deviates more than 3% from normal. Additionally, under the terms of the final order, PA Gas Utility will be authorized to implement a DSIC once its total property, plant and equipment less accumulated depreciation reaches $3,368 (which threshold was achieved in September 2022). On February 8, 2021, Electric Utility filed a rate 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.

Inventories

Inventories	12 Months Ended
	Sep. 30, 2022
Inventory Disclosure [Abstract]
Inventories	Note 10 — Inventories Inventories comprise the following at September 30: 2022 2021 Non-utility LPG and natural gas $ 335 $ 278 Gas Utility natural gas 166 68 Energy certificates 70 53 Materials, supplies and other 94 70 Total inventories $ 665 $ 469

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Sep. 30, 2022
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: 2022 2021 Estimated Useful Life Utility: Distribution $ 4,746 $ 4,306 Transmission 123 111 General and other 557 507 Work in process 124 98 Total Utility 5,550 5,022 Non-utility: Land 179 186 Buildings and improvements 426 436 10 - 40 years Transportation equipment 234 232 3 - 10 years Equipment, primarily cylinders and tanks 3,645 3,785 5 - 30 years Electric generation 216 211 25 - 40 years Pipeline and related assets 1,523 1,218 25 - 40 years Other 380 342 1 - 12 years Work in process 53 76 Total non-utility 6,656 6,486 Total property, plant and equipment $ 12,206 $ 11,508 The average composite depreciation rates at our Gas Utility and Electric Utility were as follows: 2022 2021 2020 Regulated natural gas utilities 2.6 % 2.6 % 2.5 % Electric Utility 2.4 % 2.3 % 2.2 % Depreciation expense totaled $460, $437 and $416 for Fiscal 2022, Fiscal 2021 and Fiscal 2020, respectively.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Sep. 30, 2022
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, 2020 $ 2,004 $ 997 $ 335 $ 182 $ 3,518 Acquisitions — 6 — 255 261 Purchase accounting adjustments — — 1 — 1 Foreign currency translation — (10) — — (10) 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 Intangible assets comprise the following at September 30: 2022 2021 Customer relationships $ 1,006 $ 1,054 Trademarks and tradenames 11 12 Noncompete agreements and other 71 75 Accumulated amortization (629) (607) Intangible assets, net (definite-lived) 459 534 Trademarks and tradenames (indefinite-lived) 41 49 Total intangible assets, net $ 500 $ 583 Changes in amounts above include the effects of currency translation. During the fourth quarter of Fiscal 2021, the Company recognized a $20 non-cash, pre-tax impairment charge related to a customer relationship intangible at DVEP resulting from a decline in anticipated volumes attributable to a historical customer. The charge is reflected in “Operating and administrative expenses” on the Consolidated Statements of Income. Amortization expense of intangible assets was $61, $76 and $83 for Fiscal 2022, Fiscal 2021 and Fiscal 2020, respectively. Estimated amortization expense of intangible assets during the next five fiscal years is as follows: Fiscal 2023 — $54; Fiscal 2024 — $53; Fiscal 2025 — $52; Fiscal 2026 — $51; Fiscal 2027 — $29.

Equity

Equity	12 Months Ended
	Sep. 30, 2022
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 2022 and Fiscal 2020 the Company purchased and placed in treasury stock 900,000 shares and 950,000 shares at a total cost of $38 and $38, respectively. There were no such repurchases during Fiscal 2021. UGI Preferred Stock and Common Stock share activity for Fiscal 2022, Fiscal 2021 and Fiscal 2020 is as follows: Preferred Stock Common Stock Issued/Outstanding Issued Treasury Outstanding Balance at September 30, 2019 — 209,304,129 (299,340) 209,004,789 Issued: Employee and director plans — 209,915 180,050 389,965 Repurchases of common stock — — (950,000) (950,000) Reacquired common stock – employee and director plans — — (90,316) (90,316) 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 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 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, 2022 or 2021. 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, 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 2022 and Fiscal 2021.

Equity-Based Compensation

Equity-Based Compensation	12 Months Ended
	Sep. 30, 2022
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 $15 ($11 after-tax), $21 ($15 after-tax) and $15 ($11 after-tax) in Fiscal 2022, Fiscal 2021 and Fiscal 2020, 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 were 18,015,916 shares of Common Stock available for future grants under the 2021 IAP at September 30, 2022 . 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 was $8.47, $6.05 and $5.58 in Fiscal 2022, Fiscal 2021 and Fiscal 2020, respectively. As of September 30, 2022, there was $5 of unrecognized compensation cost associated with unvested stock options that is expected to be recognized over a weighted-average period of 1.8 years. There were 9,004,896 stock options outstanding at September 30, 2022, of which, 7,179,583 stock options were exercisable with a weighted-average option price of $42.23. UGI Unit Awards . UGI Stock Unit and UGI Performance Unit awards entitle the grantee to shares of UGI Common Stock or cash once the service condition is met and, with respect to UGI Performance Unit awards, subject to market performance conditions. UGI Performance Unit grant recipients are awarded a target number of UGI Performance Units. The number of UGI Performance Units ultimately paid at the end of the performance period (generally three years) may be higher or lower than the target amount, or even zero, based on UGI’s TSR percentile rank relative to the UGI comparator group. Grantees may receive 0% to 200% of the target award granted. 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 weighted-average grant date fair value of UGI Stock Units and UGI Performance Units granted to employees during Fiscal 2022, Fiscal 2021, and Fiscal 2020 was $51.24, $41.41 and $41.47, respectively. As of September 30, 2022, there was a total of $24 unrecognized compensation cost associated with UGI Unit awards outstanding that is expected to be recognized over a weighted-average period of 2.0 years. As of September 30, 2022, there were 1,376,371 UGI Unit awards outstanding with a weighted-average grant-date fair value of $42.31 per share.

Partnership Distributions

Partnership Distributions	12 Months Ended
	Sep. 30, 2022
Distributions Made to Members or Limited Partners [Abstract]
Partnership Distributions	Note 15 — Partnership Distributions In accordance with the Partnership Agreement, the Partnership makes distributions to its partners approximately 45 days after the end of each fiscal quarter in a total amount equal to its Available Cash (as defined in the Partnership Agreement) for such quarter. The General Partner may establish reserves for the proper conduct of the Partnership’s business and for distributions during the next four quarters.

Leases

Leases	12 Months Ended
	Sep. 30, 2022
Leases [Abstract]
Leases	Note 16 — 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. ROU assets and lease liabilities recorded in the Consolidated Balance Sheets as of September 30 are as follows: 2022 2021 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 368 $ 390 Other assets Finance lease ROU assets 48 49 Property, plant and equipment Total ROU assets $ 416 $ 439 Lease liabilities: Operating lease liabilities — current $ 82 $ 81 Other current liabilities Operating lease liabilities — noncurrent 294 318 Other noncurrent liabilities Finance lease liabilities — current 4 4 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 41 Long-term debt Total lease liabilities $ 421 $ 444 The components of lease cost for Fiscal 2022, Fiscal 2021 and Fiscal 2020 are as follows: 2022 2021 2020 Operating lease cost $ 96 $ 101 $ 102 Finance lease cost: Amortization of ROU assets 4 4 5 Interest on lease liabilities 3 3 3 Variable lease cost 6 4 5 Short-term lease cost 2 2 3 Total lease cost $ 111 $ 114 $ 118 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statements of Cash Flows during Fiscal 2022, Fiscal 2021 and Fiscal 2020: 2022 2021 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 95 $ 99 $ 103 Operating cash flows — finance leases $ 3 $ 3 $ 3 Financing cash flows — finance leases $ 2 $ 3 $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (a) $ 72 $ 85 $ 506 ROU assets obtained in exchange for finance lease liabilities $ 2 $ 1 $ 22 (a) Fiscal 2020 includes the impact of the adoption of ASC 842 – Leases . The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2022 2021 Operating leases 6.0 6.3 Finance leases 3.7 2.4 Weighted-average discount rate (%) 2022 2021 Operating leases 3.6% 3.6% Finance leases 1.8% 1.5% 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, 2022, were as follows: 2023 2024 2025 2026 2027 After 2027 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 93 $ 81 $ 64 $ 52 $ 41 $ 86 $ 417 $ (41) $ 376 Finance leases $ 4 $ 4 $ 4 $ 4 $ 3 $ 77 $ 96 $ (51) $ 45 Approximately 85% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2022, operating and finance leases that had not yet commenced were not material. Lessor
Leases	Note 16 — 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. ROU assets and lease liabilities recorded in the Consolidated Balance Sheets as of September 30 are as follows: 2022 2021 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 368 $ 390 Other assets Finance lease ROU assets 48 49 Property, plant and equipment Total ROU assets $ 416 $ 439 Lease liabilities: Operating lease liabilities — current $ 82 $ 81 Other current liabilities Operating lease liabilities — noncurrent 294 318 Other noncurrent liabilities Finance lease liabilities — current 4 4 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 41 Long-term debt Total lease liabilities $ 421 $ 444 The components of lease cost for Fiscal 2022, Fiscal 2021 and Fiscal 2020 are as follows: 2022 2021 2020 Operating lease cost $ 96 $ 101 $ 102 Finance lease cost: Amortization of ROU assets 4 4 5 Interest on lease liabilities 3 3 3 Variable lease cost 6 4 5 Short-term lease cost 2 2 3 Total lease cost $ 111 $ 114 $ 118 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statements of Cash Flows during Fiscal 2022, Fiscal 2021 and Fiscal 2020: 2022 2021 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 95 $ 99 $ 103 Operating cash flows — finance leases $ 3 $ 3 $ 3 Financing cash flows — finance leases $ 2 $ 3 $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (a) $ 72 $ 85 $ 506 ROU assets obtained in exchange for finance lease liabilities $ 2 $ 1 $ 22 (a) Fiscal 2020 includes the impact of the adoption of ASC 842 – Leases . The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2022 2021 Operating leases 6.0 6.3 Finance leases 3.7 2.4 Weighted-average discount rate (%) 2022 2021 Operating leases 3.6% 3.6% Finance leases 1.8% 1.5% 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, 2022, were as follows: 2023 2024 2025 2026 2027 After 2027 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 93 $ 81 $ 64 $ 52 $ 41 $ 86 $ 417 $ (41) $ 376 Finance leases $ 4 $ 4 $ 4 $ 4 $ 3 $ 77 $ 96 $ (51) $ 45 Approximately 85% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2022, operating and finance leases that had not yet commenced were not material. Lessor
Leases	Note 16 — 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. ROU assets and lease liabilities recorded in the Consolidated Balance Sheets as of September 30 are as follows: 2022 2021 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 368 $ 390 Other assets Finance lease ROU assets 48 49 Property, plant and equipment Total ROU assets $ 416 $ 439 Lease liabilities: Operating lease liabilities — current $ 82 $ 81 Other current liabilities Operating lease liabilities — noncurrent 294 318 Other noncurrent liabilities Finance lease liabilities — current 4 4 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 41 Long-term debt Total lease liabilities $ 421 $ 444 The components of lease cost for Fiscal 2022, Fiscal 2021 and Fiscal 2020 are as follows: 2022 2021 2020 Operating lease cost $ 96 $ 101 $ 102 Finance lease cost: Amortization of ROU assets 4 4 5 Interest on lease liabilities 3 3 3 Variable lease cost 6 4 5 Short-term lease cost 2 2 3 Total lease cost $ 111 $ 114 $ 118 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statements of Cash Flows during Fiscal 2022, Fiscal 2021 and Fiscal 2020: 2022 2021 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 95 $ 99 $ 103 Operating cash flows — finance leases $ 3 $ 3 $ 3 Financing cash flows — finance leases $ 2 $ 3 $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (a) $ 72 $ 85 $ 506 ROU assets obtained in exchange for finance lease liabilities $ 2 $ 1 $ 22 (a) Fiscal 2020 includes the impact of the adoption of ASC 842 – Leases . The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2022 2021 Operating leases 6.0 6.3 Finance leases 3.7 2.4 Weighted-average discount rate (%) 2022 2021 Operating leases 3.6% 3.6% Finance leases 1.8% 1.5% 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, 2022, were as follows: 2023 2024 2025 2026 2027 After 2027 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 93 $ 81 $ 64 $ 52 $ 41 $ 86 $ 417 $ (41) $ 376 Finance leases $ 4 $ 4 $ 4 $ 4 $ 3 $ 77 $ 96 $ (51) $ 45 Approximately 85% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2022, operating and finance leases that had not yet commenced were not material. Lessor

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Sep. 30, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 17 — 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, 2022 and 2021, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the current COA and the predecessor agreements totaled $53 and $50, 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, 2022 and 2021, 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. Although we cannot predict the final results of these pending claims and legal actions, we believe, after consultation with counsel, that the final outcome of these matters 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, 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, 2022
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 18 — 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, 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 September 30, 2021 Derivative instruments: Assets: Commodity contracts $ 641 $ 1,008 $ — $ 1,649 Foreign currency contracts $ — $ 38 $ — $ 38 Liabilities: Commodity contracts $ (264) $ (16) $ — $ (280) Foreign currency contracts $ — $ (8) $ — $ (8) Interest rate contracts $ — $ (29) $ — $ (29) Non-qualified supplemental postretirement grantor trust investments (a) $ 53 $ — $ — $ 53 (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 held-for-sale associated with the October 2022 sale of the United Kingdom energy marketing business (see Note 25). 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 Level 3 measurements reflect natural gas commodity contracts attributable to our UGI International operations. The fair values of these contracts have been determined using unobservable inputs in an illiquid market, and the fair values of such Level 3 measurements ranged from $7 to $27 given the available inputs considered. The actual realized value at which these contracts will settle could vary significantly compared to the fair values reflected at September 30, 2022. The fair values of investments held in grantor trusts are derived from quoted market prices as substantially all of the investments in these trusts have active markets. Other Financial Instruments The carrying amounts of other financial instruments included in current assets and current liabilities (except for current maturities of long-term debt) approximate their fair values because of their short-term nature. We estimate the fair value of long-term debt by using current market rates and by discounting future cash flows using rates available for similar type debt (Level 2). The carrying amounts and estimated fair values of our long-term debt (including current maturities but excluding unamortized debt issuance costs) were as follows: 2022 2021 Carrying amount $ 6,665 $ 6,491 Estimated fair value $ 6,189 $ 6,996

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Sep. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Note 19 — 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 summarizes the types of derivative instruments used by the Company to manage certain 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. 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, 2022, the amount of pre-tax net losses associated with interest rate hedges (excluding pay-fixed, receive-variable interest rate swaps) expected to be reclassified into earnings during the next twelve months is $3. 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 a multi-year period to eventually equal approximately 90% of anticipated UGI International foreign currency earnings before income taxes. Because these contracts are not designated as hedging instruments, realized and unrealized gains and losses on these contracts are recorded in “Other non-operating income (expense), net” on the 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 transactions are included in cash flows from investing activities on the Consolidated Statements of Cash Flows. We recognized pre-tax gains associated with net investment hedges in the foreign currency component of AOCI totaling $69 during Fiscal 2022. Our euro-denominated long-term debt has also been designated as net investment hedges, representing a portion of our UGI International euro-denominated net investment. We recognized pre-tax gains (losses) associated with these net investment hedges in the foreign currency component of AOCI totaling $123, $9 and $(53) during Fiscal 2022, Fiscal 2021, and Fiscal 2020, 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, 2022 and 2021 and the final settlement dates of the Company's open derivative contracts as of September 30, 2022, (including amounts associated with our energy marketing businesses in the United Kingdom and France (Note 25)) but excluding those derivatives that qualified for the NPNS exception: Notional Amounts September 30, Type Units Settlements Extending Through 2022 2021 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms October 2023 19 20 Non-utility Operations LPG swaps Gallons January 2025 874 708 Natural gas futures, forward, basis swap, options and pipeline contracts Dekatherms October 2026 363 355 Electricity forward and futures contracts Kilowatt hours December 2026 2,446 4,302 Interest Rate Risk: Interest rate swaps Euro October 2022 € 300 € 300 Interest rate swaps USD June 2026 $ 1,358 $ 1,421 Foreign Currency Exchange Rate Risk: Forward foreign exchange contracts USD August 2025 $ 465 $ 509 Net investment hedge forward foreign exchange contracts Euro December 2026 € 411 € 173 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, 2022, 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 $2,418. 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, 2022, we had received cash collateral from derivative instrument counterparties totaling $398. 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, 2022, 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: 2022 2021 Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 57 $ 20 Interest rate contracts 66 — 123 20 Derivatives subject to PGC and DS mechanisms: Commodity contracts 31 58 Derivatives not designated as hedging instruments: Commodity contracts (a) 2,202 1,591 Foreign currency contracts 62 18 2,264 1,609 Total derivative assets – gross 2,418 1,687 Gross amounts offset in the balance sheet (295) (216) Cash collateral received (398) (468) Total derivative assets – net $ 1,725 $ 1,003 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts $ — $ (29) Derivatives subject to PGC and DS mechanisms: Commodity contracts (26) (23) Derivatives not designated as hedging instruments: Commodity contracts (a) (487) (257) Foreign currency contracts (2) (8) (489) (265) Total derivative liabilities – gross (515) (317) Gross amounts offset in the balance sheet 295 216 Cash collateral pledged 7 3 Total derivative liabilities – net $ (213) $ (98) (a) Includes derivative assets and liabilities held-for-sale associated with the October 2022 sale of the United Kingdom energy marketing business (see Note 25). 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 2022, Fiscal 2021 and Fiscal 2020: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from 2022 2021 2020 2022 2021 2020 Cash Flow Hedges: Interest rate contracts 91 4 (53) (7) (25) (13) Interest expense Net Investment Hedges: Foreign currency contracts $ 69 $ 4 $ (1) Gain (Loss) Location of 2022 2021 2020 Derivatives Not Designated as Hedging Instruments: Commodity contracts $ (9) $ (17) $ 10 Revenues Commodity contracts 1,181 1,545 (32) Cost of sales Commodity contracts 1 5 — Other operating income, net Foreign currency contracts 63 9 (20) Other non-operating income (expense), net Total $ 1,236 $ 1,542 $ (42) 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 the contract is 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, 2022
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	Note 20 — 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 2022, Fiscal 2021 and Fiscal 2020: Postretirement Derivative Foreign Total AOCI - September 30, 2019 $ (26) $ (25) $ (166) $ (217) Other comprehensive (loss) income before reclassification adjustments (3) (38) 99 58 Amounts reclassified from AOCI 3 9 — 12 Other comprehensive (loss) income attributable to UGI — (29) 99 70 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 Operating Income, Net and

Other Operating Income, Net and Other Non-Operating Income (Expense), Net	12 Months Ended
	Sep. 30, 2022
Component of Operating Income [Abstract]
Other Operating Income, Net and Other Non-Operating (Expense) Income, Net	Note 21 — Other Operating Income, Net and Other Non-Operating Income (Expense), Net Other Operating Income, Net Other operating income, net, comprises the following: 2022 2021 2020 Finance charges $ 18 $ 17 $ 9 Gains on sales of fixed assets, net 33 11 5 Gain on early derivative termination — 5 — Interest and interest-related income 1 — 2 Other, net 27 — 5 Total other operating income, net $ 79 $ 33 $ 21 Other Non-Operating Income (Expense), Net Other non-operating income (expense), net comprises the following: 2022 2021 2020 Gains (losses) on foreign currency contracts, net $ 63 $ 9 $ (20) Amortization of excluded components of certain net investment hedges 7 2 — Pension and other postretirement plans non-service income, net 5 1 — Total other non-operating income (expense), net $ 75 $ 12 $ (20)

Equity Method Investments

Equity Method Investments	12 Months Ended
	Sep. 30, 2022
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Note 22 — Equity Method Investments During Fiscal 2022 and Fiscal 2021, the Company’s principal equity method investments comprised Pine Run, Pennant and PennEast which are reflected in our Midstream and Marketing Segment. Our equity method investments are included within “Other assets” on the Consolidated Balance Sheets and totaled $130 and $174 at September 30, 2022 and 2021, respectively. Pine Run. The Company has an approximately 49% interest in Pine Run, a company jointly owned by Stonehenge Energy Resources and UGI Pine Run, LLC. 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. The carrying value of our investment in Pine Run at September 30, 2022 and 2021 was $68 and $60, respectively. Pennant . As of September 30, 2021, Energy Services held a 47% membership interest in Pennant, a natural gas gathering system located in northeast Ohio and western Pennsylvania. In Fiscal 2022, relating to the Company’s acquisition of a controlling interest in Pennant, the Company recognized an other-than-temporary pre-tax impairment charge of $44 related to its 47% membership interest, which was recorded in “(Loss) income from equity investees” in the Consolidated Statements of Income. The Company acquired the outstanding interest in Pennant d uring the fourth quarter of Fiscal 2022. See Note 5 for additional information related to the acquired interest in Pennant. The carrying value of our investment in Pennant at September 30, 2021 was $93. PennEast . UGI PennEast, LLC and four other members comprising wholly owned subsidiaries of Southern Company, New Jersey Resources, South Jersey Industries, and Enbridge, Inc., 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. In September 2019, a panel of the U.S. Court of Appeals for the Third Circuit ruled that New Jersey’s Eleventh Amendment immunity barred PennEast from bringing an eminent domain lawsuit in federal court, under the Natural Gas Act, against New Jersey or its agencies. On February 3, 2021, the U.S. Supreme Court issued an order granting PennEast’s petition for a writ of certiorari and the case was argued on April 28, 2021. On June 29, 2021, the U.S. Supreme Court ruled in favor of PennEast, overturning the Third Circuit’s decision that blocked PennEast from exercising federal eminent domain authority over lands in which a state has property rights interests. Following the favorable Supreme Court decision, 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 the 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 recorded in “(Loss) income from equity investees” in the Consolidated Statements of Income. On September 27, 2021, the PennEast partners announced that further development of the project is no longer supported. Following this announcement, the estimated fair value was assessed using the liquidation value of equipment held by PennEast and did not result in a significant change compared to June 30, 2021 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, 2022 and 2021 was not material. Other Equity Investment s. Our other equity investments totaled $62 and $21 at September 30, 2022 and 2021, respectively, and principally comprise investments in biomass and other renewable energy projects at Midstream and Marketing and, in Fiscal 2022, an investment in a renewable energy joint venture at UGI International.

Segment Information

Segment Information	12 Months Ended
	Sep. 30, 2022
Segment Reporting [Abstract]
Segment Information	Note 23 — 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 natural gas marketing businesses in France, Belgium and the United Kingdom and a natural gas and electricity marketing business in the Netherlands. See Note 25 for additional information regarding the October 2022 sale of the United Kingdom energy marketing business and the November 2022 announcement related to the France 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, 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., and, prior to its sale on September 30, 2020, also from contracting services provided by HVAC to customers in portions of eastern and central Pennsylvania (see Note 5). 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 & 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 $ — Total Elim- AmeriGas UGI International Midstream Utilities Corporate & 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 $ — $ — 2020 Revenues from external customers $ 6,559 $ — $ 2,381 $ 2,127 $ 1,065 $ 983 $ 3 Intersegment revenues $ — $ (232) (b) $ — $ — $ 182 $ 47 $ 3 Cost of sales $ 3,149 $ (229) (b) $ 960 $ 1,191 $ 892 $ 448 $ (113) Operating income (loss) $ 982 $ — $ 373 $ 241 $ 140 $ 229 $ (1) Income from equity investees 27 — — — 27 — — Other non-operating (expense) income, net (20) — — 18 1 — (39) Earnings (loss) before interest expense and income taxes 989 — 373 259 168 229 (40) Interest expense (322) — (164) (31) (42) (54) (31) Income tax (expense) benefit (135) — (53) (55) (34) (39) 46 Net income (loss) attributable to UGI $ 532 $ — $ 156 $ 173 $ 92 $ 136 $ (25) Depreciation and amortization $ 484 $ — $ 178 $ 125 $ 75 $ 105 $ 1 Total assets $ 13,985 $ (282) $ 4,327 $ 3,123 $ 2,775 $ 3,809 $ 233 Short-term borrowings $ 347 $ — $ 186 $ 1 $ 19 $ 141 $ — Capital expenditures (including the effects of accruals) $ 665 $ — $ 135 $ 89 $ 93 $ 348 $ — Investments in equity investees $ 200 $ — $ — $ 10 $ 190 $ — $ — (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 2022, Fiscal 2021 and Fiscal 2020: Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing 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 $ (21) $ (9) $ (1) Loss on extinguishment of debt Loss on extinguishments of debt $ — $ (11) $ — Unrealized gains on foreign currency derivative instruments Other non-operating income (expense), net $ — $ 50 $ — Impairments of certain equity method investments and assets Operating and administrative expenses; (Loss) income from equity investees, respectively $ — $ (5) $ (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 losses on foreign currency derivative instruments Other non-operating income (expense), 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 (Loss) income from equity investees $ — $ — $ (93) 2020 Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ 3 Net gains on commodity derivative instruments not associated with current-period transactions Cost of Sales $ 72 $ — $ 42 Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (36) $ — Acquisition and integration expenses associated with the CMG Acquisition Operating and administrative expenses $ — $ — $ (2) Business transformation expenses Operating and administrative expenses $ (44) $ (18) $ — Loss on disposals of Conemaugh and HVAC Loss on disposals of Conemaugh and HVAC $ — $ — $ (54) (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, Utilities and AmeriGas Propane.

Business Transformation Initiat

Business Transformation Initiatives	12 Months Ended
	Sep. 30, 2022
Restructuring and Related Activities [Abstract]
Business Transformation Initiatives	Note 24 — Business Transformation Initiatives AmeriGas 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- Operating and administrative expenses Operating and administrative expenses

Subsequent Events

Subsequent Events	12 Months Ended
	Sep. 30, 2022
Subsequent Events [Abstract]
Subsequent Events	Note 25 — Subsequent Events Dispositions UGI International United Kingdom Energy Marketing. In October 2022, UGI International, through a wholly-owned subsidiary, sold its natural gas marketing business located in the United Kingdom resulting in a net cash payment to the buyer of $19 which includes working capital adjustments. The assets and liabilities associated with this business, primarily attributable to the value of unrealized gains and losses on derivative contracts, are classified as held-for-sale on the accompanying Consolidated Balance Sheet as of September 30, 2022. During the fourth quarter of Fiscal 2022, the Company recognized an impairment charge, which was limited to the disposal group’s long-lived assets in accordance with its policy related to assets held for sale. Such impairment in Fiscal 2022 was not material. An incremental pretax loss of approximately $220 was recognized in the first quarter of Fiscal 2023 in connection with the completed sale, largely attributable to the difference between the net cash payment to the buyer and the fair value of net derivative assets sold along with customer contracts as of the transaction date. The change in the net assets held for sale as of September 30, 2022, and the loss recognized upon disposal in October 2022, was due to the change in the fair value of the net derivative assets subsequent to September 30, 2022. UGI International France Energy Marketing. In November 2022, the Company announced its intent to sell its energy marketing business located in France, with a definitive agreement expected to be signed in the first quarter of Fiscal 2023. The Company expects to recognize a significant loss on the sale largely attributable to the value of net derivative assets sold along with the related customer contracts. At September 30, 2022, the carrying value of the net assets of the Company’s energy marketing business in France amounted to approximately $470 with primarily all of that value related to the fair value of the applicable derivative contracts.

SCHEDULE I _ CONDENSED FINANCIA

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)	12 Months Ended
	Sep. 30, 2022
Condensed Financial Information Disclosure [Abstract]
SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)	BALANCE SHEETS (Millions of dollars) September 30, 2022 2021 ASSETS Current assets: Cash and cash equivalents $ 20 $ 14 Accounts receivable – related parties 24 18 Prepaid expenses and other current assets 20 11 Total current assets 64 43 Property, plant and equipment, net 1 2 Investments in subsidiaries 7,035 6,479 Other assets 97 107 Total assets $ 7,197 $ 6,631 LIABILITIES AND COMMON STOCKHOLDERS’ EQUITY Current liabilities: Current maturities of long-term debt $ 125 $ 70 Accounts and notes payable 20 24 Accrued liabilities 51 62 Total current liabilities 196 156 Long-term debt 889 875 Other noncurrent liabilities 46 78 Total liabilities 1,131 1,109 Commitments and contingencies (Note 1) Equity: Preferred Stock, without par value (authorized - 5,000,000; issued - 220,000 and 220,000, respectively) 162 213 Common Stock, without par value (authorized – 450,000,000 shares; issued – 210,560,494 and 209,843,296 shares, respectively) 1,483 1,394 Retained earnings 4,841 4,081 Accumulated other comprehensive loss (380) (140) Treasury stock, at cost (40) (26) Total common stockholders’ equity 6,066 5,522 Total liabilities and common stockholders’ equity $ 7,197 $ 6,631 Note 1 — Commitments and Contingencies: At September 30, 2022, UGI Corporation had agreed to indemnify the issuers of $107 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 $371 of such obligations were outstanding as of September 30, 2022. Scheduled principal repayments of long-term debt during the next five fiscal years include $125 in Fiscal 2023, $377 in Fiscal 2024, and $515 in Fiscal 2025. STATEMENTS OF INCOME (Millions of dollars, except per share amounts) Year Ended September 30, 2022 2021 2020 Revenues $ — $ — $ — Costs and expenses: Operating and administrative expenses 74 94 56 Other operating income, net (a) (63) (65) (54) 11 29 2 Operating loss (11) (29) (2) Pension and other postretirement plans non-service expense (3) — — Interest expense (35) (27) (32) Loss before income taxes (49) (56) (34) Income tax expense — 9 17 Loss before equity in income of unconsolidated subsidiaries (49) (65) (51) Equity in income of unconsolidated subsidiaries 1,122 1,532 583 Net income attributable to UGI Corporation $ 1,073 $ 1,467 $ 532 Other comprehensive income (loss) 34 7 (12) Equity in other comprehensive (loss) income of unconsolidated subsidiaries (274) — 82 Comprehensive income attributable to UGI Corporation $ 833 $ 1,474 $ 602 Earnings per common share attributable to UGI Corporation stockholders: Basic $ 5.11 $ 7.02 $ 2.55 Diluted $ 4.97 $ 6.92 $ 2.54 Weighted - average common shares outstanding (thousands): Basic 209,940 209,063 208,928 Diluted 215,821 212,126 209,869 (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, 2022 2021 2020 NET CASH PROVIDED BY OPERATING ACTIVITIES (a) $ 485 $ 300 $ 322 CASH FLOWS FROM INVESTING ACTIVITIES: Return of capital distributions 175 — — Net investments in unconsolidated subsidiaries (390) (401) — Net cash used by investing activities (215) (401) — CASH FLOWS FROM FINANCING ACTIVITIES: Dividends on UGI Common Stock (296) (282) (273) Issuances of debt, net of issuance costs 597 483 60 Repayments of long-term debt (530) (385) (60) Issuance of preferred stock, net of issuance costs — 213 — Issuances of UGI Common Stock 19 19 2 Repurchases of UGI Common Stock (38) — (38) Payments on Purchase Contracts (16) — — Net cash (used) provided by financing activities (264) 48 (309) Cash and cash equivalents increase (decrease) $ 6 $ (53) $ 13 Cash and cash equivalents: End of year $ 20 $ 14 $ 67 Beginning of year 14 67 54 Cash and cash equivalents increase (decrease) $ 6 $ (53) $ 13 (a) Includes dividends received from unconsolidated subsidiaries of $506, $354 and $352 for the years ended September 30, 2022, 2021 and 2020, respectively.

SCHEDULE II _ VALUATION AND QUA

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS	12 Months Ended
	Sep. 30, 2022
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, 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 Year Ended September 30, 2020 Reserves deducted from assets in the consolidated balance sheet: Allowance for doubtful accounts $ 32 $ 32 $ (22) (1) $ 42 Other reserves: Deferred tax assets valuation allowance $ 91 $ — $ 14 (2) $ 105 (1) Uncollectible accounts written off, net of recoveries. (2) Primarily a notional interest deduction valuation allowance adjustment.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Sep. 30, 2022
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.
Reclassification	For purposes of comparability, certain prior-year amounts have been reclassified to conform to the current-year presentation. 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 issued in May 2021.
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 22 for more 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 cross-currency swaps and net investment hedges, if any, are included in cash flows from operating activities on the Consolidated Statements of Cash Flows. Cash flows from the interest portion of our cross-currency hedges, if any, are included in cash flows from operating activities while cash flows from the currency portion of such hedges, if any, are included in cash flows from financing activities. Cash flows from net investment hedges, if any, 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
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 RecognitionIn 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.
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
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.
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 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.
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. 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
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 an intangible asset impairment recognized in 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.
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 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.
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. environmental liabilities on the Consolidated Balance Sheets
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 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	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 2022 and New Accounting Standard Adopted Effective October 1, 2022	New Accounting Standard Adopted in Fiscal 2022 Income Taxes. Effective October 1, 2021, the Company adopted ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes” prospectively and retrospectively where deemed applicable. This ASU simplifies the accounting for income taxes by eliminating certain exceptions within the existing guidance for recognizing deferred taxes for equity method investments, performing intraperiod allocations and calculating income taxes in interim periods. Further, this ASU clarifies existing guidance related to, among other things, recognizing deferred taxes for goodwill and allocated taxes to members of a consolidated group. The adoption of the new guidance did not have a material impact on our consolidated financial statements. New Accounting Standard Adopted Effective October 1, 2022

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Sep. 30, 2022
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) 2022 2021 2020 Weighted-average common shares outstanding for basic computation 209,940 209,063 208,928 Incremental shares issuable for stock options, common stock awards and Equity Units (a) (b) 5,881 3,063 941 Weighted-average common shares outstanding for diluted computation 215,821 212,126 209,869 (a) Fiscal 2022 and 2021 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 2022, Fiscal 2021 and Fiscal 2020 there were 8,138 shares, 5,267 shares and 7,056 shares, respectively, associated with outstanding stock option awards that were not included in the computation of diluted earnings per share because their effect was antidilutive.
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. 2022 2021 2020 Cash and cash equivalents $ 405 $ 855 $ 336 Restricted cash 64 22 21 Cash, cash equivalents and restricted cash $ 469 $ 877 $ 357
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. 2022 2021 2020 Cash and cash equivalents $ 405 $ 855 $ 336 Restricted cash 64 22 21 Cash, cash equivalents and restricted cash $ 469 $ 877 $ 357

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Sep. 30, 2022
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 2022, Fiscal 2021 and Fiscal 2020: 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) 2020 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 563 $ — $ — $ — $ — $ 563 $ — Commercial & Industrial 215 — — — — 215 — Large delivery service 142 — — — — 142 — Off-system sales and capacity releases 48 (45) — — — 93 — Other 14 (2) — — — 16 — Total Utility 982 (47) — — — 1,029 — Non-Utility: LPG: Retail 3,499 — 2,037 1,462 — — — Wholesale 211 — 63 148 — — — Energy Marketing 1,233 (79) — 434 878 — — Midstream: Pipeline 168 — — — 168 — — Peaking 6 (100) — — 106 — — Other 7 — — — 7 — — Electricity Generation 34 — — — 34 — — Other 312 (3) 215 60 40 — — Total Non-Utility 5,470 (182) 2,315 2,104 1,233 — — Total revenues from contracts with customers 6,452 (229) 2,315 2,104 1,233 1,029 — Other revenues (b) 107 (3) 66 23 14 1 6 Total revenues $ 6,559 $ (232) $ 2,381 $ 2,127 $ 1,247 $ 1,030 $ 6 (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, rental revenues from certain 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.

Acquisitions and Dispositions (

Acquisitions and Dispositions (Tables)	12 Months Ended
	Sep. 30, 2022
Business Combination and Asset Acquisition [Abstract]
Components of the Purchase Price Allocations	The Company has accounted for the Mountaineer Acquisition using the acquisition method. During Fiscal 2022, the Company recorded an adjustment to decrease goodwill by $5 primarily reflecting an adjustment to a valuation allowance on certain deferred income taxes. The Consolidated Balance Sheet at September 30, 2022, reflects the final allocation of the purchase price to the assets acquired and liabilities assumed for the Mountaineer Acquisition. The components of the Mountaineer purchase price allocations 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
Total Cash Paid and Liabilities Incurred	Total cash paid and liabilities incurred in connection with these acquisitions were as follows: 2021 2020 UGI International Midstream & Marketing Total cash paid $ 18 $ 16 Liabilities incurred — 7 Total purchase price $ 18 $ 23

Debt (Tables)

Debt (Tables)	12 Months Ended
	Sep. 30, 2022
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, 2022 and 2021, 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 and its predecessor agreement) 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, 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 % September 30, 2021 AmeriGas OLP (a) December 2022 $ 600 $ 170 $ 60 $ 370 2.58 % 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 $ 130 $ — $ 220 1.35 % Mountaineer (e) November 2024 $ 100 $ 67 $ — $ 33 N.M. UGI Corporation (f) August 2024 $ 300 $ 185 $ — $ 115 3.27 % (a) At September 30, 2022 the 2022 AmeriGas OLP Credit Agreement includes a $100 sublimit for letters of credit. At September 30, 2021 the AmeriGas OLP Credit Agreement included a $150 sublimit for letters of credit. (b) The UGI International Credit Facilities Agreement permits UGI International, LLC to borrow 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. (e) The Mountaineer Credit Agreement includes a $20 sublimit for letters of credit. (f) At September 30, 2022 and 2021, management intended to maintain a substantial portion of amounts outstanding under the 2021 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 and 2021, the Company repaid $87 and $70, respectively, of such borrowings and classified these repayments as “Current maturities of long-term debt” on the Consolidated Balance Sheets. The 2021 UGI Corporation Senior Credit Facility includes a $10 sublimit for letters of credit. N.A. - Not applicable N.M. - Not meaningful
Schedule of Receivables Facility	Information regarding the amounts of trade receivables transferred to ESFC and the amounts sold to the bank are as follows: 2022 2021 2020 Trade receivables transferred to ESFC during the year $ 2,221 $ 1,353 $ 1,046 ESFC trade receivables sold to the bank during the year $ 152 $ 308 $ 182 ESFC trade receivables - end of year (a) $ 101 $ 61 $ 50 (a) At September 30, 2022 and 2021, 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: 2022 2021 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 675 675 5.75% due May 2027 525 525 Other — 1 Unamortized debt issuance costs (12) (16) Total AmeriGas Propane 2,563 2,560 UGI International: 3.25% Senior Notes due November 2025 — 405 2.50% Senior Notes due December 2029 392 — UGI International, LLC variable-rate term loan due October 2023 (a) 294 347 Other 2 23 Unamortized debt issuance costs (6) (5) Total UGI International 682 770 Midstream & Marketing: Energy Services variable-rate term loan due through August 2026 (b) 677 684 Other 40 42 Unamortized discount and debt issuance costs (7) (10) Total Energy Services 710 716 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 — 4.99% due September 2052 85 — Medium-Term Notes: 6.13% due October 2034 20 20 6.50% due August 2033 20 20 Mountaineer senior notes (c) 201 164 Variable-rate term loan due through July 2027 (d) 95 102 Other 1 1 Unamortized debt issuance costs (6) (6) Total UGI Utilities 1,656 1,451 UGI Corporation: UGI Corporation revolving credit facility maturing August 2024 (e) 252 185 UGI Corporation variable-rate term loan due May 2025 (f) 300 300 UGI Corporation variable-rate term loan due through August 2024 (g) 250 250 UGI Corporation variable-rate term loan due May 2025 (h) 215 215 Unamortized debt issuance costs (2) (5) Total UGI Corporation 1,015 945 Other 6 7 Total long-term debt 6,632 6,449 Less: current maturities (149) (110) Total long-term debt due after one year $ 6,483 $ 6,339 (a) The effective interest rate on the term loan was 1.89% at both September 30, 2022 and 2021. We have entered into pay- fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate on these borrowings. (b) At September 30, 2022 and 2021, the effective interest rates on the term loan were 5.13% and 5.23%, respectively. We have entered into a pay-fixed, receive-variable interest rate swap to effectively fix the underlying variable rate on these borrowings. 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. (c) Total long-term debt at September 30, 2022 and 2021, comprises $180 and $140 principal amount of Mountaineer senior secured notes plus unamortized premium of $21 and $24, respectively. The face interest rates on the Mountaineer senior notes range from 3.50% to 4.49%, with maturities ranging from 2027 to 2052. (d) At September 30, 2022 and 2021, the effective interest rate on this term loan was 3.92% and 4.00%, respectively. We have entered into a pay-fixed, receive-variable interest rate swap to effectively fix the underlying variable rate on these borrowings. Term loan borrowings are due in equal quarterly installments of $2, with the balance of the principal being due in full at maturity. (e) At September 30, 2022 and 2021, the effective interest rates on credit facility borrowings were 5.61% and 3.27%, respectively. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate on a portion of these borrowings. (f) At September 30, 2022 and 2021, the effective interest rates on the term loan was 2.67% and 3.26%, respectively. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate on these borrowings. (g) At September 30, 2022 and 2021, the effective interest rates on the term loan were 4.15% and 3.56%, respectively. We have entered into pay-fixed, receive-variable interest rate swaps to effectively fix the underlying variable rate on a portion of these borrowings. Term loan borrowings are due in equal quarterly installments of $9, commencing December 2022, with the balance of the principal being due in full at maturity.
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: 2023 2024 2025 2026 2027 AmeriGas Propane $ — $ 675 $ 700 $ 675 $ 525 UGI International 1 294 — — — Midstream & Marketing 10 7 7 656 — Utilities 7 6 6 281 70 UGI Corporation (a) 125 377 515 — — Other 6 — — — — Total $ 149 $ 1,359 $ 1,228 $ 1,612 $ 595 (a) Subsequent to September 30, 2022 and 2021, the Company repaid $87 and $70, respectively, of borrowings on the UGI Corporation revolving credit facility maturing August 2024. Such repayments are classified as “Current maturities of long-term debt” on the Consolidated Balance Sheets.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Income Before Income Taxes	Income before income taxes comprises the following: 2022 2021 2020 Domestic $ 362 $ 647 $ 424 Foreign 1,025 1,342 243 Total income before income taxes $ 1,387 $ 1,989 $ 667
Provisions for Income Taxes	The provisions for income taxes consist of the following: 2022 2021 2020 Current expense (benefit): Federal $ 24 $ (48) $ (85) State 18 7 4 Foreign 50 85 70 Total current expense (benefit) 92 44 (11) Deferred expense (benefit): Federal 45 168 135 State (17) 48 19 Foreign 193 262 (8) Total deferred expense 221 478 146 Total income tax expense $ 313 $ 522 $ 135
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: 2022 2021 2020 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % Difference in tax rate due to: Effects of U.S. tax legislation — (0.8) (4.7) Effects of tax rate changes - International (2.3) (1.3) 0.3 Effects of tax rate changes – State, net of federal benefit (1.4) — — State income taxes, net of federal benefit 1.5 1.9 2.8 Valuation allowance adjustments (0.5) 1.0 — Effects of foreign operations 4.4 4.6 1.3 Excess tax benefits on share-based payments (0.3) (0.1) (0.2) Other, net 0.2 (0.1) (0.3) Effective tax rate 22.6 % 26.2 % 20.2 %
Deferred Tax Liabilities (Assets)	Deferred tax liabilities (assets) comprise the following at September 30: 2022 2021 Excess book basis over tax basis of property, plant and equipment $ 867 $ 937 Utility regulatory assets 106 105 Intangible assets and goodwill 75 77 Derivative instrument assets 514 322 Other 33 36 Gross deferred tax liabilities 1,595 1,477 Investment in AmeriGas Partners (79) (102) Pension plan liabilities (21) (29) Employee-related benefits (38) (45) Operating loss carryforwards (48) (53) Foreign tax credit carryforwards (76) (79) Utility regulatory liabilities (85) (102) Utility environmental liabilities (15) (16) Other (125) (107) Gross deferred tax assets (487) (533) Deferred tax assets valuation allowance 141 138 Net deferred tax liabilities $ 1,249 $ 1,082

Employee Retirement Plans (Tabl

Employee Retirement Plans (Tables)	12 Months Ended
	Sep. 30, 2022
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, 2022 and 2021. 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 2022 2021 Change in benefit obligations: Benefit obligations — beginning of year $ 870 $ 782 Service cost 16 12 Interest cost 26 22 Actuarial gain (240) (30) Plan amendments 1 2 Acquisitions — 114 Foreign currency (6) (1) Benefits paid (34) (31) Pension Benefits 2022 2021 Benefit obligations — end of year (a) $ 633 $ 870 Change in plan assets: Fair value of plan assets — beginning of year $ 736 $ 585 Actual (loss) gain on plan assets (173) 75 Foreign currency (3) — Employer contributions 15 14 Acquisitions — 92 Benefits paid (34) (30) Fair value of plan assets — end of year $ 541 $ 736 Funded status of the plans — end of year (b) $ (92) $ (134) Amounts recorded in UGI Corporation stockholders’ equity (pre-tax): Prior service cost $ 3 $ 3 Net actuarial (gain) loss (17) 13 Total $ (14) $ 16 Amounts recorded in regulatory assets and liabilities (pre-tax): Net actuarial loss 114 108 Total $ 114 $ 108 (a) The ABO for the U.S. Pension Plans was $570 and $756 as of September 30, 2022 and 2021, 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 2022 2021 2020 Weighted-average assumptions: Discount rate – benefit obligations 5.70 % 3.13 % 2.90 % Discount rate – benefit cost 3.13 % 2.90 % 3.30 % Expected return on plan assets 7.10 % 7.10 % 7.20 % Rate of increase in salary levels 3.25 % 3.25 % 3.25 %
Net Periodic Pension Cost	Net periodic pension cost includes the following components: Pension Benefits 2022 2021 2020 Service cost $ 16 $ 12 $ 11 Interest cost 26 22 23 Expected return on assets (50) (40) (38) Curtailment gain — — (1) Amortization of: Prior service cost — — 1 Actuarial loss 7 14 15 Net benefit (income) cost $ (1) $ 8 $ 11
Expected Payments for Pension Benefits and Other Postretirement Welfare Benefits	Expected payments for pension benefits are as follows: Pension Fiscal 2023 $ 37 Fiscal 2024 $ 38 Fiscal 2025 $ 40 Fiscal 2026 $ 41 Fiscal 2027 $ 43 Fiscal 2028 - 2032 $ 229
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) 2022 2021 2022 2021 Equity investments: U.S. equities 26.5 % 22.2 % 24.7 % 25.3 % Non-U.S. equities 20.9 % 21.7 % 20.9 % 21.4 % Global equities (a) 13.8 % 16.0 % 13.1 % 13.1 % Total 61.2 % 59.9 % 58.7 % 59.8 % Fixed income funds & cash equivalents 35.5 % 36.4 % 35.0 % 34.4 % Alternative investments 3.3 % 3.7 % 6.3 % 5.8 % 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, 2022 and 2021 are as follows: 2022 2021 U.S. Pension Plans: Domestic equity investments: UGI Corporation Common Stock $ 26 $ 35 Total domestic equity investments (a) 26 35 Common collective trust funds: U.S. equity index investments 113 124 Non-U.S. equity index investments 110 155 Global equity index investments 72 115 Bond index investments 177 254 Cash equivalents 10 7 Total common collective trust funds (b) 482 655 Alternative investments (b) 17 27 Total $ 525 $ 717 (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, 2022
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: 2022 2021 Regulatory assets (a): Income taxes recoverable $ 83 $ 143 Underfunded pension plans 114 108 Environmental costs 37 58 Deferred fuel and power costs 32 11 Removal costs, net 22 24 Other 52 53 Total regulatory assets $ 340 $ 397 Regulatory liabilities (a): Postretirement benefits $ 11 $ 13 Deferred fuel and power refunds 3 36 State income tax benefits — distribution system repairs 38 32 Excess federal deferred income taxes 279 287 Other 4 20 Total regulatory liabilities $ 335 $ 388 (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: 2022 2021 Regulatory assets (a): Income taxes recoverable $ 83 $ 143 Underfunded pension plans 114 108 Environmental costs 37 58 Deferred fuel and power costs 32 11 Removal costs, net 22 24 Other 52 53 Total regulatory assets $ 340 $ 397 Regulatory liabilities (a): Postretirement benefits $ 11 $ 13 Deferred fuel and power refunds 3 36 State income tax benefits — distribution system repairs 38 32 Excess federal deferred income taxes 279 287 Other 4 20 Total regulatory liabilities $ 335 $ 388 (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, 2022
Inventory Disclosure [Abstract]
Components of Inventories	Inventories comprise the following at September 30: 2022 2021 Non-utility LPG and natural gas $ 335 $ 278 Gas Utility natural gas 166 68 Energy certificates 70 53 Materials, supplies and other 94 70 Total inventories $ 665 $ 469

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment comprise the following at September 30: 2022 2021 Estimated Useful Life Utility: Distribution $ 4,746 $ 4,306 Transmission 123 111 General and other 557 507 Work in process 124 98 Total Utility 5,550 5,022 Non-utility: Land 179 186 Buildings and improvements 426 436 10 - 40 years Transportation equipment 234 232 3 - 10 years Equipment, primarily cylinders and tanks 3,645 3,785 5 - 30 years Electric generation 216 211 25 - 40 years Pipeline and related assets 1,523 1,218 25 - 40 years Other 380 342 1 - 12 years Work in process 53 76 Total non-utility 6,656 6,486 Total property, plant and equipment $ 12,206 $ 11,508
Average Composite Depreciation Rates	The average composite depreciation rates at our Gas Utility and Electric Utility were as follows: 2022 2021 2020 Regulated natural gas utilities 2.6 % 2.6 % 2.5 % Electric Utility 2.4 % 2.3 % 2.2 %

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Sep. 30, 2022
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, 2020 $ 2,004 $ 997 $ 335 $ 182 $ 3,518 Acquisitions — 6 — 255 261 Purchase accounting adjustments — — 1 — 1 Foreign currency translation — (10) — — (10) 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
Schedule of Finite-Lived Intangible Assets	Intangible assets comprise the following at September 30: 2022 2021 Customer relationships $ 1,006 $ 1,054 Trademarks and tradenames 11 12 Noncompete agreements and other 71 75 Accumulated amortization (629) (607) Intangible assets, net (definite-lived) 459 534 Trademarks and tradenames (indefinite-lived) 41 49 Total intangible assets, net $ 500 $ 583
Schedule of Indefinite-Lived Intangible Assets	Intangible assets comprise the following at September 30: 2022 2021 Customer relationships $ 1,006 $ 1,054 Trademarks and tradenames 11 12 Noncompete agreements and other 71 75 Accumulated amortization (629) (607) Intangible assets, net (definite-lived) 459 534 Trademarks and tradenames (indefinite-lived) 41 49 Total intangible assets, net $ 500 $ 583

Equity (Tables)

Equity (Tables)	12 Months Ended
	Sep. 30, 2022
Equity [Abstract]
Common Stock Share Activity	UGI Preferred Stock and Common Stock share activity for Fiscal 2022, Fiscal 2021 and Fiscal 2020 is as follows: Preferred Stock Common Stock Issued/Outstanding Issued Treasury Outstanding Balance at September 30, 2019 — 209,304,129 (299,340) 209,004,789 Issued: Employee and director plans — 209,915 180,050 389,965 Repurchases of common stock — — (950,000) (950,000) Reacquired common stock – employee and director plans — — (90,316) (90,316) 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 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

Leases (Tables)

Leases (Tables)	12 Months Ended
	Sep. 30, 2022
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: 2022 2021 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 368 $ 390 Other assets Finance lease ROU assets 48 49 Property, plant and equipment Total ROU assets $ 416 $ 439 Lease liabilities: Operating lease liabilities — current $ 82 $ 81 Other current liabilities Operating lease liabilities — noncurrent 294 318 Other noncurrent liabilities Finance lease liabilities — current 4 4 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 41 Long-term debt Total lease liabilities $ 421 $ 444
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 2022, Fiscal 2021 and Fiscal 2020 are as follows: 2022 2021 2020 Operating lease cost $ 96 $ 101 $ 102 Finance lease cost: Amortization of ROU assets 4 4 5 Interest on lease liabilities 3 3 3 Variable lease cost 6 4 5 Short-term lease cost 2 2 3 Total lease cost $ 111 $ 114 $ 118 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statements of Cash Flows during Fiscal 2022, Fiscal 2021 and Fiscal 2020: 2022 2021 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 95 $ 99 $ 103 Operating cash flows — finance leases $ 3 $ 3 $ 3 Financing cash flows — finance leases $ 2 $ 3 $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (a) $ 72 $ 85 $ 506 ROU assets obtained in exchange for finance lease liabilities $ 2 $ 1 $ 22 (a) Fiscal 2020 includes the impact of the adoption of ASC 842 – Leases . The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2022 2021 Operating leases 6.0 6.3 Finance leases 3.7 2.4 Weighted-average discount rate (%) 2022 2021 Operating leases 3.6% 3.6% Finance leases 1.8% 1.5%
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, 2022, were as follows: 2023 2024 2025 2026 2027 After 2027 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 93 $ 81 $ 64 $ 52 $ 41 $ 86 $ 417 $ (41) $ 376 Finance leases $ 4 $ 4 $ 4 $ 4 $ 3 $ 77 $ 96 $ (51) $ 45
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, 2022, were as follows: 2023 2024 2025 2026 2027 After 2027 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 93 $ 81 $ 64 $ 52 $ 41 $ 86 $ 417 $ (41) $ 376 Finance leases $ 4 $ 4 $ 4 $ 4 $ 3 $ 77 $ 96 $ (51) $ 45

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Sep. 30, 2022
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, 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 September 30, 2021 Derivative instruments: Assets: Commodity contracts $ 641 $ 1,008 $ — $ 1,649 Foreign currency contracts $ — $ 38 $ — $ 38 Liabilities: Commodity contracts $ (264) $ (16) $ — $ (280) Foreign currency contracts $ — $ (8) $ — $ (8) Interest rate contracts $ — $ (29) $ — $ (29) Non-qualified supplemental postretirement grantor trust investments (a) $ 53 $ — $ — $ 53 (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 held-for-sale associated with the October 2022 sale of the United Kingdom energy marketing business (see Note 25).
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: 2022 2021 Carrying amount $ 6,665 $ 6,491 Estimated fair value $ 6,189 $ 6,996

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Sep. 30, 2022
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, 2022 and 2021 and the final settlement dates of the Company's open derivative contracts as of September 30, 2022, (including amounts associated with our energy marketing businesses in the United Kingdom and France (Note 25)) but excluding those derivatives that qualified for the NPNS exception: Notional Amounts September 30, Type Units Settlements Extending Through 2022 2021 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms October 2023 19 20 Non-utility Operations LPG swaps Gallons January 2025 874 708 Natural gas futures, forward, basis swap, options and pipeline contracts Dekatherms October 2026 363 355 Electricity forward and futures contracts Kilowatt hours December 2026 2,446 4,302 Interest Rate Risk: Interest rate swaps Euro October 2022 € 300 € 300 Interest rate swaps USD June 2026 $ 1,358 $ 1,421 Foreign Currency Exchange Rate Risk: Forward foreign exchange contracts USD August 2025 $ 465 $ 509 Net investment hedge forward foreign exchange contracts Euro December 2026 € 411 € 173
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: 2022 2021 Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 57 $ 20 Interest rate contracts 66 — 123 20 Derivatives subject to PGC and DS mechanisms: Commodity contracts 31 58 Derivatives not designated as hedging instruments: Commodity contracts (a) 2,202 1,591 Foreign currency contracts 62 18 2,264 1,609 Total derivative assets – gross 2,418 1,687 Gross amounts offset in the balance sheet (295) (216) Cash collateral received (398) (468) Total derivative assets – net $ 1,725 $ 1,003 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts $ — $ (29) Derivatives subject to PGC and DS mechanisms: Commodity contracts (26) (23) Derivatives not designated as hedging instruments: Commodity contracts (a) (487) (257) Foreign currency contracts (2) (8) (489) (265) Total derivative liabilities – gross (515) (317) Gross amounts offset in the balance sheet 295 216 Cash collateral pledged 7 3 Total derivative liabilities – net $ (213) $ (98) (a) Includes derivative assets and liabilities held-for-sale associated with the October 2022 sale of the United Kingdom energy marketing business (see Note 25).
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 2022, Fiscal 2021 and Fiscal 2020: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from 2022 2021 2020 2022 2021 2020 Cash Flow Hedges: Interest rate contracts 91 4 (53) (7) (25) (13) Interest expense Net Investment Hedges: Foreign currency contracts $ 69 $ 4 $ (1) Gain (Loss) Location of 2022 2021 2020 Derivatives Not Designated as Hedging Instruments: Commodity contracts $ (9) $ (17) $ 10 Revenues Commodity contracts 1,181 1,545 (32) Cost of sales Commodity contracts 1 5 — Other operating income, net Foreign currency contracts 63 9 (20) Other non-operating income (expense), net Total $ 1,236 $ 1,542 $ (42)

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Sep. 30, 2022
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	The tables below present changes in AOCI, net of tax, during Fiscal 2022, Fiscal 2021 and Fiscal 2020: Postretirement Derivative Foreign Total AOCI - September 30, 2019 $ (26) $ (25) $ (166) $ (217) Other comprehensive (loss) income before reclassification adjustments (3) (38) 99 58 Amounts reclassified from AOCI 3 9 — 12 Other comprehensive (loss) income attributable to UGI — (29) 99 70 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 Operating Income, Net a_2

Other Operating Income, Net and Other Non-Operating Income (Expense), Net (Tables)	12 Months Ended
	Sep. 30, 2022
Component of Operating Income [Abstract]
Other Operating Income, Net	Other operating income, net, comprises the following: 2022 2021 2020 Finance charges $ 18 $ 17 $ 9 Gains on sales of fixed assets, net 33 11 5 Gain on early derivative termination — 5 — Interest and interest-related income 1 — 2 Other, net 27 — 5 Total other operating income, net $ 79 $ 33 $ 21
Schedule of Other Non-Operating Income (Expense), Net	Other non-operating income (expense), net comprises the following: 2022 2021 2020 Gains (losses) on foreign currency contracts, net $ 63 $ 9 $ (20) Amortization of excluded components of certain net investment hedges 7 2 — Pension and other postretirement plans non-service income, net 5 1 — Total other non-operating income (expense), net $ 75 $ 12 $ (20)

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Sep. 30, 2022
Segment Reporting [Abstract]
Schedule of Segment Reporting Information	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 $ — Total Elim- AmeriGas UGI International Midstream Utilities Corporate & 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 $ — $ — 2020 Revenues from external customers $ 6,559 $ — $ 2,381 $ 2,127 $ 1,065 $ 983 $ 3 Intersegment revenues $ — $ (232) (b) $ — $ — $ 182 $ 47 $ 3 Cost of sales $ 3,149 $ (229) (b) $ 960 $ 1,191 $ 892 $ 448 $ (113) Operating income (loss) $ 982 $ — $ 373 $ 241 $ 140 $ 229 $ (1) Income from equity investees 27 — — — 27 — — Other non-operating (expense) income, net (20) — — 18 1 — (39) Earnings (loss) before interest expense and income taxes 989 — 373 259 168 229 (40) Interest expense (322) — (164) (31) (42) (54) (31) Income tax (expense) benefit (135) — (53) (55) (34) (39) 46 Net income (loss) attributable to UGI $ 532 $ — $ 156 $ 173 $ 92 $ 136 $ (25) Depreciation and amortization $ 484 $ — $ 178 $ 125 $ 75 $ 105 $ 1 Total assets $ 13,985 $ (282) $ 4,327 $ 3,123 $ 2,775 $ 3,809 $ 233 Short-term borrowings $ 347 $ — $ 186 $ 1 $ 19 $ 141 $ — Capital expenditures (including the effects of accruals) $ 665 $ — $ 135 $ 89 $ 93 $ 348 $ — Investments in equity investees $ 200 $ — $ — $ 10 $ 190 $ — $ — (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 2022, Fiscal 2021 and Fiscal 2020: Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing 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 $ (21) $ (9) $ (1) Loss on extinguishment of debt Loss on extinguishments of debt $ — $ (11) $ — Unrealized gains on foreign currency derivative instruments Other non-operating income (expense), net $ — $ 50 $ — Impairments of certain equity method investments and assets Operating and administrative expenses; (Loss) income from equity investees, respectively $ — $ (5) $ (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 losses on foreign currency derivative instruments Other non-operating income (expense), 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 (Loss) income from equity investees $ — $ — $ (93) 2020 Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ 3 Net gains on commodity derivative instruments not associated with current-period transactions Cost of Sales $ 72 $ — $ 42 Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (36) $ — Acquisition and integration expenses associated with the CMG Acquisition Operating and administrative expenses $ — $ — $ (2) Business transformation expenses Operating and administrative expenses $ (44) $ (18) $ — Loss on disposals of Conemaugh and HVAC Loss on disposals of Conemaugh and HVAC $ — $ — $ (54) (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, 2022
Condensed Financial Information Disclosure [Abstract]
Balance Sheets	BALANCE SHEETS (Millions of dollars) September 30, 2022 2021 ASSETS Current assets: Cash and cash equivalents $ 20 $ 14 Accounts receivable – related parties 24 18 Prepaid expenses and other current assets 20 11 Total current assets 64 43 Property, plant and equipment, net 1 2 Investments in subsidiaries 7,035 6,479 Other assets 97 107 Total assets $ 7,197 $ 6,631 LIABILITIES AND COMMON STOCKHOLDERS’ EQUITY Current liabilities: Current maturities of long-term debt $ 125 $ 70 Accounts and notes payable 20 24 Accrued liabilities 51 62 Total current liabilities 196 156 Long-term debt 889 875 Other noncurrent liabilities 46 78 Total liabilities 1,131 1,109 Commitments and contingencies (Note 1) Equity: Preferred Stock, without par value (authorized - 5,000,000; issued - 220,000 and 220,000, respectively) 162 213 Common Stock, without par value (authorized – 450,000,000 shares; issued – 210,560,494 and 209,843,296 shares, respectively) 1,483 1,394 Retained earnings 4,841 4,081 Accumulated other comprehensive loss (380) (140) Treasury stock, at cost (40) (26) Total common stockholders’ equity 6,066 5,522 Total liabilities and common stockholders’ equity $ 7,197 $ 6,631
Statements of Income	STATEMENTS OF INCOME (Millions of dollars, except per share amounts) Year Ended September 30, 2022 2021 2020 Revenues $ — $ — $ — Costs and expenses: Operating and administrative expenses 74 94 56 Other operating income, net (a) (63) (65) (54) 11 29 2 Operating loss (11) (29) (2) Pension and other postretirement plans non-service expense (3) — — Interest expense (35) (27) (32) Loss before income taxes (49) (56) (34) Income tax expense — 9 17 Loss before equity in income of unconsolidated subsidiaries (49) (65) (51) Equity in income of unconsolidated subsidiaries 1,122 1,532 583 Net income attributable to UGI Corporation $ 1,073 $ 1,467 $ 532 Other comprehensive income (loss) 34 7 (12) Equity in other comprehensive (loss) income of unconsolidated subsidiaries (274) — 82 Comprehensive income attributable to UGI Corporation $ 833 $ 1,474 $ 602 Earnings per common share attributable to UGI Corporation stockholders: Basic $ 5.11 $ 7.02 $ 2.55 Diluted $ 4.97 $ 6.92 $ 2.54 Weighted - average common shares outstanding (thousands): Basic 209,940 209,063 208,928 Diluted 215,821 212,126 209,869
Statements of Cash Flows	STATEMENTS OF CASH FLOWS (Millions of dollars) Year Ended September 30, 2022 2021 2020 NET CASH PROVIDED BY OPERATING ACTIVITIES (a) $ 485 $ 300 $ 322 CASH FLOWS FROM INVESTING ACTIVITIES: Return of capital distributions 175 — — Net investments in unconsolidated subsidiaries (390) (401) — Net cash used by investing activities (215) (401) — CASH FLOWS FROM FINANCING ACTIVITIES: Dividends on UGI Common Stock (296) (282) (273) Issuances of debt, net of issuance costs 597 483 60 Repayments of long-term debt (530) (385) (60) Issuance of preferred stock, net of issuance costs — 213 — Issuances of UGI Common Stock 19 19 2 Repurchases of UGI Common Stock (38) — (38) Payments on Purchase Contracts (16) — — Net cash (used) provided by financing activities (264) 48 (309) Cash and cash equivalents increase (decrease) $ 6 $ (53) $ 13 Cash and cash equivalents: End of year $ 20 $ 14 $ 67 Beginning of year 14 67 54 Cash and cash equivalents increase (decrease) $ 6 $ (53) $ 13 (a) Includes dividends received from unconsolidated subsidiaries of $506, $354 and $352 for the years ended September 30, 2022, 2021 and 2020, respectively.

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Revenue Recognition (Details)	12 Months Ended
	Sep. 30, 2022
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, 2022	Sep. 30, 2021	Sep. 30, 2020
Accounting Policies [Abstract]
Weighted-average common shares outstanding for basic computation (in shares)	209,940	209,063	208,928
Incremental shares issuable for stock options, common stock awards and Equity Units (in shares)	5,881	3,063	941
Weighted-average common shares outstanding for diluted computation (in shares)	215,821	212,126	209,869
Antidilutive securities excluded from computation of earnings per share (in shares)	8,138	5,267	7,056

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, 2022	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Accounting Policies [Abstract]
Cash and cash equivalents	$ 405	$ 855	$ 336
Restricted cash	64	22	21
Cash, cash equivalents and restricted cash	$ 469	$ 877	$ 357	$ 511

Summary of Significant Accoun_7

Summary of Significant Accounting Policies- Property, Plant and Equipment and Related Depreciation (Details) - USD ($)	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
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 ($)	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Goodwill [Line Items]
Goodwill	$ 3,612,000,000	$ 3,770,000,000	$ 3,518,000,000
Accumulated impairment losses	0	0
Provision for goodwill or other intangible asset impairments	$ 0	$ 0	$ 0
AmeriGas Propane
Goodwill [Line Items]
Fair value in excess of carrying value	30%
Goodwill	$ 2,000,000,000

Summary of Significant Accoun_9

Summary of Significant Accounting Policies - Impairment of Long-Lived Assets and Cost Basis Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Accounting Policies [Abstract]
Impairment charges	$ 0	$ 20

Summary of Significant Accou_10

Summary of Significant Accounting Policies - Refundable Tank and Cylinder Deposits and Environmental Matters (Details) - USD ($) $ in Millions	Sep. 30, 2022	Sep. 30, 2021
Accounting Policies [Abstract]
Customer paid deposits primarily on owned tanks and cylinders	$ 243	$ 296
Environmental Loss Contingency, Statement of Financial Position [Extensible Enumeration]	Environmental Loss Contingency, Statement of Financial Position Extensible Enumeration Not Disclosed Flag [Member]

Revenue from Contracts with C_3

Revenue from Contracts with Customers - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Contract liabilities	$ 164	$ 149
Contract liabilities, recognized revenue	$ 119	$ 138	$ 122
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	$ 2,400
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
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 9,981	$ 7,348	$ 6,452
Other revenues	125	99	107
Total revenues	10,106	7,447	6,559
Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	875	568	563
Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	365	218	215
Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	171	148	142
Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	76	51	48
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	23	21	14
Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,510	1,006	982
Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4,436	3,957	3,499
Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	496	328	211
Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,951	1,564	1,233
Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	211	181	168
Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	48	16	6
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	9	8	7
Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	34	13	34
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	286	275	312
Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	8,471	6,342	5,470
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(474)	(288)	(229)
Other revenues	(3)	(3)	(3)
Total revenues	(477)	(291)	(232)
Eliminations | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Eliminations | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Eliminations | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Eliminations | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(104)	(62)	(45)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(1)	(2)	(2)
Eliminations | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(105)	(64)	(47)
Eliminations | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Eliminations | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Eliminations | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(264)	(126)	(79)
Eliminations | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Eliminations | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(105)	(98)	(100)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Eliminations | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	(3)
Eliminations | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(369)	(224)	(182)
Eliminations | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0
Eliminations | UGI International
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0
Eliminations | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues	369	224	182
Eliminations | Utilities
Disaggregation of Revenue [Line Items]
Total revenues	105	64	47
Operating Segments | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,864	2,548	2,315
Other revenues	79	66	66
Total revenues	2,943	2,614	2,381
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 Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Operating Segments | AmeriGas Propane | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,439	2,203	2,037
Operating Segments | AmeriGas Propane | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	218	139	63
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	207	206	215
Operating Segments | AmeriGas Propane | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,864	2,548	2,315
Operating Segments | UGI International
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	3,652	2,617	2,104
Other revenues	34	34	23
Total revenues	3,686	2,651	2,127
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 Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Operating Segments | UGI International | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,997	1,754	1,462
Operating Segments | UGI International | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	278	189	148
Operating Segments | UGI International | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,298	605	434
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	79	69	60
Operating Segments | UGI International | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	3,652	2,617	2,104
Operating Segments | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,324	1,401	1,233
Other revenues	2	5	14
Total revenues	2,326	1,406	1,247
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 Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
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	1,917	1,085	878
Operating Segments | Midstream & Marketing | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	211	181	168
Operating Segments | Midstream & Marketing | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	153	114	106
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	9	8	7
Operating Segments | Midstream & Marketing | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	34	13	34
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	40
Operating Segments | Midstream & Marketing | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,324	1,401	1,233
Operating Segments | Utilities
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,615	1,070	1,029
Other revenues	5	9	1
Total revenues	1,620	1,079	1,030
Operating Segments | Utilities | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	875	568	563
Operating Segments | Utilities | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	365	218	215
Operating Segments | Utilities | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	171	148	142
Operating Segments | Utilities | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	180	113	93
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	24	23	16
Operating Segments | Utilities | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,615	1,070	1,029
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
Operating Segments | Utilities | Total Non-Utility
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	8	(12)	6
Total revenues	8	(12)	6
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 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
Corporate & Other | Total Non-Utility
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			3 Months Ended	12 Months Ended
	Jan. 27, 2022	Sep. 01, 2021	Jun. 30, 2020	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020	Jul. 31, 2020
Business Acquisition [Line Items]
Purchase accounting adjustments				$ (5)	$ 1
Investments in equity method investees				$ 47	$ 65	$ 0
Energy Services | Pennant
Business Acquisition [Line Items]
Ownership percent				47%	47%
Energy Services | Pennant
Business Acquisition [Line Items]
Percentage of voting interests acquired				53%
Investments in equity method investees				$ 61
2021 UGI Corporation Senior Credit Facility
Business Acquisition [Line Items]
Proceeds from issuance of debt		$ 215
Sale | HVAC business
Business Acquisition [Line Items]
Loss on disposal						$ 2
Ownership | Sale | Conemaugh
Business Acquisition [Line Items]
Proportionate ownership share, percent (as a percentage)							5.97%
Impairment of assets held-for-sale			$ 52
Stonehenge | Energy Services
Business Acquisition [Line Items]
Total purchase price	$ 190
Mountaineer
Business Acquisition [Line Items]
Total purchase price		540
Liabilities incurred		$ 140
Purchase accounting adjustments				$ 5
Transaction costs					$ 13

Acquisitions and Dispositions_2

Acquisitions and Dispositions - Components of the Preliminary Mountaineer Purchase Price Allocation (Details) - USD ($) $ in Millions	Sep. 30, 2022	Sep. 30, 2021	Sep. 01, 2021	Sep. 30, 2020
Liabilities assumed:
Goodwill	$ 3,612	$ 3,770		$ 3,518
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

Acquisitions and Dispositions_3

Acquisitions and Dispositions - Total Cash Paid and Liabilities Incurred (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
UGI International
Business Acquisition [Line Items]
Total cash paid	$ 18
Liabilities incurred	0
Total purchase price	$ 18
Midstream & Marketing
Business Acquisition [Line Items]
Total cash paid		$ 16
Liabilities incurred		7
Total purchase price		$ 23

Debt - Mountaineer Credit Agree

Debt - Mountaineer Credit Agreement (Details) - Mountaineer - USD ($)	Oct. 20, 2022	Sep. 30, 2022	Sep. 30, 2021
Debt Instrument [Line Items]
Borrowings (up to)		$ 100,000,000	$ 100,000,000
Line of Credit | Letter of Credit
Debt Instrument [Line Items]
Borrowings (up to)		$ 20,000,000
Mountaineer Credit Agreement | Line of Credit | Revolving Credit Facility | Subsequent Event
Debt Instrument [Line Items]
Borrowings (up to)	$ 150,000,000
Option to increase capacity	250,000,000
Mountaineer Credit Agreement | Line of Credit | Letter of Credit | Subsequent Event
Debt Instrument [Line Items]
Borrowings (up to)	$ 20,000,000

Debt - AmeriGas Propane (Detail

Debt - AmeriGas Propane (Details) - AmeriGas OLP - USD ($)	Sep. 30, 2022	Sep. 28, 2022	Sep. 30, 2021
Debt Instrument [Line Items]
Borrowings (up to)	$ 600,000,000		$ 600,000,000
AmeriGas OLP Credit Agreement | Line of Credit | Letter of Credit
Debt Instrument [Line Items]
Borrowings (up to)	$ 100,000,000	$ 100,000,000	$ 150,000,000
AmeriGas OLP Credit Agreement | Line of Credit | Revolving Credit Facility
Debt Instrument [Line Items]
Borrowings (up to)		600,000,000
Option to increase capacity		$ 900,000,000

Debt - UGI Utilities (Details)

Debt - UGI Utilities (Details) - UGI Utilities - USD ($)	Jul. 12, 2022	Sep. 15, 2022	Jul. 15, 2022	Jun. 30, 2022
Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Quarterly Installments	$ 2,000,000
Senior Notes | 4.75% due July 2032
Debt Instrument [Line Items]
Aggregate principal amount			$ 90,000,000	$ 90,000,000
Stated interest rate (as a percentage)		4.75%	4.75%	4.75%
Senior Notes | 4.99% due September 2052
Debt Instrument [Line Items]
Aggregate principal amount		$ 85,000,000		$ 85,000,000
Stated interest rate (as a percentage)		4.99%		4.99%

Debt - Mountaineer (Details)

Debt - Mountaineer (Details) - Mountaineer - 4.49% Senior Notes Due August 2052 - Senior Notes - USD ($)	Aug. 16, 2022	Jun. 30, 2022
Debt Instrument [Line Items]
Aggregate principal amount	$ 40,000,000	$ 40,000,000
Stated interest rate (as a percentage)	4.49%	4.49%

Debt - UGI International (Detai

Debt - UGI International (Details) $ in Millions		12 Months Ended
	Dec. 07, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Dec. 07, 2021 EUR (€)
Debt Instrument [Line Items]
Loss on extinguishments of debt		$ 11	$ 0	$ 0
UGI International LLC | Senior Notes | 2.50% Senior Notes due December 2029
Debt Instrument [Line Items]
Aggregate principal amount | €					€ 400,000,000
Stated interest rate (as a percentage)					2.50%
UGI International LLC | Senior Notes | 3.25% Senior Notes Due November 2025
Debt Instrument [Line Items]
Stated interest rate (as a percentage)					3.25%
Loss on extinguishments of debt	$ 11

Debt - Schedule of Credit Facil

Debt - Schedule of Credit Facilities and Short-term Borrowings (Details)	2 Months Ended	12 Months Ended
	Nov. 21, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2022 EUR (€)	Sep. 30, 2021 EUR (€)
AmeriGas OLP
Short-term Debt [Line Items]
Total Capacity		$ 600,000,000	$ 600,000,000
Borrowings Outstanding		170,000,000	131,000,000
Letters of Credit and Guarantees Outstanding		60,000,000	2,000,000
Available Borrowing Capacity		$ 370,000,000	$ 467,000,000
Weighted Average Interest Rate - End of Year		2.58%	7.27%	7.27%	2.58%
UGI International LLC
Short-term Debt [Line Items]
Total Capacity | €				€ 300,000,000	€ 300,000,000
Borrowings Outstanding | €				0	0
Letters of Credit and Guarantees Outstanding | €				0	0
Available Borrowing Capacity | €				€ 300,000,000	€ 300,000,000
Energy Services
Short-term Debt [Line Items]
Total Capacity		$ 260,000,000	$ 260,000,000
Borrowings Outstanding		0	0
Letters of Credit and Guarantees Outstanding		0	0
Available Borrowing Capacity		260,000,000	260,000,000
UGI Utilities
Short-term Debt [Line Items]
Total Capacity		350,000,000	350,000,000
Borrowings Outstanding		130,000,000	151,000,000
Letters of Credit and Guarantees Outstanding		0	0
Available Borrowing Capacity		$ 220,000,000	$ 199,000,000
Weighted Average Interest Rate - End of Year		1.35%	4.37%	4.37%	1.35%
UGI Corporation
Short-term Debt [Line Items]
Total Capacity		$ 300,000,000	$ 300,000,000
Borrowings Outstanding		185,000,000	252,000,000
Letters of Credit and Guarantees Outstanding		0	0
Available Borrowing Capacity		$ 115,000,000	$ 48,000,000
Weighted Average Interest Rate - End of Year		3.27%			3.27%
Repayment of debt		$ 70,000,000
UGI Corporation | Subsequent Event
Short-term Debt [Line Items]
Repayment of debt	$ 87,000,000
UGI Corporation | Line of Credit
Short-term Debt [Line Items]
Weighted Average Interest Rate - End of Year			5.62%	5.62%
UGI Corporation | 2021 UGI Corporation Senior Credit Facility | Line of Credit
Short-term Debt [Line Items]
Repayment of debt		70,000,000
UGI Corporation | 2021 UGI Corporation Senior Credit Facility | Line of Credit | Letter of Credit
Short-term Debt [Line Items]
Total Capacity			$ 10,000,000
UGI Corporation | 2021 UGI Corporation Senior Credit Facility | Line of Credit | Subsequent Event
Short-term Debt [Line Items]
Repayment of debt	$ 87,000,000
Mountaineer
Short-term Debt [Line Items]
Total Capacity		100,000,000	100,000,000
Borrowings Outstanding		67,000,000	85,000,000
Letters of Credit and Guarantees Outstanding		0	0
Available Borrowing Capacity		$ 33,000,000	$ 15,000,000
Weighted Average Interest Rate - End of Year			3.82%	3.82%
Mountaineer | Line of Credit | Letter of Credit
Short-term Debt [Line Items]
Total Capacity			$ 20,000,000

Debt - Schedule of Short-term D

Debt - Schedule of Short-term Debt (Footnotes) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2022	Sep. 28, 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
Mountaineer
Short-term Debt [Line Items]
Maximum borrowing capacity	100,000,000	100,000,000
UGI Corporation
Short-term Debt [Line Items]
Maximum borrowing capacity	300,000,000	300,000,000
Repayment of debt	70,000,000
UGI Utilities
Short-term Debt [Line Items]
Maximum borrowing capacity	350,000,000	350,000,000
Line of Credit | AmeriGas OLP | Letter of Credit | AmeriGas OLP Credit Agreement
Short-term Debt [Line Items]
Maximum borrowing capacity	150,000,000	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 | 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	$ 70,000,000
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
Line of Credit | UGI Utilities | Letter of Credit | UGI Utilities, Inc. Credit Agreement
Short-term Debt [Line Items]
Maximum borrowing capacity		$ 100,000,000

Debt - Accounts Receivable Secu

Debt - Accounts Receivable Securitization Facility (Details) - USD ($)	6 Months Ended
	Oct. 20, 2023	Apr. 30, 2023
Energy Services | Receivables Facility | Energy Services Receivables Facility | Forecast
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 75,000,000	$ 150,000,000

Debt - Schedule of Receivables

Debt - Schedule of Receivables Facility (Details) - Energy Services - Receivables Facility - Energy Services Receivables Facility - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Short-term Debt [Line Items]
Trade receivables transferred to ESFC during the year	$ 2,221	$ 1,353	$ 1,046
ESFC trade receivables sold to the bank during the year	152	308	182
ESFC trade receivables - end of year	$ 101	61	$ 50
Outstanding balance of trade receivables sold		$ 0

Debt - Schedule of Long-term De

Debt - Schedule of Long-term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2022	Sep. 30, 2021
Debt Instrument [Line Items]
Total long-term debt	$ 6,632	$ 6,449
Less: current maturities	(149)	(110)
Total long-term debt due after one year	6,483	6,339
AmeriGas Propane
Debt Instrument [Line Items]
Unamortized debt issuance costs	(12)	(16)
Total long-term debt	2,563	2,560
AmeriGas Propane | Other
Debt Instrument [Line Items]
Long-term debt, gross	$ 0	1
AmeriGas Propane | Senior Notes | 5.50% due May 2025
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	5.50%
Long-term debt, gross	$ 700	700
AmeriGas Propane | Senior Notes | 5.875% due August 2026
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	5.875%
Long-term debt, gross	$ 675	675
AmeriGas Propane | Senior Notes | 5.625% due May 2024
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	5.625%
Long-term debt, gross	$ 675	675
AmeriGas Propane | Senior Notes | 5.75% due May 2027
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	5.75%
Long-term debt, gross	$ 525	525
UGI International
Debt Instrument [Line Items]
Unamortized debt issuance costs	(6)	(5)
Total long-term debt	$ 682	770
UGI International | Senior Notes | 3.25% Senior Notes due November 2025
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	3.25%
Long-term debt, gross	$ 0	405
UGI International | Senior Notes | 2.50% Senior Notes due December 2029
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	2.50%
Long-term debt, gross	$ 392	0
UGI International | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	2	23
UGI International | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	294	347
Midstream & Marketing
Debt Instrument [Line Items]
Unamortized debt issuance costs	(7)	(10)
Total long-term debt	710	716
Midstream & Marketing | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	40	42
Midstream & Marketing | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	677	684
Utilities
Debt Instrument [Line Items]
Unamortized debt issuance costs	(6)	(6)
Total long-term debt	1,656	1,451
Utilities | Mountaineer senior notes
Debt Instrument [Line Items]
Long-term debt, gross	$ 201	164
Utilities | Senior Notes | 4.12% due September 2046
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	4.12%
Long-term debt, gross	$ 200	200
Utilities | Senior Notes | 4.98% due March 2044
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	4.98%
Long-term debt, gross	$ 175	175
Utilities | Senior Notes | 3.12% due April 2050
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	3.12%
Long-term debt, gross	$ 150	150
Utilities | Senior Notes | 4.55% due February 2049
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	4.55%
Long-term debt, gross	$ 150	150
Utilities | Senior Notes | 4.12% due October 2046
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	4.12%
Long-term debt, gross	$ 100	100
Utilities | Senior Notes | 6.21% due September 2036
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	6.21%
Long-term debt, gross	$ 100	100
Utilities | Senior Notes | 2.95% due June 2026
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	2.95%
Long-term debt, gross	$ 100	100
Utilities | Senior Notes | 1.59% due June 2026
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	1.59%
Long-term debt, gross	$ 100	100
Utilities | Senior Notes | 1.64% due September 2026
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	1.64%
Long-term debt, gross	$ 75	75
Utilities | Senior Notes | 4.75% due July 2032
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	4.75%
Long-term debt, gross	$ 90	0
Utilities | Senior Notes | 4.99% due September 2052
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	4.99%
Long-term debt, gross	$ 85	0
Utilities | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	1	1
Utilities | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	$ 95	102
Utilities | Medium-term Notes | 6.13% due October 2034
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	6.13%
Long-term debt, gross	$ 20	20
Utilities | Medium-term Notes | 6.50% due August 2033
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	6.50%
Long-term debt, gross	$ 20	20
UGI Corporation
Debt Instrument [Line Items]
Unamortized debt issuance costs	(2)	(5)
Total long-term debt	1,015	945
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	250	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	252	185
Other
Debt Instrument [Line Items]
Total long-term debt	$ 6	$ 7

Debt - Schedule of Long-term _2

Debt - Schedule of Long-term Debt (Footnotes) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Debt Instrument [Line Items]
Long-term debt	$ 6,632,000,000	$ 6,449,000,000
Senior Secured Notes | Mountaineer senior notes
Debt Instrument [Line Items]
Long-term debt	180,000,000	140,000,000
Unamortized premium	$ 21,000,000	24,000,000
Senior Secured Notes | Mountaineer senior notes | Minimum
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	3.50%
Senior Secured Notes | Mountaineer senior notes | Maximum
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	4.49%
AmeriGas Propane
Debt Instrument [Line Items]
Long-term debt	$ 2,563,000,000	2,560,000,000
UGI International
Debt Instrument [Line Items]
Long-term debt	$ 682,000,000	$ 770,000,000
UGI International | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	1.89%	1.89%
Midstream & Marketing
Debt Instrument [Line Items]
Long-term debt	$ 710,000,000	$ 716,000,000
Midstream & Marketing | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	5.13%	5.23%
Quarterly Installments	$ 2,000,000
Utilities
Debt Instrument [Line Items]
Long-term debt	$ 1,656,000,000	$ 1,451,000,000
Utilities | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	3.92%	4%
Quarterly Installments	$ 2,000,000
UGI Corporation
Debt Instrument [Line Items]
Long-term debt	$ 1,015,000,000	$ 945,000,000
Weighted Average Interest Rate - End of Year		3.27%
UGI Corporation | Term Loan | 3-year Term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	2.67%	3.26%
UGI Corporation | Term Loan | 5-year Term Loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	4.15%	3.56%
Quarterly Installments	$ 9,000,000
UGI Corporation | Term Loan | 7-Year Term Loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	3.53%	1.88%
UGI Corporation | Line of Credit
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	5.61%	3.27%
Weighted Average Interest Rate - End of Year	5.62%

Debt - Schedule of Principal Re

Debt - Schedule of Principal Repayments of Long-term Debt (Details) - USD ($) $ in Millions	2 Months Ended	12 Months Ended
	Nov. 21, 2022	Sep. 30, 2021	Sep. 30, 2022
Debt Instrument [Line Items]
2023			$ 149
2024			1,359
2025			1,228
2026			1,612
2027			595
AmeriGas Propane
Debt Instrument [Line Items]
2023			0
2024			675
2025			700
2026			675
2027			525
UGI International
Debt Instrument [Line Items]
2023			1
2024			294
2025			0
2026			0
2027			0
Midstream & Marketing
Debt Instrument [Line Items]
2023			10
2024			7
2025			7
2026			656
2027			0
Utilities
Debt Instrument [Line Items]
2023			7
2024			6
2025			6
2026			281
2027			70
UGI Corporation
Debt Instrument [Line Items]
2023			125
2024			377
2025			515
2026			0
2027			0
Repayment of debt		$ 70
UGI Corporation | Subsequent Event
Debt Instrument [Line Items]
Repayment of debt	$ 87
Other
Debt Instrument [Line Items]
2023			6
2024			0
2025			0
2026			0
2027			$ 0

Debt - Restricted Net Assets (D

Debt - Restricted Net Assets (Details) $ in Millions	Sep. 30, 2022 USD ($)
Debt Disclosure [Abstract]
Restricted net assets	$ 2,900

Income Taxes - Income Before In

Income Taxes - Income Before Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Domestic	$ 362	$ 647	$ 424
Foreign	1,025	1,342	243
Income before income taxes	$ 1,387	$ 1,989	$ 667

Income Taxes - Provisions for I

Income Taxes - Provisions for Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Current expense (benefit):
Federal	$ 24	$ (48)	$ (85)
State	18	7	4
Foreign	50	85	70
Total current expense (benefit)	92	44	(11)
Deferred expense (benefit):
Federal	45	168	135
State	(17)	48	19
Foreign	193	262	(8)
Total deferred expense	221	478	146
Total income tax expense	$ 313	$ 522	$ 135

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($)	2 Months Ended	12 Months Ended
	Nov. 21, 2022	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Income Tax Examination [Line Items]
Foreign tax credits		$ 5,000,000	$ 0	$ 0
Foreign tax credit carryforwards		76,000,000	79,000,000
Net operating loss carryback			15,000,000	32,000,000
Income taxes receivable		128,000,000	128,000,000
GILTI taxes		3,000,000	8,000,000	0
Deferred tax assets relating to operating loss carryforwards		48,000,000	53,000,000
Increase (decrease) in valuation allowance		3,000,000	33,000,000
Unrecognized tax benefits if recognized would impact the reported effective tax rate		4,000,000	4,000,000	4,000,000
Future capital losses from PennEast and Hudson investments
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance			30,000,000
State Tax Rate Changes
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance		4,000,000
Future FTC's realizable
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance		6,000,000	10,000,000
Notional interest deduction carryover
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance		17,000,000	10,000,000
Foreign Net Operating Loss Carry Forwards
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance		4,000,000
AmeriGas Propane
Income Tax Examination [Line Items]
Operating loss carryforwards		6,000,000
Other Subsidiaries
Income Tax Examination [Line Items]
Deferred tax assets relating to operating loss carryforwards		48,000,000
Fiscal 2020 carryback to Fiscal 2015
Income Tax Examination [Line Items]
Income taxes receivable		90,000,000	37,000,000	90,000,000
Fiscal 2020 carryback to Fiscal 2015 | Subsequent Event
Income Tax Examination [Line Items]
Income tax refunds	$ 75,000,000
Foreign | Flaga
Income Tax Examination [Line Items]
Operating loss carryforwards		5,000,000
Foreign | UGI France
Income Tax Examination [Line Items]
Operating loss carryforwards		30,000,000
Foreign | Italy
Income Tax Examination [Line Items]
Foreign tax credit carryforwards			23,000,000
Foreign | Netherlands
Income Tax Examination [Line Items]
Operating loss carryforwards		10,000,000
Effects of tax rate changes – State, net of federal benefit
Income Tax Examination [Line Items]
Benefit from legislation		20,000,000
Decrease in income tax expense due to state tax flow through of accelerated depreciation		10,000,000	$ 9,000,000	$ 11,000,000
Operating loss carryforwards		787,000,000
Domestic | Mountaintop Energy Holding, LLC
Income Tax Examination [Line Items]
Operating loss carryforwards		$ 16,000,000

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of U.S. Federal Statutory Tax Rate to Effective Tax Rate (Details)	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Operating Loss Carryforwards [Line Items]
U.S. federal statutory tax rate	21%	21%	21%
Difference in tax rate due to:
State, net of federal benefit	1.50%	1.90%	2.80%
Valuation allowance adjustments	(0.50%)	1%	0%
Effects of foreign operations	4.40%	4.60%	1.30%
Excess tax benefits on share-based payments	(0.30%)	(0.10%)	(0.20%)
Other, net	0.20%	(0.10%)	(0.30%)
Effective tax rate	22.60%	26.20%	20.20%
Effects of U.S. tax legislation
Difference in tax rate due to:
Effect of tax rate change	0%	(0.80%)	(4.70%)
Effects of tax rate changes - International
Difference in tax rate due to:
Effect of tax rate change	(2.30%)	(1.30%)	0.30%
Effects of tax rate changes – State, net of federal benefit
Difference in tax rate due to:
Effect of tax rate change	(1.40%)	0%	0%

Income Taxes - Deferred Tax Lia

Income Taxes - Deferred Tax Liabilities (Assets) (Details) - USD ($) $ in Millions	Sep. 30, 2022	Sep. 30, 2021
Income Tax Disclosure [Abstract]
Excess book basis over tax basis of property, plant and equipment	$ 867	$ 937
Utility regulatory assets	106	105
Intangible assets and goodwill	75	77
Derivative instrument assets	514	322
Other	33	36
Gross deferred tax liabilities	1,595	1,477
Investment in AmeriGas Partners	(79)	(102)
Pension plan liabilities	(21)	(29)
Employee-related benefits	(38)	(45)
Operating loss carryforwards	(48)	(53)
Foreign tax credit carryforwards	(76)	(79)
Utility regulatory liabilities	(85)	(102)
Utility environmental liabilities	(15)	(16)
Other	(125)	(107)
Gross deferred tax assets	(487)	(533)
Deferred tax assets valuation allowance	141	138
Net deferred tax liabilities	$ 1,249	$ 1,082

Employee Retirement Plans - Nar

Employee Retirement Plans - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Defined Benefit Plan Disclosure [Line Items]
ABO	$ 22	$ 31
Fair value of plan assets	16	19
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Contribution made to Pension Plan	15	14
Projected benefit obligations of unfunded and non qualified supplemental executive retirement plans	633	870	$ 782
Costs associated with the plans	(1)	8	11
Net actuarial loss	(17)	13
Payments for defined benefit retirement plan	34	30
Supplemental Employee Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligations of unfunded and non qualified supplemental executive retirement plans	44	57
Costs associated with the plans	0	0
Net actuarial loss	1	10
Payments for defined benefit retirement plan	0	12	0
Fair value of pension and other postretirement benefit contributions	31	44
U.S. | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Contribution made to Pension Plan	$ 14	$ 13	$ 13

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, 2022	Sep. 30, 2021	Sep. 30, 2020
Change in benefit obligations:
Benefit obligations — beginning of year	$ 870	$ 782
Service cost	16	12	$ 11
Interest cost	26	22	23
Actuarial gain	(240)	(30)
Plan amendments	1	2
Acquisitions	0	114
Foreign currency	(6)	(1)
Benefits paid	(34)	(31)
Benefit obligations — end of year	633	870	782
Change in plan assets:
Fair value of plan assets — beginning of year	736	585
Actual (loss) gain on plan assets	(173)	75
Foreign currency	(3)	0
Employer contributions	15	14
Acquisitions	0	92
Benefits paid	(34)	(30)
Fair value of plan assets — end of year	541	736	$ 585
Funded status of the plans — end of year	(92)	(134)
Amounts recorded in UGI Corporation stockholders’ equity (pre-tax):
Prior service cost	3	3
Net actuarial (gain) loss	(17)	13
Total	(14)	16
Amounts recorded in regulatory assets and liabilities (pre-tax):
Net actuarial loss	114	108
Total	114	108
ABO for the pension plans	$ 570	$ 756

Employee Retirement Plans - Act

Employee Retirement Plans - Actuarial Assumptions for Domestic Plans (Details) - Pension Benefits	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Weighted-average assumptions:
Discount rate – benefit obligations	5.70%	3.13%	2.90%
Discount rate – benefit cost	3.13%	2.90%	3.30%
Expected return on plan assets	7.10%	7.10%	7.20%
Rate of increase in salary levels	3.25%	3.25%	3.25%

Employee Retirement Plans - Net

Employee Retirement Plans - Net Periodic Pension Costs (Details) - Pension Benefits - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 16	$ 12	$ 11
Interest cost	26	22	23
Expected return on assets	(50)	(40)	(38)
Curtailment gain	0	0	(1)
Amortization of:
Prior service cost	0	0	1
Actuarial loss	7	14	15
Net benefit (income) cost	$ (1)	$ 8	$ 11

Employee Retirement Plans - Exp

Employee Retirement Plans - Expected Payments for Pension Benefits and Other Postretirement Welfare Benefits (Details) - Pension Benefits $ in Millions	Sep. 30, 2022 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Fiscal 2023	$ 37
Fiscal 2024	38
Fiscal 2025	40
Fiscal 2026	41
Fiscal 2027	43
Fiscal 2028 - 2032	$ 229

Employee Retirement Plans - Pen

Employee Retirement Plans - Pension Plans Assets (Details) - Pension Benefits - U.S.	Sep. 30, 2022	Sep. 30, 2021
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	100%	100%
Target Asset Allocation	100%	100%
Target allocation range	5%
U.S. equities
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	26.50%	22.20%
Target Asset Allocation	24.70%	25.30%
Non-U.S. equities
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	20.90%	21.70%
Target Asset Allocation	20.90%	21.40%
Global equities
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	13.80%	16%
Target Asset Allocation	13.10%	13.10%
Equity investments
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	61.20%	59.90%
Target Asset Allocation	58.70%	59.80%
Fixed income funds & cash equivalents
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	35.50%	36.40%
Target Asset Allocation	35%	34.40%
Alternative investments
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	3.30%	3.70%
Target Asset Allocation	6.30%	5.80%

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, 2022	Sep. 30, 2021	Sep. 30, 2020
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 541	$ 736	$ 585
U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	525	717
U.S. | U.S. equities
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	26	35
U.S. | UGI Corporation Common Stock
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	26	35
U.S. | Total common collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	482	655
U.S. | U.S. equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	113	124
U.S. | Non-U.S. equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	110	155
U.S. | Global equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	72	115
U.S. | Bond index mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	177	254
U.S. | Cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	10	7
U.S. | Alternative investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 17	$ 27

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, 2022	Sep. 30, 2021	Sep. 30, 2020
Defined Contribution Plan Disclosure [Line Items]
Costs of benefits under savings plans	$ 21	$ 21	$ 21
Total fair values of grantor trust investment assets	$ 7	$ 9

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, 2022	Sep. 30, 2021
Regulatory Assets [Line Items]
Regulatory assets	$ 340	$ 397
Regulatory Liabilities [Line Items]
Regulatory liabilities	335	388
Postretirement benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities	11	13
Deferred fuel and power refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities	3	36
State income tax benefits — distribution system repairs
Regulatory Liabilities [Line Items]
Regulatory liabilities	38	32
Excess federal deferred income taxes
Regulatory Liabilities [Line Items]
Regulatory liabilities	279	287
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities	4	20
Income taxes recoverable
Regulatory Assets [Line Items]
Regulatory assets	83	143
Underfunded pension plans
Regulatory Assets [Line Items]
Regulatory assets	114	108
Environmental costs
Regulatory Assets [Line Items]
Regulatory assets	37	58
Deferred fuel and power costs
Regulatory Assets [Line Items]
Regulatory assets	32	11
Removal costs, net
Regulatory Assets [Line Items]
Regulatory assets	22	24
Other
Regulatory Assets [Line Items]
Regulatory assets	$ 52	$ 53

Utility Regulatory Assets and_4

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

12 Months Ended

Oct. 01, 2023

Oct. 29, 2022

Sep. 15, 2022

Jan. 28, 2022

Nov. 09, 2021

Feb. 08, 2021

Oct. 08, 2020

Jan. 28, 2020

Oct. 27, 2018

Oct. 19, 2016

Sep. 30, 2022

Sep. 30, 2021

Regulatory Assets [Line Items]

Regulatory asset, amortization period

20 years

Pennsylvania Public Utility Commission | UGI Gas

Regulatory Assets [Line Items]

Regulatory asset, amortization period

10 years

Requested rate increase

$ 9,000,000

$ 75,000,000

Approved rate increase, amount

$ 6,000,000

$ 20,000,000

Property, plant and equipment, net threshold

2,875,000,000

Pennsylvania Public Utility Commission | UGI Gas | Beginning January 1, 2021

Regulatory Assets [Line Items]

Approved rate increase, amount

10,000,000

Pennsylvania Public Utility Commission | UGI Gas | Beginning July 1, 2021

Regulatory Assets [Line Items]

Approved rate increase, amount

$ 10,000,000

Pennsylvania Public Utility Commission | Regulated natural gas utilities

Regulatory Assets [Line Items]

Requested rate increase

$ 83,000,000

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

Regulatory Assets [Line Items]

Public utilities

5 years

Weather condition rate

3%

Property, plant and equipment, net threshold

$ 3,368,000

Approved rate increase, amount

$ 49,000,000

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

Regulatory Assets [Line Items]

Requested rate increase

$ 38,000,000

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

Regulatory Assets [Line Items]

Requested rate increase

$ 11,000,000

Postretirement benefits

Regulatory Assets [Line Items]

Regulatory liability, amortization period

10 years

Regulated natural gas utilities

Regulatory Assets [Line Items]

Fair value of unrealized gains (losses)

$ 5,000,000

$ 35,000,000

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, 2022	Sep. 30, 2021
Public Utilities, Inventory
Total inventories	$ 665	$ 469
Non-utility LPG and natural gas
Public Utilities, Inventory
Total inventories	335	278
Gas Utility natural gas
Public Utilities, Inventory
Total inventories	166	68
Energy certificates
Public Utilities, Inventory
Total inventories	70	53
Materials, supplies and other
Public Utilities, Inventory
Total inventories	$ 94	$ 70

Property, Plant and Equipment -

Property, Plant and Equipment - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Property, Plant and Equipment
Utility	$ 5,550	$ 5,022
Non-utility	6,656	6,486
Total property, plant and equipment	12,206	11,508
Distribution
Property, Plant and Equipment
Utility	4,746	4,306
Transmission
Property, Plant and Equipment
Utility	123	111
General and other
Property, Plant and Equipment
Utility	557	507
Work in process
Property, Plant and Equipment
Utility	124	98
Non-utility	53	76
Land
Property, Plant and Equipment
Non-utility	179	186
Buildings and improvements
Property, Plant and Equipment
Non-utility	$ 426	436
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	$ 234	232
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	$ 3,645	3,785
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	$ 216	211
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	$ 1,523	1,218
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	$ 380	$ 342
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, 2022	Sep. 30, 2021	Sep. 30, 2020
Property, Plant and Equipment
Depreciation	$ 460	$ 437	$ 416
Regulated natural gas utilities
Property, Plant and Equipment
Average composite depreciation rates (as a percentage)	2.60%	2.60%	2.50%
Electric Utility
Property, Plant and Equipment
Average composite depreciation rates (as a percentage)	2.40%	2.30%	2.20%

Goodwill and Intangible Asset_2

Goodwill and Intangible Assets - Changes in the Carrying Amount of Goodwill (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Goodwill
Balance at beginning of period	$ 3,770	$ 3,518
Acquisitions		261
Purchase accounting adjustments	(5)	1
Foreign currency translation	(153)	(10)
Balance at end of period	3,612	3,770
AmeriGas Propane
Goodwill
Balance at beginning of period	2,004	2,004
Acquisitions		0
Purchase accounting adjustments	0	0
Foreign currency translation	0	0
Balance at end of period	2,004	2,004
UGI International
Goodwill
Balance at beginning of period	993	997
Acquisitions		6
Purchase accounting adjustments	0	0
Foreign currency translation	(153)	(10)
Balance at end of period	840	993
Midstream & Marketing
Goodwill
Balance at beginning of period	336	335
Acquisitions		0
Purchase accounting adjustments	0	1
Foreign currency translation	0	0
Balance at end of period	336	336
Utilities
Goodwill
Balance at beginning of period	437	182
Acquisitions		255
Purchase accounting adjustments	(5)	0
Foreign currency translation	0	0
Balance at end of period	$ 432	$ 437

Goodwill and Intangible Asset_3

Goodwill and Intangible Assets - Components of Intangible Assets (Details) - USD ($) $ in Millions	Sep. 30, 2022	Sep. 30, 2021
Goodwill and Intangible Assets Disclosure [Abstract]
Customer relationships	$ 1,006	$ 1,054
Trademarks and tradenames	11	12
Noncompete agreements and other	71	75
Accumulated amortization	(629)	(607)
Intangible assets, net (definite-lived)	459	534
Trademarks and tradenames (indefinite-lived)	41	49
Total intangible assets, net	$ 500	$ 583

Goodwill and Intangible Asset_4

Goodwill and Intangible Assets - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Goodwill and Intangible Assets Disclosure [Abstract]
Impairment charges	$ 0	$ 20
Amortization expense of intangible assets	61	$ 76	$ 83
Fiscal 2023	54
Fiscal 2024	53
Fiscal 2025	52
Fiscal 2026	51
Fiscal 2027	$ 29

Equity - Narrative (Details)

Equity - Narrative (Details) - USD ($)				12 Months Ended
	Jun. 01, 2024	Feb. 02, 2022	May 25, 2021	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020	May 17, 2021
Class of Stock [Line Items]
Preferred Stock, shares authorized (in shares)				5,000,000	5,000,000
Beginning balance - shares 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
Accretion of purchase contract adjustment liability					$ 0
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)		8,000,000
Stock repurchase program period		4 years
Repurchases of common stock - Treasury (in shares)				(900,000)	0	(950,000)
Repurchases of common stock				$ 38,000,000		$ 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

Equity - Common Stock Share Act

Equity - Common Stock Share Activity (Details) - shares	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Class of Stock [Line Items]
Beginning balance - shares Issued (in shares)	220,000	0
Ending balance - shares Issued (in shares)		220,000	0
Ending balance - shares outstanding (in shares)	0	0
Preferred Stock
Class of Stock [Line Items]
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	0
Common Stock
Class of Stock [Line Items]
Beginning balance - shares Issued (in shares)	209,843,296	209,514,044	209,304,129
Beginning balance - shares Outstanding (in shares)	209,216,135	208,354,438	209,004,789
Employee and director plans - shares Issued/Treasury (in shares)	717,198	329,252	209,915
Treasury stock acquired (in shares)	900,000	0	950,000
Reacquired common stock – employee and director plans	(250,273)	(21,870)	(90,316)
Ending balance - shares Issued (in shares)	210,560,494	209,843,296	209,514,044
Ending balance - shares Outstanding (in shares)	209,582,212	209,216,135	208,354,438
Employee and director plans - shares Outstanding (in shares)	1,516,350	883,567	389,965
Common Stock | Treasury stock
Class of Stock [Line Items]
Beginning balance - shares Outstanding (in shares)	(627,161)	(1,159,606)	(299,340)
Employee and director plans - shares Issued/Treasury (in shares)	799,152	554,315	180,050
Treasury stock acquired (in shares)	900,000		950,000
Reacquired common stock – employee and director plans	(250,273)	(21,870)	(90,316)
Ending balance - shares Outstanding (in shares)	(978,282)	(627,161)	(1,159,606)

Equity-Based Compensation - Nar

Equity-Based Compensation - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions		12 Months Ended
	Jan. 29, 2021	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Share-based Compensation Arrangement by Share-based Payment Award
Pre-tax equity-based compensation expense		$ 15	$ 21	$ 15
After tax equity-based compensation expense		$ 11	$ 15	$ 11
Weighted-average fair value of stock option granted under stock plans (in dollars per share)		$ 8.47	$ 6.05	$ 5.58
Options outstanding (in shares)		9,004,896
Options exercisable (in shares)		7,179,583
Weighted average exercise price (in dollars per share)		$ 42.23
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 9 months 18 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)		$ 51.24	$ 41.41	$ 41.47
Award performance period		3 years
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 Performance Units and Stock Units
Share-based Compensation Arrangement by Share-based Payment Award
Unrecognized compensation cost associated with unvested unit awards		$ 24
Weighted-average period of recognition for unvested unit awards		2 years
UGI Unit awards outstanding (in shares)		1,376,371
Weighted average grant date fair value, outstanding (in dollars per share)		$ 42.31
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)		18,015,916

Partnership Distributions (Deta

Partnership Distributions (Details)	12 Months Ended
	Sep. 30, 2022
Distributions Made to Members or Limited Partners [Abstract]
Partnership distributions to partners (days following quarter end)	45 days

Leases - Addition Details (Deta

Leases - Addition Details (Details)	12 Months Ended
	Sep. 30, 2022 USD ($)
Lessor, Lease, Description [Line Items]
Operating leases not yet commenced	$ 0
Finance leases not yet commenced	$ 0
Renewal term (up to)	9 years
AmeriGas Propane | Lease Liability Total | Segment Concentration Risk
Lessor, Lease, Description [Line Items]
Risk percent	85%
Minimum | Vehicles
Lessor, Lease, Description [Line Items]
Operating lease remaining lease term	1 year
Maximum | Vehicles
Lessor, Lease, Description [Line Items]
Operating lease remaining lease term	10 years

Leases - Assets and Liabilities

Leases - Assets and Liabilities Lessee (Details) - USD ($) $ in Millions	Sep. 30, 2022	Sep. 30, 2021
ROU assets:
Operating lease ROU assets	$ 368	$ 390
Finance lease ROU assets	48	49
Total ROU assets	$ 416	$ 439
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	$ 82	$ 81
Operating lease liabilities — noncurrent	294	318
Finance lease liabilities — current	4	4
Finance lease liabilities — noncurrent	41	41
Total lease liabilities	$ 421	$ 444
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, 2022	Sep. 30, 2021	Sep. 30, 2020
Leases [Abstract]
Operating lease cost	$ 96	$ 101	$ 102
Finance lease cost:
Amortization of ROU assets	4	4	5
Interest on lease liabilities	3	3	3
Variable lease cost	6	4	5
Short-term lease cost	2	2	3
Total lease cost	111	114	118
Cash paid related to lease liabilities:
Operating cash flows — operating leases	95	99	103
Operating cash flows — finance leases	3	3	3
Financing cash flows — finance leases	2	3	4
Non-cash lease liability activities:
ROU assets obtained in exchange for operating lease liabilities	72	85	506
ROU assets obtained in exchange for finance lease liabilities	$ 2	$ 1	$ 22
Weighted-average remaining lease term (in years)
Operating leases	6 years	6 years 3 months 18 days
Finance leases	3 years 8 months 12 days	2 years 4 months 24 days
Weighted-average discount rate (%)
Operating leases	3.60%	3.60%
Finance leases	1.80%	1.50%

Leases - Operating and Finance

Leases - Operating and Finance Leases, Liability, Maturity (Details) $ in Millions	Sep. 30, 2022 USD ($)
Operating leases
2023	$ 93
2024	81
2025	64
2026	52
2027	41
After 2026	86
Total Lease Payments	417
Imputed Interest	(41)
Lease Liabilities	376
Finance leases
2023	4
2024	4
2025	4
2026	4
2027	3
After 2026	77
Total Lease Payments	96
Imputed Interest	(51)
Lease Liabilities	$ 45

Commitments and Contingencies -

Commitments and Contingencies - Contingencies (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017 record_of_decision	Sep. 30, 2022 USD ($) subsidiary	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2017 USD ($)
Loss Contingencies [Line Items]
Environmental expenditures cap during year		$ 5
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		$ 53	$ 50
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, 2022	Sep. 30, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	$ 2,418	$ 1,687
Derivative instrument, Liabilities	515	317
Non-qualified supplemental postretirement grantor trust investments	43	53
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-qualified supplemental postretirement grantor trust investments	43	53
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	2,233	1,649
Derivative instrument, Liabilities	513	280
Commodity contracts | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	938	641
Derivative instrument, Liabilities	377	264
Commodity contracts | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	1,268	1,008
Derivative instrument, Liabilities	136	16
Commodity contracts | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	27	0
Derivative instrument, Liabilities	0	0
Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	119	38
Derivative instrument, Liabilities	2	8
Foreign currency contracts | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	0	0
Derivative instrument, Liabilities	0	0
Foreign currency contracts | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	119	38
Derivative instrument, Liabilities	2	8
Foreign currency contracts | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	0	0
Derivative instrument, Liabilities	0	0
Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	66
Derivative instrument, Liabilities		29
Interest rate contracts | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	0
Derivative instrument, Liabilities		0
Interest rate contracts | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	66
Derivative instrument, Liabilities		29
Interest rate contracts | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	$ 0
Derivative instrument, Liabilities		$ 0

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - Level 3 - Commodity contracts $ in Millions	Sep. 30, 2022 USD ($)
Minimum
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Unobservable inputs reconciliation	$ 7
Maximum
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Unobservable inputs reconciliation	$ 27

Fair Value Measurements - Long-

Fair Value Measurements - Long-term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2022	Sep. 30, 2021
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,665	$ 6,491
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,189	$ 6,996

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Narrative (Details)	12 Months Ended
	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2022 EUR (€)	Dec. 07, 2021 EUR (€)	Sep. 30, 2021 EUR (€)
Derivative [Line Items]
Pre-tax net losses associated with interest rate hedges	$ 3,000,000
Pre-tax (losses) gains associated with net investment hedges	123,000,000	$ 9,000,000	$ (53,000,000)
Maximum amount of loss	2,418,000,000
Cash collateral received	(398,000,000)	(468,000,000)
3.25% Senior Notes Due November 2025 | Senior Notes | UGI International LLC
Derivative [Line Items]
Stated interest rate (as a percentage)					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	$ 465,000,000	$ 509,000,000		€ 411,000,000		€ 173,000,000
Foreign currency contracts | UGI International LLC | Net Investment Hedging
Derivative [Line Items]
Notional amount | €					€ 93,000,000
Pre-tax (losses) gains associated with net investment hedges	$ 69,000,000

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, 2022 USD ($) DTH kWh gal	Sep. 30, 2021 USD ($) DTH kWh gal	Sep. 30, 2022 EUR (€) DTH	Sep. 30, 2021 EUR (€) DTH
Commodity contracts | Propane
Derivative [Line Items]
Notional Amounts (in millions) | gal	874	708
Commodity contracts | Electricity
Derivative [Line Items]
Notional Amounts (in millions) | kWh	2,446	4,302
Natural gas futures, forward, basis swap, options and pipeline contracts | Natural Gas
Derivative [Line Items]
Notional amount (in units)	363	355	363	355
Interest rate swaps
Derivative [Line Items]
Notional amount	$ 1,358	$ 1,421	€ 300	€ 300
Forward foreign exchange contracts
Derivative [Line Items]
Notional amount	$ 465	$ 509	€ 411	€ 173
Regulated Utility Operations | Commodity contracts | Natural Gas
Derivative [Line Items]
Notional amount (in units)	19	20	19	20

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, 2022	Sep. 30, 2021
Derivative assets:
Fair value of derivative instruments	$ 2,418	$ 1,687
Gross amounts offset in the balance sheet	(295)	(216)
Cash collateral received	(398)	(468)
Total derivative assets – net	1,725	1,003
Derivative liabilities:
Total derivative liabilities – gross	(515)	(317)
Gross amounts offset in the balance sheet	295	216
Cash collateral pledged	7	3
Total derivative liabilities – net	(213)	(98)
Foreign currency contracts
Derivative assets:
Fair value of derivative instruments	119	38
Derivative liabilities:
Total derivative liabilities – gross	(2)	(8)
Commodity contract - subject to PGC and DS mechanisms
Derivative assets:
Fair value of derivative instruments	31	58
Derivative liabilities:
Total derivative liabilities – gross	(26)	(23)
Commodity contracts
Derivative assets:
Fair value of derivative instruments	2,233	1,649
Derivative liabilities:
Total derivative liabilities – gross	(513)	(280)
Interest rate contracts
Derivative assets:
Fair value of derivative instruments	66
Derivative liabilities:
Total derivative liabilities – gross		(29)
Derivatives designated as hedging instruments
Derivative assets:
Fair value of derivative instruments	123	20
Derivatives designated as hedging instruments | Foreign currency contracts
Derivative assets:
Fair value of derivative instruments	57	20
Derivatives designated as hedging instruments | Interest rate contracts
Derivative assets:
Fair value of derivative instruments	66	0
Derivative liabilities:
Total derivative liabilities – gross	0	(29)
Derivatives not designated as hedging instruments
Derivative assets:
Fair value of derivative instruments	2,264	1,609
Derivative liabilities:
Total derivative liabilities – gross	(489)	(265)
Derivatives not designated as hedging instruments | Foreign currency contracts
Derivative assets:
Fair value of derivative instruments	62	18
Derivative liabilities:
Total derivative liabilities – gross	(2)	(8)
Derivatives not designated as hedging instruments | Commodity contracts
Derivative assets:
Fair value of derivative instruments	2,202	1,591
Derivative liabilities:
Total derivative liabilities – gross	$ (487)	$ (257)

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, 2022	Sep. 30, 2021	Sep. 30, 2020
Derivatives Not Designated as Hedging Instruments:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 1,236	$ 1,542	$ (42)
Derivatives Not Designated as Hedging Instruments: | Foreign currency contracts | Other non-operating income (expense), net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	63	9	(20)
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Revenues
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(9)	(17)	10
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	1,181	1,545	(32)
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Other operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	1	5	0
Cash Flow Hedges: | Interest rate contracts
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	91	4	(53)
Cash Flow Hedges: | Interest rate contracts | Interest expense
Derivative Instruments, Gain (Loss)
Gain (Loss) Reclassified from AOCI into Income	(7)	(25)	(13)
Net Investment Hedges: | Foreign currency contracts
Derivative Instruments, Gain (Loss)
Foreign currency contracts	$ 69	$ 4	$ (1)

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	$ 5,531	$ 4,137
Other comprehensive income (loss) before reclassification adjustments	(249)	(13)	$ 58
Amounts reclassified from AOCI	9	20	12
Other comprehensive income (loss) attributable to UGI	(240)	7	70
Balance, end of year	6,074	5,531	4,137
Postretirement Benefit Plans
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(17)	(26)	(26)
Other comprehensive income (loss) before reclassification adjustments	28	7	(3)
Amounts reclassified from AOCI	3	2	3
Other comprehensive income (loss) attributable to UGI	31	9	0
Balance, end of year	14	(17)	(26)
Derivative Instruments
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(33)	(54)	(25)
Other comprehensive income (loss) before reclassification adjustments	64	3	(38)
Amounts reclassified from AOCI	6	18	9
Other comprehensive income (loss) attributable to UGI	70	21	(29)
Balance, end of year	37	(33)	(54)
Foreign Currency
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(90)	(67)	(166)
Other comprehensive income (loss) before reclassification adjustments	(341)	(23)	99
Amounts reclassified from AOCI	0	0	0
Other comprehensive income (loss) attributable to UGI	(341)	(23)	99
Balance, end of year	(431)	(90)	(67)
Accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(140)	(147)	(217)
Balance, end of year	$ (380)	$ (140)	$ (147)

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, 2022	Sep. 30, 2021	Sep. 30, 2020
Component of Operating Income [Abstract]
Finance charges	$ 18	$ 17	$ 9
Gains on sales of fixed assets, net	33	11	5
Gain on early derivative termination	0	5	0
Interest and interest-related income	1	0	2
Other, net	27	0	5
Total other operating income, net	$ 79	$ 33	$ 21

Other Operating Income, Net a_4

Other Operating Income, Net and Other Non-Operating Income (Expense), Net - Other Non-Operating Income (Expense), Net (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Component of Operating Income [Abstract]
Gains (losses) on foreign currency contracts, net	$ 63	$ 9	$ (20)
Amortization of excluded components of certain net investment hedges	7	2	0
Pension and other postretirement plans non-service income, net	5	1	0
Total other non-operating income (expense), net	$ 75	$ 12	$ (20)

Equity Method Investments - Nar

Equity Method Investments - Narrative (Details)	1 Months Ended		12 Months Ended
	Jun. 30, 2021 USD ($)	Feb. 28, 2021 USD ($)	Sep. 30, 2022 USD ($) mi	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)
Schedule of Equity Method Investments [Line Items]
Equity method investments			$ 130,000,000	$ 174,000,000	$ 200,000,000
Equity in income of unconsolidated subsidiaries			(14,000,000)	(63,000,000)	$ 27,000,000
Pine Run Midstream L L C Member
Schedule of Equity Method Investments [Line Items]
Total purchase price		$ 205,000,000
Total cash paid		115,000,000
Liabilities incurred		$ 90,000,000
PennEast
Schedule of Equity Method Investments [Line Items]
Pretax impairment charge	$ 93,000,000
Equity in income of unconsolidated subsidiaries			9,000,000
PennEast | Level 2
Schedule of Equity Method Investments [Line Items]
Equity method investments			$ 0	0
PennEast | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Area of natural gas pipeline to be constructed (in miles) | mi			120
PennEast | UGI PennEast, LLC | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Ownership percent			20%
PennEast | Southern Company | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Ownership percent			20%
PennEast | New Jersey Resources | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Ownership percent			20%
PennEast | South Jersey Industries | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Ownership percent			20%
PennEast | Enbridge Inc | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Ownership percent			20%
Pennant
Schedule of Equity Method Investments [Line Items]
Equity method investments				$ 93,000,000
Pretax impairment charge			$ 44,000,000
Pennant | Energy Services
Schedule of Equity Method Investments [Line Items]
Ownership percent			47%	47%
Pine Run Midstream L L C Member
Schedule of Equity Method Investments [Line Items]
Equity method investments			$ 68,000,000	$ 60,000,000
Ownership percent			49%
Other Equity Investments
Schedule of Equity Method Investments [Line Items]
Pretax impairment charge			$ 62,000,000	$ 21,000,000

Segment Information - Narrative

Segment Information - Narrative (Details)	12 Months Ended
	Sep. 30, 2022 state segment
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, 2022	Sep. 30, 2021	Sep. 30, 2020
Segment Reporting Information [Line Items]
Revenues	$ 10,106	$ 7,447	$ 6,559
Cost of sales	5,973	2,614	3,149
Operating income	1,666	2,350	982
(Loss) income from equity investees	(14)	(63)	27
Loss on extinguishment of debt	(11)	0	0
Other non-operating income, net	75	12	(20)
Earnings (loss) before interest expense and income taxes	1,716	2,299	989
Interest expense	(329)	(310)	(322)
Income tax expense	(313)	(522)	(135)
Noncontrolling interests’ net (income) loss	(1)	0	0
Net income attributable to UGI Corporation	1,073	1,467	532
Depreciation and amortization	518	502	484
Total assets	17,575	16,723	13,985
Short-term borrowings	368	367	347
Capital expenditures (including the effects of accruals)	835	674	665
Investments in equity investees	130	174	200
Eliminations
Segment Reporting Information [Line Items]
Revenues	(477)	(291)	(232)
Cost of sales	(474)	(288)	(229)
Operating income	0	0	0
(Loss) income from equity investees	0	0	0
Loss on extinguishment of debt	0
Other non-operating income, net	0	0	0
Earnings (loss) 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 income attributable to UGI Corporation	0	0	0
Depreciation and amortization	0	0	0
Total assets	(203)	(241)	(282)
Short-term borrowings	0	0	0
Capital expenditures (including the effects of accruals)	0	0	0
Investments in equity investees	0	0	0
Eliminations | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	0	0	0
Eliminations | UGI International
Segment Reporting Information [Line Items]
Revenues	0	0	0
Eliminations | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	369	224	182
Eliminations | Utilities
Segment Reporting Information [Line Items]
Revenues	105	64	47
Operating Segments | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	2,943	2,614	2,381
Cost of sales	1,613	1,217	960
Operating income	307	385	373
(Loss) income from equity investees	0	0	0
Loss on extinguishment of debt	0
Other non-operating income, net	0	0	0
Earnings (loss) before interest expense and income taxes	307	385	373
Interest expense	(160)	(159)	(164)
Income tax expense	(35)	(58)	(53)
Noncontrolling interests’ net (income) loss	0
Net income attributable to UGI Corporation	112	168	156
Depreciation and amortization	177	173	178
Total assets	4,332	4,485	4,327
Short-term borrowings	131	170	186
Capital expenditures (including the effects of accruals)	128	130	135
Investments in equity investees	0	0	0
Operating Segments | UGI International
Segment Reporting Information [Line Items]
Revenues	3,686	2,651	2,127
Cost of sales	2,751	1,598	1,191
Operating income	237	314	241
(Loss) income from equity investees	(2)	0	0
Loss on extinguishment of debt	0
Other non-operating income, net	19	3	18
Earnings (loss) before interest expense and income taxes	254	317	259
Interest expense	(28)	(27)	(31)
Income tax expense	(50)	(69)	(55)
Noncontrolling interests’ net (income) loss	(1)
Net income attributable to UGI Corporation	175	221	173
Depreciation and amortization	116	134	125
Total assets	4,610	4,421	3,123
Short-term borrowings	1	0	1
Capital expenditures (including the effects of accruals)	107	107	89
Investments in equity investees	20	11	10
Operating Segments | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	2,326	1,406	1,247
Revenues from external customers	1,957	1,182	1,065
Cost of sales	1,876	1,033	892
Operating income	246	160	140
(Loss) income from equity investees	23	30	27
Loss on extinguishment of debt	0
Other non-operating income, net	0	0	1
Earnings (loss) before interest expense and income taxes	269	190	168
Interest expense	(41)	(42)	(42)
Income tax expense	(65)	(41)	(34)
Noncontrolling interests’ net (income) loss	0
Net income attributable to UGI Corporation	163	107	92
Depreciation and amortization	79	76	75
Total assets	3,286	3,010	2,775
Short-term borrowings	0	0	19
Capital expenditures (including the effects of accruals)	38	43	93
Investments in equity investees	109	163	190
Operating Segments | Utilities
Segment Reporting Information [Line Items]
Revenues	1,620	1,079	1,030
Revenues from external customers	1,515	1,015	983
Cost of sales	798	458	448
Operating income	327	241	229
(Loss) income from equity investees	0	0	0
Loss on extinguishment of debt	0
Other non-operating income, net	9	1	0
Earnings (loss) before interest expense and income taxes	336	242	229
Interest expense	(65)	(56)	(54)
Income tax expense	(65)	(42)	(39)
Noncontrolling interests’ net (income) loss	0
Net income attributable to UGI Corporation	206	144	136
Depreciation and amortization	144	119	105
Total assets	5,354	4,859	3,809
Short-term borrowings	236	197	141
Capital expenditures (including the effects of accruals)	562	394	348
Investments in equity investees	0	0	0
Corporate & Other
Segment Reporting Information [Line Items]
Revenues	8	(12)	6
Revenues from external customers	5	(15)	3
Cost of sales	(591)	(1,404)	(113)
Operating income	549	1,250	(1)
(Loss) income from equity investees	(35)	(93)	0
Loss on extinguishment of debt	(11)
Other non-operating income, net	47	8	(39)
Earnings (loss) before interest expense and income taxes	550	1,165	(40)
Interest expense	(35)	(26)	(31)
Income tax expense	(98)	(312)	46
Noncontrolling interests’ net (income) loss	0
Net income attributable to UGI Corporation	417	827	(25)
Depreciation and amortization	2	0	1
Total assets	196	189	233
Short-term borrowings	0	0	0
Capital expenditures (including the effects of accruals)	0	0	0
Investments in equity investees	1	0	0
Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishment of debt	0
Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Loss on extinguishment of debt	(11)
Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishment of debt	0
Corporate, Intersegment Eliminations & Other
Segment Reporting Information [Line Items]
Revenues	$ 3	$ 3	$ 3

Segment Information - Corporate

Segment Information - Corporate and Other segment information (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	$ 648	$ 1,398	$ 81
Loss on extinguishment of debt	(11)	0	0
Loss on disposals of Conemaugh and HVAC	0	0	(54)
Corporate & Other
Segment Reporting Information [Line Items]
Loss on extinguishment of debt	(11)
Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishment of debt	0
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	(185)	167	72
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]
Restructuring costs	(21)	(54)	(44)
Impairment of customer relationship intangible		0
Acquisition and integration expenses associated with the CMG Acquisition			0
Corporate & Other | AmeriGas Propane | Other non-operating income (expense), 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 | (Loss) income from equity investees
Segment Reporting Information [Line Items]
Impairments of certain equity method investments and assets	0	0
Corporate & Other | AmeriGas Propane | Loss on disposals of Conemaugh and HVAC
Segment Reporting Information [Line Items]
Loss on disposals of Conemaugh and HVAC			0
Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Loss on extinguishment of debt	(11)
Corporate & Other | UGI International | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	9	0	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	797	1,065	0
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
Corporate & Other | UGI International | Operating and administrative expenses
Segment Reporting Information [Line Items]
Restructuring costs	(9)	(33)	(18)
Impairment of customer relationship intangible		(20)
Acquisition and integration expenses associated with the CMG Acquisition			0
Corporate & Other | UGI International | Other non-operating income (expense), net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	50	8	(36)
Corporate & Other | UGI International | (Loss) income from equity investees
Segment Reporting Information [Line Items]
Impairments of certain equity method investments and assets	(5)	0
Corporate & Other | UGI International | Loss on disposals of Conemaugh and HVAC
Segment Reporting Information [Line Items]
Loss on disposals of Conemaugh and HVAC			0
Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishment of debt	0
Corporate & Other | Midstream & Marketing | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(4)	(15)	3
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	(21)	173	42
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]
Restructuring costs	(1)	0	0
Impairment of customer relationship intangible		0
Acquisition and integration expenses associated with the CMG Acquisition			(2)
Corporate & Other | Midstream & Marketing | Other non-operating income (expense), 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 | (Loss) income from equity investees
Segment Reporting Information [Line Items]
Impairments of certain equity method investments and assets	$ (35)	$ (93)
Corporate & Other | Midstream & Marketing | Loss on disposals of Conemaugh and HVAC
Segment Reporting Information [Line Items]
Loss on disposals of Conemaugh and HVAC			$ (54)

Business Transformation Initi_2

Business Transformation Initiatives (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Restructuring Cost and Reserve [Line Items]
Costs principally comprising consulting, advisory and employee-related costs		$ 87	$ 62
Restructuring, Incurred Cost, Statement of Income or Comprehensive Income [Extensible Enumeration]	Selling, General and Administrative Expense	Selling, General and Administrative Expense
Corporate Services Member
Restructuring Cost and Reserve [Line Items]
Costs principally comprising consulting, advisory and employee-related costs	$ 9	$ 14
Restructuring, Incurred Cost, Statement of Income or Comprehensive Income [Extensible Enumeration]	Selling, General and Administrative Expense	Selling, General and Administrative Expense

Subsequent Events (Details)

Subsequent Events (Details) - Sale - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2023	Oct. 31, 2022	Sep. 30, 2022
UGI International France Energy Marketing
Subsequent Event [Line Items]
Carrying value of net assets			$ 470
Subsequent Event | UGI International United Kingdom Energy Marketing
Subsequent Event [Line Items]
Net cash payment		$ 19
Loss on disposal	$ 220

SCHEDULE I _ CONDENSED FINANC_3

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) - BALANCE SHEETS (Details) - USD ($) $ in Millions	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Current assets
Cash and cash equivalents	$ 405	$ 855	$ 336
Prepaid expenses and other current assets	120	101
Total current assets	3,802	3,270
Other assets	755	831
Total assets	17,575	16,723	$ 13,985
Current liabilities
Current maturities of long-term debt	149	110
Total current liabilities	2,444	2,297
Long-term debt	6,483	6,339
Other noncurrent liabilities	1,219	1,381
Total liabilities	11,501	11,192
Commitments and contingencies (Note 1)
Equity:
Preferred Stock, without par value (authorized 5,000,000 shares; issued 220,000 and 220,000 Series A shares, respectively)	162	213
Common Stock, without par value (authorized – 450,000,000 shares; issued – 210,560,494 and 209,843,296 shares, respectively)	1,483	1,394
Retained earnings	4,841	4,081
Accumulated other comprehensive loss	(380)	(140)
Treasury stock, at cost	(40)	(26)
Total UGI Corporation stockholders’ equity	6,066	5,522
Total liabilities and equity	$ 17,575	$ 16,723
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
Common Stock, shares authorized (in shares)	450,000,000	450,000,000
Common Stock, shares issued (in shares)	210,560,494	209,843,296
Parent Company
Current assets
Cash and cash equivalents	$ 20	$ 14
Accounts receivable – related parties	24	18
Prepaid expenses and other current assets	20	11
Total current assets	64	43
Property, plant and equipment, net	1	2
Investments in subsidiaries	7,035	6,479
Other assets	97	107
Total assets	7,197	6,631
Current liabilities
Current maturities of long-term debt	125	70
Accounts and notes payable	20	24
Accrued liabilities	51	62
Total current liabilities	196	156
Long-term debt	889	875
Other noncurrent liabilities	46	78
Total liabilities	1,131	1,109
Commitments and contingencies (Note 1)
Equity:
Preferred Stock, without par value (authorized 5,000,000 shares; issued 220,000 and 220,000 Series A shares, respectively)	162	213
Common Stock, without par value (authorized – 450,000,000 shares; issued – 210,560,494 and 209,843,296 shares, respectively)	1,483	1,394
Retained earnings	4,841	4,081
Accumulated other comprehensive loss	(380)	(140)
Treasury stock, at cost	(40)	(26)
Total UGI Corporation stockholders’ equity	6,066	5,522
Total liabilities and equity	$ 7,197	$ 6,631
Condensed Financial Information of Registrant [Abstract]
Common Stock, shares authorized (in shares)	450,000,000	450,000,000
Common Stock, shares issued (in shares)	210,560,494	209,843,296

SCHEDULE I _ CONDENSED FINANC_4

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) - Narrative (Details) $ in Millions	12 Months Ended
	Sep. 30, 2022 USD ($)
Guarantee Obligations [Line Items]
Debt repayment in year 2022	$ 149
Debt repayment in year 2023	1,359
Debt repayment in year 2024	1,228
Debt repayment in year 2025	1,612
Parent Company
Guarantee Obligations [Line Items]
Surety bonds indemnified	107
Maximum amount authorized to guarantee obligations to suppliers and customers (up to)	475
Current carrying value	$ 371

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, 2022	Sep. 30, 2021	Sep. 30, 2020
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 10,106	$ 7,447	$ 6,559
Costs and expenses:
Operating and administrative expenses	2,028	2,014	1,911
Other operating income, net	(79)	(33)	(21)
Total costs and expenses	8,440	5,097	5,577
Operating income	1,666	2,350	982
Pension and other postretirement plans non-service expense	5	1	0
Income tax expense	313	522	135
Equity in income of unconsolidated subsidiaries	(14)	(63)	27
Net income attributable to UGI Corporation	1,073	1,467	532
Comprehensive income attributable to UGI Corporation	$ 833	$ 1,474	$ 602
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ 5.11	$ 7.02	$ 2.55
Diluted (in dollars per share)	$ 4.97	$ 6.92	$ 2.54
Weighted - average common shares outstanding (thousands):
Basic (in shares)	209,940	209,063	208,928
Diluted (in shares)	215,821	212,126	209,869
Parent Company
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 0	$ 0	$ 0
Costs and expenses:
Operating and administrative expenses	74	94	56
Other operating income, net	(63)	(65)	(54)
Total costs and expenses	11	29	2
Operating income	(11)	(29)	(2)
Pension and other postretirement plans non-service expense	(3)	0	0
Interest expense	(35)	(27)	(32)
Loss before income taxes	(49)	(56)	(34)
Income tax expense	0	9	17
Loss before equity in income of unconsolidated subsidiaries	(49)	(65)	(51)
Equity in income of unconsolidated subsidiaries	1,122	1,532	583
Net income attributable to UGI Corporation	1,073	1,467	532
Other comprehensive income (loss)	34	7	(12)
Equity in other comprehensive (loss) income of unconsolidated subsidiaries	(274)	0	82
Comprehensive income attributable to UGI Corporation	$ 833	$ 1,474	$ 602
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ 5.11	$ 7.02	$ 2.55
Diluted (in dollars per share)	$ 4.97	$ 6.92	$ 2.54
Weighted - average common shares outstanding (thousands):
Basic (in shares)	209,940	209,063	208,928
Diluted (in shares)	215,821	212,126	209,869

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, 2022	Sep. 30, 2021	Sep. 30, 2020
Condensed Financial Statements, Captions [Line Items]
NET CASH PROVIDED BY OPERATING ACTIVITIES	$ 716	$ 1,481	$ 1,102
CASH FLOWS FROM INVESTING ACTIVITIES
Net cash used by investing activities	(1,012)	(1,113)	(649)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(296)	(282)	(273)
Issuances of debt, net of issuance costs	1,257	656	209
Issuances of UGI Common Stock	19	19	2
Repurchases of UGI Common Stock	(38)	0	(38)
Net cash (used) provided by financing activities	(51)	166	(635)
Cash, cash equivalents and restricted cash (decrease) increase	(408)	520	(154)
Cash and cash equivalents:
Cash, cash equivalents and restricted cash at end of year	469	877	357
Cash, cash equivalents and restricted cash at beginning of year	877	357	511
Cash and cash equivalents increase (decrease)	(408)	520	(154)
Parent Company
Condensed Financial Statements, Captions [Line Items]
NET CASH PROVIDED BY OPERATING ACTIVITIES	485	300	322
CASH FLOWS FROM INVESTING ACTIVITIES
Return of capital distributions	175	0	0
Net investments in unconsolidated subsidiaries	(390)	(401)	0
Net cash used by investing activities	(215)	(401)	0
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(296)	(282)	(273)
Issuances of debt, net of issuance costs	597	483	60
Repayments of long-term debt	(530)	(385)	(60)
Issuance of preferred stock, net of issuance costs	0	213	0
Issuances of UGI Common Stock	19	19	2
Repurchases of UGI Common Stock	(38)	0	(38)
Payments on Purchase Contracts	(16)	0	0
Net cash (used) provided by financing activities	(264)	48	(309)
Cash, cash equivalents and restricted cash (decrease) increase	6	(53)	13
Cash and cash equivalents:
Cash, cash equivalents and restricted cash at end of year	20	14	67
Cash, cash equivalents and restricted cash at beginning of year	14	67	54
Cash and cash equivalents increase (decrease)	6	(53)	13
Dividends from unconsolidated subsidiaries	$ 506	$ 354	$ 352

SCHEDULE II _ VALUATION AND Q_2

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2020
Allowance for doubtful accounts
Valuation and Qualifying Account
Balance at beginning of year	$ 53	$ 42	$ 32
Charged (credited) to costs and expenses	61	36	32
Other	(50)	(25)	(22)
Balance at end of year	64	53	42
Deferred tax assets valuation allowance
Valuation and Qualifying Account
Balance at beginning of year	138	105	91
Charged (credited) to costs and expenses	(14)	23	0
Other	17	10	14
Balance at end of year	$ 141	$ 138	$ 105