UGI (UGI) 10-K 19 Nov 21 2021 FY Annual report Financial data

Cover Page

Cover Page - USD ($)	12 Months Ended
	Sep. 30, 2021	Nov. 12, 2021	Mar. 31, 2021
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Sep. 30, 2021
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			$ 8,512,319,963
Entity Common Stock, Shares Outstanding		209,221,695
Documents Incorporated by Reference	Portions of the Proxy Statement for the Annual Meeting of Shareholders to be held on January 28, 2022 are incorporated by reference into Part III of this Form 10-K.
Entity Central Index Key	0000884614
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Common Stock
Document Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	UGI
Security Exchange Name	NYSE
Capital Units
Document Information [Line Items]
Title of 12(b) Security	Corporate Units
Trading Symbol	UGIC
Security Exchange Name	NYSE

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2021	Sep. 30, 2020
Current assets
Cash and cash equivalents	$ 855	$ 336
Restricted cash	22	21
Accounts receivable (less allowances for doubtful accounts of $53 and $42, respectively)	880	652
Accrued utility revenues	15	14
Income taxes receivable	128	80
Inventories	469	241
Derivative instruments	665	44
Prepaid expenses	135	96
Other current assets	101	59
Total current assets	3,270	1,543
Property, plant and equipment
Non-utility	6,486	6,393
Utility	5,022	4,265
Total property, plant and equipment	11,508	10,658
Accumulated depreciation	(3,950)	(3,698)
Net property, plant, and equipment	7,558	6,960
Goodwill	3,770	3,518
Intangible assets, net	583	677
Utility regulatory assets	373	395
Derivative instruments	338	38
Other assets	831	854
Total assets	16,723	13,985
Current liabilities
Current maturities of long-term debt	110	53
Short-term borrowings	367	347
Accounts payable	837	475
Employee compensation and benefits accrued	181	162
Deposits and advances	208	204
Derivative instruments	60	64
Other current liabilities	534	450
Total current liabilities	2,297	1,755
Noncurrent liabilities
Long-term debt	6,339	5,981
Deferred income taxes	1,137	640
Derivative instruments	38	59
Other noncurrent liabilities	1,381	1,413
Total liabilities	11,192	9,848
Commitments and contingencies (Note 17)
UGI Corporation stockholders’ equity:
Preferred Stock, without par value (authorized 5,000,000 shares; issued 220,000 and 0 Series A shares, respectively)	213	0
UGI Common Stock, without par value (authorized – 450,000,000 shares; issued – 209,843,296 and 209,514,044 shares, respectively)	1,394	1,416
Retained earnings	4,081	2,908
Accumulated other comprehensive loss	(140)	(147)
Treasury stock, at cost	(26)	(49)
Total UGI Corporation stockholders’ equity	5,522	4,128
Noncontrolling interests	9	9
Total equity	5,531	4,137
Total liabilities and equity	$ 16,723	$ 13,985

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2021	Sep. 30, 2020
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 53	$ 42
Preferred Stock, shares authorized (in shares)	5,000,000	5,000,000
Preferred Stock, shares issued (in shares)	220,000	0
Common Stock, shares authorized (in shares)	450,000,000	450,000,000
Common Stock, shares issued (in shares)	209,843,296	209,514,044

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Income Statement [Abstract]
Revenues	$ 7,447	$ 6,559	$ 7,320
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)	2,614	3,149	4,323
Operating and administrative expenses	2,014	1,911	1,963
Loss on disposals of Conemaugh and HVAC	0	54	0
Depreciation and amortization	502	484	448
Other operating income, net	(33)	(21)	(31)
Total costs and expenses	5,097	5,577	6,703
Operating income	2,350	982	617
(Loss) income from equity investees	(63)	27	9
Loss on extinguishments of debt	0	0	(6)
Other non-operating income (expense), net	12	(20)	39
Interest expense	(310)	(322)	(258)
Income before income taxes	1,989	667	401
Income tax expense	(522)	(135)	(93)
Net income including noncontrolling interests	1,467	532	308
Deduct net income attributable to noncontrolling interests, principally in AmeriGas Partners prior to the AmeriGas Merger	0	0	(52)
Net income attributable to UGI Corporation	$ 1,467	$ 532	$ 256
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ 7.02	$ 2.55	$ 1.44
Diluted (in dollars per share)	$ 6.92	$ 2.54	$ 1.41
Weighted-average common shares outstanding:
Basic (in shares)	209,063	208,928	178,417
Diluted (in shares)	212,126	209,869	181,111

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Statement of Comprehensive Income [Abstract]
Net income including noncontrolling interests	$ 1,467	$ 532	$ 308
Net gains (losses) on derivative instruments (net of tax of $(1), $15, and $3, respectively)	3	(38)	(7)
Reclassifications of net losses on derivative instruments (net of tax of $(7), $(4), and $(2), respectively)	18	9	2
Foreign currency translation adjustments (net of tax of $(4), $12, and $(13), respectively)	(11)	15	(24)
Foreign currency (losses) gains on long-term intra-company transactions	(12)	84	(59)
Benefit plans, principally actuarial gains (losses) (net of tax of $(3), $1, and $5, respectively)	7	(3)	(13)
Reclassifications of benefit plans actuarial losses and net prior service benefit (net of tax of $(1), $(1), and $(1), respectively)	2	3	1
Other comprehensive income (loss)	7	70	(100)
Comprehensive income including noncontrolling interests	1,474	602	208
Deduct comprehensive income attributable to noncontrolling interests, principally in AmeriGas Partners prior to the AmeriGas Merger	0	0	(52)
Comprehensive income attributable to UGI Corporation	$ 1,474	$ 602	$ 156

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Statement of Comprehensive Income [Abstract]
Net (losses) gains on derivative instruments, tax	$ (1)	$ 15	$ 3
Reclassifications of net losses (gains) on derivative instruments, tax	7	4	2
Foreign currency translation adjustments, tax	(4)	12	(13)
Benefit plans, principally actuarial (losses) gains, tax	(3)	1	5
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, 2021	Sep. 30, 2020	Sep. 30, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income including noncontrolling interests	$ 1,467	$ 532	$ 308
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization	502	484	448
Deferred income tax expense (benefit), net	478	146	(43)
Provision for uncollectible accounts	36	32	29
Changes in unrealized gains and losses on derivative instruments	(1,398)	(81)	259
Loss on disposals of Conemaugh and HVAC	0	54	0
Equity-based compensation expense	21	15	18
Loss (income) from equity investees	63	(27)	(9)
Other, net	31	21	15
Net change in:
Accounts receivable and accrued utility revenues	(233)	(18)	83
Income taxes receivable	(48)	(80)	0
Inventories	(231)	(5)	84
Utility deferred fuel costs, net of changes in unsettled derivatives	(22)	17	(30)
Accounts payable	366	3	(97)
Derivative instruments collateral received (paid)	472	22	(41)
Other current assets	(10)	38	45
Other current liabilities	(13)	(51)	9
Net cash provided by operating activities	1,481	1,102	1,078
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(690)	(655)	(705)
Acquisitions of businesses and assets, net of cash and restricted cash acquired	(397)	(16)	(1,362)
Investments in equity method investees	65	0	0
Other, net	39	22	12
Net cash used by investing activities	(1,113)	(649)	(2,055)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(282)	(273)	(200)
Distributions on AmeriGas Partners publicly held Common Units	0	0	(263)
Issuances of debt, net of issuance costs	656	209	2,412
Repayments of debt and finance leases	(405)	(86)	(738)
Receivables Facility net (repayments) borrowings	(19)	(27)	44
(Decrease) increase in short-term borrowings	(16)	(422)	327
Issuances of preferred stock, net of issuance costs	213	0	0
Issuances of UGI Common Stock	19	2	17
Repurchases of UGI Common Stock	0	(38)	(17)
Cash paid for AmeriGas Merger	0	0	(529)
Other	0	0	(11)
Net cash provided (used) by financing activities	166	(635)	1,042
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(14)	28	(16)
Cash, cash equivalents and restricted cash increase (decrease)	520	(154)	49
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of year	877	357	511
Cash, cash equivalents and restricted cash at beginning of year	357	511	462
Cash, cash equivalents and restricted cash increase (decrease)	520	(154)	49
Cash paid for:
Interest	297	311	248
Income taxes	$ 96	$ 75	$ 74

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, 2018			$ 0	$ 1,201	$ 2,611	$ (110)	$ (20)	$ 419
Balance, beginning of year (ASC 606) at Sep. 30, 2018					(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock issued in connection with employee and director plans, net of tax withheld				11
Equity-based compensation expense				15
AmeriGas Merger-related adjustments				170				(199)
Net income including noncontrolling interests	$ 308				256			52
Cash dividends on common stock ($1.35, $1.31, and $1.145 per share, respectively)					(200)
Reclassification of stranded income tax effects related to TCJA	(7)				7	(7)
Losses on treasury stock transactions in connection with employee and director plans					(14)
Net gains (losses) on derivative instruments						(7)
Reclassification of net losses on derivative instruments	2					2
Benefit plans, principally actuarial gains (losses)	(13)					(13)
Reclassification of benefit plans actuarial losses and net prior service benefits	1					1
Foreign currency (losses) gains on long-term intra-company transactions	(59)					(59)
Foreign currency translation adjustments	(24)					(24)
Common Stock issued in connection with employee and director plans, net of tax withheld							24
Repurchases of common stock							(17)
Reacquired common stock – employee and director plans							(3)
Dividends and distributions								(263)
Other								1
Balance, end of year at Sep. 30, 2019	3,827	$ 3,817	0	1,397	2,653	(217)	(16)	10
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net gains (losses) on derivative instruments (net of tax of $(1), $15, and $3, respectively)	(7)
Common Stock issued in connection with employee and director plans, net of tax withheld				2
Equity-based compensation expense				17
Net income including noncontrolling interests	532				532
Cash dividends on common stock ($1.35, $1.31, and $1.145 per share, respectively)					(273)
Losses on treasury stock transactions in connection with employee and director plans					(4)
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)
Other								(1)
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]
Net gains (losses) on derivative instruments (net of tax of $(1), $15, and $3, respectively)	(38)					(38)
Issuance of preferred stock			213	(45)
Common Stock issued in connection with employee and director plans, net of tax withheld				9
Equity-based compensation expense				16
Net income including noncontrolling interests	1,467				1,467
Cash dividends on common stock ($1.35, $1.31, and $1.145 per share, respectively)					(282)
Losses on treasury stock transactions in connection with employee and director plans					(12)
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)
Other				(2)
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]
Net gains (losses) on derivative instruments (net of tax of $(1), $15, and $3, respectively)	$ 3					$ 3

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Statement of Stockholders' Equity [Abstract]
Accounting Standards Update [Extensible List]				ASC 606
Cash dividends on common stock (in dollars per share)	$ 1.35	$ 1.31	$ 1.145

Nature of Operations

Nature of Operations	12 Months Ended
	Sep. 30, 2021
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 United States, we own and operate (1) a retail propane marketing and distribution business; (2) natural gas and electric distribution utilities; and (3) an 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. On August 21, 2019, we completed the AmeriGas Merger pursuant to which we issued 34.6 million shares of UGI Common Stock and paid $529 in cash to acquire all of the outstanding Common Units in AmeriGas Partners not already held by UGI or its subsidiaries, with the Partnership surviving as a wholly owned subsidiary of UGI. Prior to the AmeriGas Merger, UGI controlled the Partnership through its ownership of the General Partner, which held a 1% general partner interest (which included IDRs) and approximately 25.5% of the outstanding Common Units, and held an effective 27% ownership interest in AmeriGas OLP. The IDRs held by the General Partner prior to the AmeriGas Merger entitled it to receive distributions from AmeriGas Partners in excess of its general partner interest under certain circumstances (see Note 15). For additional information on the AmeriGas Merger, see Note 5. 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. Energy Services conducts, directly and through subsidiaries and affiliates, energy marketing, including RNG, midstream transmission, LNG storage, natural gas gathering and processing, natural gas and RNG production, electricity generation and energy services businesses primarily in the eastern region of the U.S., eastern Ohio, the panhandle of West Virginia and California. UGID owns electricity generation facilities principally located in Pennsylvania. Energy Services and its subsidiaries’ storage, LNG and portions of its midstream transmission operations are subject to regulation by the FERC. Upon acquisition of Mountaineer on September 1, 2021 (described below), our UGI Utilities segment includes UGI Utilities, Inc. and Mountaintop Energy Holdings, LLC. UGI Utilities, Inc. directly owns and operates Gas Utility, a natural gas distribution utility business in eastern and central Pennsylvania and in a portion of one Maryland county. Gas Utility is subject to regulation by the PAPUC, the FERC, and, with respect to a small service territory in one Maryland county, the MDPSC. UGI Utilities, Inc. also owns and operates Electric Utility, an electric distribution utility located in northeastern Pennsylvania. Electric Utility is subject to regulation by the PAPUC and the FERC. On September 1, 2021, UGI acquired Mountaineer, the largest natural gas distribution company in West Virginia for a purchase price of $540, which includes the assumption of approximately $140 principal amounts of long-term debt. Mountaineer serves nearly 214,000 customers across 50 of the state’s 55 counties. Mountaineer is subject to regulation by the WVPSC. For additional information on the Mountaineer Acquisition, see Note 5.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Sep. 30, 2021
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. 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. Prior to the AmeriGas Merger, we also reported the public’s interest in the Partnership as a noncontrolling interest. 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 valued at their cost less impairment (if any). 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 UGI 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 U.S. dollars using the exchange rate at the balance sheet date. Income statements and equity investee results are translated into U.S. dollars using an average exchange rate for each reporting period. Where the local currency is the functional currency, translation adjustments are recorded in other comprehensive income. Transactions denominated in currencies other than the functional currency are recorded based on exchange rates at the time such transactions arise with the impact of subsequent changes in such rates reflected in the income statement. The functional currency of a significant portion of our international operations is the euro. Revenue Recognition In accordance with ASC 606, the Company recognizes revenue when control of promised goods or services is transferred to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Certain revenues such as revenue from leases, financial instruments and other revenues are not within the scope of ASC 606 because they are not from contracts with customers. Such revenues are accounted for in accordance with other GAAP. Revenue-related taxes collected on behalf of customers and remitted to taxing authorities, principally sales and use taxes, are not included in revenues. Gross receipts taxes at Midstream & Marketing, Mountaineer and Electric Utility are presented on a gross basis. The Company has elected to use the practical expedient to expense the costs to obtain contracts when incurred for contracts that have a term less than one year. The costs incurred to obtain contracts that have durations of longer than one year are not material. See Note 4 for additional disclosures regarding the Company’s revenue from contracts with customers. Accounts Receivable Accounts receivable are reported on the Consolidated Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. Provisions for uncollectible accounts are established based upon our collection experience, the assessment of the collectability of specific amounts and the Company’s best estimate of current expected credit losses. Accounts receivable are written off in the period in which the receivable is deemed uncollectible. LPG Delivery Expenses Expenses associated with the delivery of LPG to customers of the Partnership and our UGI International operations (including vehicle expenses, expenses of delivery personnel, vehicle repair and maintenance and general liability expenses) are classified as “Operating and administrative expenses” on the Consolidated Statements of Income. Depreciation expense associated with the Partnership and UGI International delivery vehicles is classified in “Depreciation and amortization” on the Consolidated Statements of Income. Income Taxes AmeriGas Partners and AmeriGas OLP are not directly subject to federal income taxes. Instead, their taxable income or loss is allocated to the individual partners which, prior to the AmeriGas Merger, included public holders of AmeriGas Partners Common Units. 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. UGI 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. UGI 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) 2021 2020 2019 Weighted-average common shares outstanding for basic computation (a) 209,063 208,928 178,417 Incremental shares issuable for stock options, common stock awards and Equity Units (b) (c) 3,063 941 2,694 Weighted-average common shares outstanding for diluted computation 212,126 209,869 181,111 (a) Fiscal 2019 includes the partial-year impact from the August 2019 issuance of 34,613 shares of UGI Common Stock in connection with the AmeriGas Merger (see Note 5). (b) Fiscal 2021 includes the partial-year 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). (c) For Fiscal 2021, Fiscal 2020 and Fiscal 2019 there were 5,267 shares, 7,056 shares and 1,162 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. 2021 2020 2019 Cash and cash equivalents $ 855 $ 336 $ 447 Restricted cash 22 21 64 Cash, cash equivalents and restricted cash $ 877 $ 357 $ 511 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 business. 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, Inc. 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 UGI 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 (other than customer relationships acquired in the CMG Acquisition), certain tradenames and noncompete agreements, generally do not exceed 15 years. The estimated useful lives of customer relationships acquired in the CMG Acquisition is 35 years (see Note 5). 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. 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. There were no accumulated goodwill impairment losses at September 30, 2021 and 2020, 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. During the fourth quarter of Fiscal 2021, the Company identified impairment indicators associated with certain natural gas gathering system asset groups within the Midstream & Marketing reportable segment having a carrying value of approximately $100 at September 30, 2021. The impairment indicators resulted from the bankruptcy of a significant customer, as well as payment delinquencies resulting from the deterioration in the financial condition of an additional customer. These events resulted in a significant decline in the current forecasted operating cash flows associated with the related asset groups. The Company performed a recoverability test as a result of these triggering events utilizing an estimate of undiscounted cash flows related to the asset groups. While this analysis currently indicates that such carrying amounts are expected to be recovered, events and/or changes in circumstances may occur in the near term resulting in a change in management’s estimates of undiscounted cash flows. Any such events or changes could ultimately impact recoverability and result in an impairment loss equal to the difference between the calculated fair value of such asset groups and their estimated carrying value. No material provisions for impairments of long-lived assets were recorded during Fiscal 2019. See Note 5 for further information on the losses associated with 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 $296 and $300 at September 30, 2021 and 2020, respectively. Deposits are refundable to customers when the tanks or cylinders are returned in accordance with contract terms. Environmental Matters We are subject to environmental laws and regulations intended to mitigate or remove the effects of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current or former operating sites. Environmental reserves are accrued when assessments indicate that it is probable that a liability has been incurred and an amount can be reasonably estimated. Amounts recorded as environmental liabilities on the Consolidated Balance Sheets represent our best estimate of costs expected to be incurred or, if no best estimate can be made, the minimum liability associated with a range of expected environmental investigation and remediation costs. These estimates are based upon a number of factors including whether the Company will be responsible for such remediation, the scope and cost of the remediation work to be performed, the portion of costs that will be shared with other potentially responsible parties, the timing of the remediation and possible impact of changes in technology, and the regulations and requirements of local governmental authorities. Our estimated liability for environmental contamination is reduced to reflect anticipated participation of other responsible parties but is not reduced for possible recovery from insurance carriers. Under GAAP, if the amount and timing of cash payments associated with environmental investigation and cleanup are reliably determinable, such liabilities are discounted to reflect the time value of money. We intend to pursue recovery of incurred costs through all appropriate means, including regulatory relief. Gas Utility receives ratemaking recognition of environmental investigation and remediation costs associated with in-state environmental sites. This ratemaking recognition balances the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. For further information, see Note 17. 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-

Accounting Changes

Accounting Changes	12 Months Ended
	Sep. 30, 2021
Accounting Standards Update and Change in Accounting Principle [Abstract]
Accounting Changes	Note 3 — Accounting Changes New Accounting Standards Adopted in Fiscal 2021 Credit Losses. Effective October 1, 2020, the Company adopted ASU 2016-13, “Measurement of Credit Losses on Financial Instruments,” including subsequent amendments, using a modified retrospective transition approach. This ASU, as subsequently amended, requires entities to estimate lifetime expected credit losses for financial instruments not measured at fair value through net income, including trade and other receivables, net investments in leases, financial receivables, debt securities, and other financial instruments, which may result in earlier recognition of credit losses. Further, the new current expected credit loss model may affect how entities estimate their allowance for losses related to receivables that are current with respect to their payment terms. The adoption of the new guidance did not have a material impact on our consolidated financial statements. New Accounting Standard Adopted Effective October 1, 2021 Income Taxes. In December 2019, the FASB issued ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” 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. Effective October 1, 2021, the Company adopted this ASU, as updated, using a prospective approach. The adoption of the new guidance did not have a material impact on our consolidated financial statements. Accounting Standard Not Yet Adopted Debt and Derivatives and Hedging. In August 2020, the FASB issued ASU 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40).” The amendments in this ASU affect entities that issue convertible instruments and/or contracts indexed to and potentially settled in an entity’s own equity. This ASU reduces the number of accounting models for convertible debt instruments and convertible preferred stock, expands disclosure requirements for convertible instruments, and simplifies the related earnings per share guidance. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2022 (Fiscal 2023). Early adoption is permitted. The amendments in this ASU may be adopted using the modified or full retrospective transition methods. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the transition method and the period in which the new guidance will be adopted.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
	Sep. 30, 2021
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 UGI 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 UGI 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 UGI 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. UGI 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. UGI 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. UGI 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 propane 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 propane 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 propane 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 propane 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 table presents our disaggregated revenues by reportable segment during Fiscal 2021, Fiscal 2020 and Fiscal 2019: 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI 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 UGI 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 2019 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 553 $ — $ — $ — $ — $ 553 $ — Commercial & Industrial 226 — — — — 226 — Large delivery service 138 — — — — 138 — Off-system sales and capacity releases 46 (65) — — — 111 — Other (c) 15 (3) — — — 18 — Total Utility 978 (68) — — — 1,046 — Non-Utility: LPG: Retail 4,008 — 2,341 1,667 — — — Wholesale 233 — 64 169 — — — Energy Marketing 1,521 (134) — 448 1,207 — — Midstream: Pipeline 95 — — — 95 — — Peaking 17 (97) — — 114 — — Other 2 — — — 2 — — Electricity Generation 43 — — — 43 — — Other 314 (3) 213 55 49 — — Total Non-Utility 6,233 (234) 2,618 2,339 1,510 — — Total revenues from contracts with customers 7,211 (302) 2,618 2,339 1,510 1,046 — Other revenues (b) 109 (4) 64 33 6 3 7 Total revenues $ 7,320 $ (306) $ 2,682 $ 2,372 $ 1,516 $ 1,049 $ 7 (a) Includes intersegment revenues principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane. (b) Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, revenues from alternative revenue programs at UGI Utilities, Inc., and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP. (c) UGI Utilities includes an unallocated negative surcharge revenue reduction of $(6) during Fiscal 2019 as a result of a PAPUC Order issued May 17, 2018, related to the TCJA (see Note 9). 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, 2021 and 2020. Substantially all of our receivables are unconditional rights to consideration and are included in “Accounts receivable” and, in the case of UGI 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 $149 and $161 at September 30, 2021 and 2020, respectively, and are primarily included in “Deposits and Advances” on the Consolidated Balance Sheets. Revenue recognized during Fiscal 2021, Fiscal 2020 and Fiscal 2019 from the amount included in contract liabilities at September 30, 2020, September 30, 2019 and October 1, 2018 was $138, $122 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 UGI Utilities contain minimum future performance obligations through 2047 and 2053, respectively. At September 30, 2021, Midstream & Marketing and UGI Utilities expect to record approximately $2.0 billion and $0.2 billion of revenues, respectively, related to the minimum future performance obligations over the remaining terms of the related contracts.

AmeriGas Merger, Acquisitions a

AmeriGas Merger, Acquisitions and Dispositions	12 Months Ended
	Sep. 30, 2021
Business Combinations [Abstract]
AmeriGas Merger, Acquisitions and Dispositions	Note 5 — AmeriGas Merger, 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 and cash on hand including proceeds from the issuance of Equity Units . Accounts associated with Mountaineer are included within our UGI Utilities reportable segment. The Company has accounted for the Mountaineer Acquisition using the acquisition method. At September 30, 2021, the allocation of the purchase price is substantially complete but remains preliminary pending the finalization of the valuation of the net assets acquired, including the evaluation of certain acquired contracts, regulatory assets, and deferred income taxes, among others. The purchase price allocation will be finalized once these items have been resolved. Accordingly, the fair value estimates presented below relating to these items are subject to change within the measurement period not to exceed one year from the date of acquisition. The components of the preliminary 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 26 Other noncurrent liabilities 29 Total liabilities assumed $ 379 Goodwill 255 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 UGI 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 . AmeriGas Merger On August 21, 2019, the AmeriGas Merger was completed in accordance with the terms of the Merger Agreement entered into on April 1, 2019. Under the terms of the Merger Agreement, the Partnership was merged with and into Merger Sub, with the Partnership surviving as an indirect wholly owned subsidiary of UGI. Each outstanding Common Unit other than the Common Units owned by UGI was automatically converted at the effective time of the AmeriGas Merger into the right to receive, at the election of each holder of such Common Units, one of the following forms of merger consideration (subject to proration designed to ensure the number of shares of UGI Common Stock issued would equal approximately 34.6 million): (i) 0.6378 shares of UGI Common Stock (the “Share Multiplier”); (ii) $7.63 in cash, without interest, and 0.500 shares of UGI Common Stock; or (iii) $35.325 in cash, without interest. Pursuant to the terms of the Merger Agreement, effective on August 21, 2019, we issued 34,612,847 shares of UGI Common Stock and paid $529 in cash to the holders of Common Units other than UGI, for a total implied consideration of $2,228. In addition, the incentive distribution rights in the Partnership previously owned by the General Partner were canceled. After-tax transaction costs directly attributable to the transaction that were incurred by UGI totaling $8 were recorded as a reduction to UGI stockholders’ equity. Transaction costs incurred by the Partnership totaling $6 are reflected in “Operating and administrative expenses” on the 2019 Consolidated Statement of Income. The tax effects of the AmeriGas Merger resulting from the step-up in tax bases of the underlying assets resulted in the recording of a deferred tax asset in the amount of $512. Effective upon completion of the AmeriGas Merger, Common Units are no longer publicly traded. Also pursuant to the Merger Agreement, Partnership equity-based awards were canceled and replaced with cash-settled restricted stock units relating to UGI Common Stock using the Share Multiplier ratio. The AmeriGas Merger was accounted for in accordance with ASC 810, Consolidation - Overall - Changes in a Parent’s Ownership Interest in a Subsidiary. Because UGI controlled AmeriGas Partners before and after the merger, the changes in UGI’s ownership interest in the Partnership resulting from the merger were accounted for as an equity transaction. Accordingly, no gain or loss was recognized in UGI’s consolidated income statement and the carrying amounts of the Partnership’s assets and liabilities were not adjusted. The tax effects of the AmeriGas Merger were reported as adjustments to deferred income taxes and UGI stockholders’ equity. CMG Acquisition On August 1, 2019, UGI through its wholly owned indirect subsidiary, Energy Services, completed the CMG Acquisition in which Energy Services acquired all of the equity interests in CMG and CMG’s approximately 47% interest in Pennant, for total cash consideration of $1,284. The CMG Acquisition was consummated pursuant to the CMG Acquisition Agreements. CMG and Pennant provide natural gas gathering and processing services through five discrete systems located in western Pennsylvania, eastern Ohio and the panhandle of West Virginia. The CMG Acquisition was consistent with our growth strategies, including expanding our midstream natural gas gathering and processing assets within the Marcellus and Utica Shale production regions. The Company has accounted for the CMG Acquisition using the acquisition method. The components of the final CMG purchase price allocations are as follows: Assets acquired: Accounts receivable $ 10 Prepaid expenses and other current assets 1 Property, plant and equipment 614 Investment in Pennant 88 Intangible assets (a) 250 Total assets acquired $ 963 Liabilities assumed: Accounts payable 3 Total liabilities assumed $ 3 Goodwill 324 Net consideration transferred (including working capital adjustments) $ 1,284 (a) Represents customer relationships having an average amortization period of 35 years. We allocated the purchase price of the acquisition to identifiable intangible assets and property, plant and equipment based on estimated fair values as follows: • Customer relationships were valued using a multi-period, excess earnings method. Key assumptions used in this method include discount rates, growth rates and cash flow projections. These assumptions are most sensitive and susceptible to change as they require significant management judgment; and • Property, plant and equipment were valued based on estimated fair values primarily using depreciated replacement cost and market value methods. The excess of the purchase price for the CMG Acquisition over the fair values of the assets acquired and liabilities assumed has been reflected as goodwill, assigned to the Midstream & Marketing reportable segment, and results principally from anticipated future capital investment opportunities and value creation resulting from new natural gas processing assets in the Marcellus and Utica Shale production regions. The goodwill recognized from the CMG Acquisition is deductible for income tax purposes. The Company recognized $15 of direct transaction-related costs associated with the CMG Acquisition during Fiscal 2019, which costs are reflected in “Operating and administrative expenses” on the 2019 Consolidated Statement of Income. The CMG Acquisition did not have a material impact on the Company’s revenues or net income attributable to UGI for Fiscal 2019. In addition, the impact of the CMG Acquisition on a pro forma basis as if the CMG Acquisition had occurred on October 1, 2018 was not material to the Company’s revenues or net income for Fiscal 2019. 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. During Fiscal 2019, UGI International acquired several retail LPG distribution businesses, and Midstream & Marketing acquired a natural gas marketing business. Total cash paid and liabilities incurred in connection with these acquisitions were as follows: 2021 2020 2019 UGI International Midstream & Marketing UGI International Midstream & Marketing Total cash paid $ 18 $ 16 $ 49 $ 15 Liabilities incurred — 7 — — Total purchase price $ 18 $ 23 $ 49 $ 15 Acquisitions of Assets During Fiscal 2019, Midstream & Marketing acquired 21 miles of natural gas gathering lines and related dehydration and compression equipment located in northern Pennsylvania for cash consideration of $20. Disposals of Conemaugh and HVAC 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, 2021
Debt Disclosure [Abstract]
Debt	Note 6 — Debt Significant Financing Activities during Fiscal 2021 Mountaineer. As further described in Note 5, UGI acquired Mountaineer on September 1, 2021. Mountaineer has a credit facility agreement which provides for borrowings up to $100, with an option to increase the maximum borrowing capacity to $200. The credit facility agreement is scheduled to expire in November 2024, with the option to extend the maturity for two additional one-year periods. Borrowings under this credit facility agreement bear interest at (1) a prime rate plus a margin or (2) an adjusted LIBOR plus a margin. Such margin is dependent upon Mountaineer’s unsecured debt rating. Mountaineer also has several unsecured senior notes and principal amounts which are due in full at maturity. Interest is payable on a semiannual basis in June and December for each of these senior notes. See “Long-term Debt” below for further information on these senior notes. UGI Utilities, Inc.. On May 7, 2021, UGI Utilities, Inc. entered into a Note Purchase Agreement with a consortium of lenders. Pursuant to the Note Purchase Agreement, UGI Utilities, Inc. issued $100 aggregate principal amount of 1.59% Senior Notes due June 15, 2026 and $75 aggregate principal amount of 1.64% Senior Notes due September 15, 2026 in June and September 2021, respectively. These senior notes are unsecured and will rank equally with UGI Utilities Inc.’s existing outstanding senior debt. The net proceeds from these issuances were used to reduce short-term borrowings and for general corporate purposes. UGI Corporation. On May 4, 2021, UGI amended the existing UGI Corporation Senior Credit Facility. The 2021 UGI Corporation Senior Credit Facility (1) extends the maturity date of the previous three-year $300 term loan included in the existing UGI Corporation Senior Credit Facility, which is now due in May 2025; and (2) includes a new four-year term loan commitment, which, effective June 9, 2021, was reduced from $300 to $215, pursuant to the terms of the 2021 UGI Corporation Senior Credit Facility. Proceeds from new term loan borrowings under the 2021 UGI Corporation Senior Credit Facility were used to finance a portion of the Mountaineer Acquisition and for general corporate purposes. Borrowings on the new term loan under the 2021 UGI Corporation Senior Credit Facility bear interest subject to our election, at either (1) the associated prime rate plus a margin or (2) an adjusted LIBOR (or an alternate benchmark rate upon a transition away from LIBOR) plus a margin and are due in their entirety at the maturity date. The applicable margin on the new borrowings, which is dependent upon a ratio of consolidated net indebtedness to consolidated EBITDA, as defined, or UGI’s credit ratings, ranges from 0.125% to 1.50% if the prime rate option is elected and 1.125% to 2.50% if the LIBOR option is elected. 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, 2021 and 2020, 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, 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, Inc. (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 % September 30, 2020 AmeriGas OLP (a) December 2022 $ 600 $ 186 $ 62 $ 352 2.61 % UGI International, LLC (b) October 2023 € 300 € — € — € 300 N.A. Energy Services (c) March 2025 $ 260 $ — $ — $ 260 N.A. UGI Utilities, Inc. (d) June 2024 $ 350 $ 141 $ — $ 209 1.12 % UGI Corporation (f) August 2024 $ 300 $ 300 $ — $ — 2.41 % (a) The AmeriGas OLP Credit Agreement includes a $150 sublimit for letters of credit. (b) The UGI International Credit Facilities Agreement permits UGI International, LLC to borrow in euros or dollars. UGI International repaid all borrowings outstanding on this facility in September 2020. (c) The Energy Services Credit Agreement includes a $50 sublimit for letters of credit and is guaranteed by certain subsidiaries of Energy Services. This credit agreement is collateralized by substantially all of the assets of Energy Services, subject to certain exceptions and carveouts including, but not limited to, accounts receivables and certain real property. (d) UGI Utilities, Inc. 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, 2021 and 2020, management intended to maintain a substantial portion of amounts outstanding under the 2021 UGI Corporation Senior Credit Facility and its predecessor agreement beyond twelve months from the respective balance sheet dates. As such, borrowings outstanding are classified as “Long-term debt” on the Consolidated Balance Sheets. In October 2021 and 2020, the Company repaid $70 and $30, respectively, of such borrowings and classified these repayments as “Current maturities of long-term debt” on the Consolidated Balance Sheet. 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 currently scheduled to expire in October 2022. The Receivables Facility, as amended, provides Energy Services with the ability to borrow up to $150 of eligible receivables during the period November to April, and up to $75 of eligible receivables during the period May to October. 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: 2021 2020 2019 Trade receivables transferred to ESFC during the year $ 1,353 $ 1,046 $ 1,373 ESFC trade receivables sold to the bank during the year $ 308 $ 182 $ 179 ESFC trade receivables - end of year (a) $ 61 $ 50 $ 55 (a) At September 30, 2021 there were no ESFC trade receivables sold to the bank. At September 30, 2020, the amounts of ESFC trade receivables sold to the bank was $19, and is reflected as “Short-term borrowings” on the Consolidated Balance Sheets. Long-term Debt Long-term debt comprises the following at September 30: 2021 2020 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 5 Unamortized debt issuance costs (16) (20) Total AmeriGas Propane 2,560 2,560 UGI International: 3.25% Senior Notes due November 2025 405 410 UGI International, LLC variable-rate term loan due October 2023 (a) 347 352 Other 23 23 Unamortized debt issuance costs (5) (7) Total UGI International 770 778 Midstream & Marketing: Energy Services variable-rate term loan due through August 2026 (b) 684 691 Other 42 41 Unamortized discount and debt issuance costs (10) (12) Total Energy Services 716 720 UGI Utilities: Senior Notes: 4.12%, due September 2046 200 200 4.98%, due March 2044 175 175 3.12% due April 2050 150 150 4.55%, due February 2049 150 150 4.12%, due October 2046 100 100 6.21%, due September 2036 100 100 2.95%, due June 2026 100 100 1.59% due June 2026 100 — 1.64% due September 2026 75 — Medium-Term Notes: 6.13%, due October 2034 20 20 6.50%, due August 2033 20 20 Mountaineer senior notes (c) 164 — Variable-rate term loan due through October 2022 (d) 102 108 Other 1 3 Unamortized debt issuance costs (6) (5) Total UGI Utilities 1,451 1,121 UGI Corporation: UGI Corporation revolving credit facility maturing August 2024 (e) 185 300 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 — Unamortized debt issuance costs (5) (3) Total UGI Corporation 945 847 Other 7 8 Total long-term debt 6,449 6,034 Less: current maturities (110) (53) Total long-term debt due after one year $ 6,339 $ 5,981 (a) At September 30, 2021 and 2020, the effective interest rates on the term loan were 1.89% and 2.04%, respectively. 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, 2021 and 2020, the effective interest rates on the term loan were 5.23% and 5.30%, 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) As a result of the Mountaineer Acquisition, total long-term debt at September 30, 2021, includes $140 of Mountaineer senior secured notes (including unamortized premium of $24). The face interest rates on the Mountaineer senior notes range from 3.50% to 4.41%, with maturities ranging from 2027 to 2034. (d) The effective interest rate on this term loan was 4.00% at both September 30, 2021 and 2020. 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, 2021 and 2020, the effective interest rates on credit facility borrowings were 3.27% and 2.41%, 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, 2021 and 2020, the effective interest rate on this term loan 3.26% and 3.51%, 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, 2021 and 2020, the effective interest rates on this term loan were 3.56% and 3.50%, 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, 2021, the effective interest rate on this term loan 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: 2022 2023 2024 2025 2026 AmeriGas Propane $ 1 $ — $ 675 $ 700 $ 675 UGI International 21 2 347 — 405 Midstream & Marketing 10 7 7 7 656 UGI Utilities 7 96 — — 275 UGI Corporation (a) 70 38 327 515 — Other 1 6 — — — Total $ 110 $ 149 $ 1,356 $ 1,222 $ 2,011 (a) In October 2021, the Company repaid $70 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 2021 Consolidated Balance Sheet. 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, 2021. Restricted Net Assets At September 30, 2021, 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 $2,500.

Income Taxes

Income Taxes	12 Months Ended
	Sep. 30, 2021
Income Tax Disclosure [Abstract]
Income Taxes	Note 7 — Income Taxes Income before income taxes comprises the following: 2021 2020 2019 Domestic $ 647 $ 424 $ 330 Foreign 1,342 243 71 Total income before income taxes $ 1,989 $ 667 $ 401 The provisions for income taxes consist of the following: 2021 2020 2019 Current expense (benefit): Federal $ (48) $ (85) $ 52 State 7 4 14 Foreign 85 70 70 Total current (benefit) expense 44 (11) 136 Deferred expense (benefit): Federal 168 135 3 State 48 19 4 Foreign 262 (8) (50) Total deferred expense (benefit) 478 146 (43) Total income tax expense $ 522 $ 135 $ 93 Federal income taxes for Fiscal 2019 are net of foreign tax credits of $10. There were no foreign tax credits 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: 2021 2020 2019 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % Difference in tax rate due to: Effect of U.S. tax legislation (0.8) (4.7) 0.2 Effect of tax rate changes - International (1.3) 0.3 (0.5) Noncontrolling interests not subject to tax — — (2.7) State income taxes, net of federal benefit 1.9 2.8 3.6 Valuation allowance adjustments 1.0 — — Effects of foreign operations 4.6 1.3 1.8 Excess tax benefits on share-based payments (0.1) (0.2) (1.0) Other, net (0.1) (0.3) 0.7 Effective tax rate 26.2 % 20.2 % 23.1 % 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 which will result in incremental tax basis that will be deductible in future periods. 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 remains outstanding from the IRS. The Fiscal 2021 carryback to Fiscal 2016 will generate an expected $38 refund. Both are included in “Income taxes receivable” on the Consolidated Balance Sheet at September 30, 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 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 2021, Fiscal 2020 and Fiscal 2019 includes $8, $0 and $2, 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 2021, Fiscal 2020 and Fiscal 2019, the beneficial effects of state tax flow through of accelerated depreciation reduced income tax expense by $9, $11, and $7, respectively. Deferred tax liabilities (assets) comprise the following at September 30: 2021 2020 Excess book basis over tax basis of property, plant and equipment $ 937 $ 830 Utility regulatory assets 105 112 Intangible assets and goodwill 77 107 Derivative instrument assets 322 — Other 36 32 Gross deferred tax liabilities 1,477 1,081 Investment in AmeriGas Partners (102) (216) Pension plan liabilities (29) (48) Employee-related benefits (45) (46) Operating loss carryforwards (53) (34) Foreign tax credit carryforwards (79) (81) Utility regulatory liabilities (102) (94) Derivative instrument liabilities — (26) Utility environmental liabilities (16) (16) Other (107) (54) Gross deferred tax assets (533) (615) Deferred tax assets valuation allowance 138 105 Net deferred tax liabilities $ 1,082 $ 571 At September 30, 2021, we carried foreign net operating loss carryforwards of $10 and $19 principally relating to Flaga and certain subsidiaries of UGI France, with no expiration dates and $5 in the Netherlands expiring in 2027. We have state net operating loss carryforwards primarily relating to certain subsidiaries that approximate $606 and expire through 2041. We also have federal operating loss carryforwards of $24 for Mountaintop Energy Holding, LLC and $7 for certain operations of AmeriGas Propane. At September 30, 2021, deferred tax assets relating to operating loss carryforwards amounted to $52 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 $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 FTC’s that will be realizable in the future. The valuation allowance for all deferred tax assets decreased by $14 in Fiscal 2020 largely related to a $16 increase in a notional interest deduction carryover. 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 2017 tax year, our French tax returns are settled through the 2017 tax year, our Austrian tax returns are settled through 2016 and our other European tax returns are effectively settled for various years from 2013 to 2018. 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 $11 at September 30, 2021, 2020 and 2019, 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, 2021
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, Inc., 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 $31 and $24 as of September 30, 2021 and 2020, respectively. The fair value of the plan assets of our other postretirement benefit plans was $19 and $17 as of September 30, 2021 and 2020, 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, 2021 and 2020. 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 2021 2020 Change in benefit obligations: Benefit obligations — beginning of year $ 782 $ 750 Service cost 12 11 Interest cost 22 23 Actuarial (gain) loss (30) 27 Plan amendments 2 — Acquisitions 114 — Curtailments — (2) Foreign currency (gain) loss (1) 3 Benefits paid (31) (30) Benefit obligations — end of year (a) $ 870 $ 782 Change in plan assets: Pension Benefits 2021 2020 Fair value of plan assets — beginning of year $ 585 $ 547 Actual gain on plan assets 75 53 Foreign currency — 1 Employer contributions 14 13 Acquisitions 92 — Benefits paid (30) (29) Fair value of plan assets — end of year $ 736 $ 585 Funded status of the plans — end of year (b) $ (134) $ (197) Amounts recorded in UGI Corporation stockholders’ equity (pre-tax): Prior service cost $ 3 $ 1 Net actuarial loss 13 24 Total $ 16 $ 25 Amounts recorded in regulatory assets and liabilities (pre-tax): Net actuarial loss 108 174 Total $ 108 $ 174 (a) The ABO for the U.S. Pension Plans was $756 and $687 as of September 30, 2021 and 2020, respectively. (b) Amounts are reflected in “Other noncurrent liabilities” on the Consolidated Balance Sheets. In Fiscal 2021 and Fiscal 2020, the change in the pension plans’ PBO due to actuarial gains and losses is principally the result of changes in discount rates. In Fiscal 2022, the estimated amount that will be amortized from UGI Stockholders’ equity and regulatory assets into net periodic benefit cost is approximately $7, the majority of which represents net actuarial losses, primarily associated with the U.S. Pension Plans. 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 2021 2020 2019 Weighted-average assumptions: Discount rate – benefit obligations 3.13 % 2.90 % 3.30 % Discount rate – benefit cost 2.90 % 3.30 % 4.40 % Expected return on plan assets 7.10 % 7.20 % 7.30 % 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, are reflected in “Operating and administrative expenses” on the Consolidated Statements of Income. The non-service cost components, net of amounts capitalized by UGI 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 2021 2020 2019 Service cost $ 12 $ 11 $ 10 Interest cost 22 23 27 Expected return on assets (40) (38) (36) Curtailment gain — (1) — Amortization of: Prior service cost — 1 — Actuarial loss 14 15 8 Net cost $ 8 $ 11 $ 9 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 2021, Fiscal 2020 and Fiscal 2019, we made cash contributions to the U.S. Pension Plans of $13, $13 and $12, respectively. The minimum required contributions in Fiscal 2022 are not expected to be material. UGI Utilities, Inc. 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 2022. Expected payments for postretirement benefits over the next 10 years are not material. Expected payments for pension benefits are as follows: Pension Fiscal 2022 $ 36 Fiscal 2023 $ 36 Fiscal 2024 $ 41 Fiscal 2025 $ 41 Fiscal 2026 $ 43 Fiscal 2027 - 2031 $ 230 We also sponsor unfunded and non-qualified supplemental executive defined benefit retirement plans. At September 30, 2021 and 2020, the PBOs of these plans, including obligations for amounts held in grantor trusts, totaled $57 and $59, 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 $10 and $12 at September 30, 2021 and 2020, respectively, principally representing unrecognized actuarial losses. In Fiscal 2022, 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 2020 and Fiscal 2019, 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 $44 and $35 at September 30, 2021 and 2020, 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 an investment 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) 2021 2020 2021 2020 Equity investments: U.S. equities 22.2 % 26.5 % 25.3 % 29.0 % Non-U.S. equities 21.7 % 25.0 % 21.4 % 24.5 % Global equities (a) 16.0 % 12.3 % 13.1 % 11.5 % Total 59.9 % 63.8 % 59.8 % 65.0 % Fixed income funds & cash equivalents 36.4 % 36.2 % 34.4 % 35.0 % Alternative investments 3.7 % — % 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, 2021 and 2020 are as follows: 2021 2020 U.S. Pension Plans: Domestic equity investments: UGI Corporation Common Stock $ 35 $ 27 Total domestic equity investments (a) 35 27 Common collective trust funds: U.S. equity index investments 124 123 Non-U.S. equity index investments 155 141 Global equity index investments 115 70 Bond index investments 254 200 Cash equivalents 7 5 Total common collective trust funds (b) 655 539 Alternative investments (b) 27 — Total $ 717 $ 566 (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 2021, $21 in Fiscal 2020 and $19 in Fiscal 2019. 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 2021, Fiscal 2020 and Fiscal 2019 were not material. At September 30, 2021 and 2020, the total fair values of these grantor trust investment assets, which amounts are included in “Other assets” on the Consolidated Balance Sheets, were $9 and $7, respectively.

Utility Regulatory Assets and L

Utility Regulatory Assets and Liabilities and Regulatory Matters	12 Months Ended
	Sep. 30, 2021
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 UGI Utilities reportable segment are included in our Consolidated Balance Sheets at September 30: 2021 2020 Regulatory assets (a): Income taxes recoverable $ 143 $ 124 Underfunded pension and postretirement plans 108 175 Environmental costs 58 61 Deferred fuel and power costs 11 — Removal costs, net 24 26 Other 53 11 Total regulatory assets $ 397 $ 397 Regulatory liabilities (a): Postretirement benefit overcollections $ 13 $ 13 Deferred fuel and power refunds 36 29 State income tax benefits — distribution system repairs 32 28 PAPUC Temporary Rates Order — 7 Excess federal deferred income taxes 287 274 Other 20 2 Total regulatory liabilities $ 388 $ 353 (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, UGI 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. UGI Utilities has recorded regulatory income tax assets related to these deferred tax liabilities representing future revenues recoverable through the ratemaking process over the average remaining depreciable lives of the associated property ranging from 1 to approximately 65 years. Underfunded pension and other postretirement plans . This regulatory asset represents the portion of net actuarial losses and prior service costs (credits) associated with pension and other postretirement 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 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, 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 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. As required by PAPUC ratemaking, removal costs include actual costs incurred associated with asset retirement obligations. Consistent with prior ratemaking treatment, UGI Utilities, Inc. expects to recover these costs over five years. Postretirement benefit overcollections . This regulatory liability represents the difference between amounts recovered through rates by Gas Utility and Electric Utility and actual costs incurred in accordance with accounting for postretirement benefits. 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 refunds. UGI 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. Gas Utility uses derivative instruments to reduce volatility in the cost of gas it purchases for retail core-market customers. Realized and unrealized gains or losses on natural gas derivative instruments are included in deferred fuel and power costs or refunds. Net unrealized gains (losses) on such contracts at September 30, 2021 and 2020 were $35 and $8, 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, Inc.’s assets that are capitalized for regulatory and U.S. 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. PAPUC Temporary Rates Order. On May 17, 2018, the PAPUC ordered each regulated utility currently not in a general base rate case proceeding, including Gas Utility, to reduce their rates to credit customers any tax savings as a result of the TCJA through the establishment of a negative surcharge. These negative surcharges applied to bills rendered on or after July 1, 2018 and remained in effect until October 11, 2019, the effective date of Gas Utility’s new base rates, subject to a final reconciliation of any over- or under-crediting of the tax savings. The remaining regulatory liability was returned to customers through an additional temporary negative surcharge from January 1, 2021 through October 10, 2021 In its May 17, 2018 Order, the PAPUC also required Pennsylvania utilities to establish a regulatory liability for tax benefits that accrued during the period January 1, 2018 through June 30, 2018, resulting from the reduced federal tax rate. The rate treatment of this regulatory liability was addressed in Gas Utility’s base rate proceeding filed January 28, 2019 (see “Base Rate Filings” below for further information). For Pennsylvania utilities that were in a general base rate proceeding, including Electric Utility, no negative surcharge applied. The tax benefits that accrued during the period January 1, 2018 through October 26, 2018, the date before Electric Utility’s base rate case became effective were refunded to Electric Utility ratepayers through a one-time bill credit. Excess federal deferred income taxes. This regulatory liability is the result of remeasuring UGI 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 ongoing COVID-19 pandemic, certain information technology costs, energy efficiency conservation costs and rate case expenses. Other Regulatory Matters Base Rate Filings. 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, 2021
Inventory Disclosure [Abstract]
Inventories	Note 10 — Inventories Inventories comprise the following at September 30: 2021 2020 Non-utility LPG and natural gas $ 278 $ 164 Utility natural gas 68 20 Energy certificates 53 3 Materials, supplies and other 70 54 Total inventories $ 469 $ 241

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Sep. 30, 2021
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: 2021 2020 Estimated Useful Life Utility: Distribution $ 4,306 $ 3,630 Transmission 111 111 General and other 507 425 Work in process 98 99 Total Utility 5,022 4,265 Non-utility: Land 186 191 Buildings and improvements 436 431 10 - 40 years Transportation equipment 232 248 3 - 10 years Equipment, primarily cylinders and tanks 3,785 3,712 5 - 30 years Electric generation 211 211 25 - 40 years Pipeline and related assets 1,218 1,098 25 - 40 years Other 342 306 1 - 12 years Work in process 76 196 Total non-utility 6,486 6,393 Total property, plant and equipment $ 11,508 $ 10,658 The average composite depreciation rates at our regulated natural gas utilities (inclusive of Gas Utility and Mountaineer) and Electric Utility were as follows: 2021 2020 2019 Regulated natural gas utilities 2.6 % 2.5 % 2.2 % Electric Utility 2.3 % 2.2 % 2.1 % Depreciation expense totaled $437, $416 and $389 for Fiscal 2021, Fiscal 2020 and Fiscal 2019, respectively.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Sep. 30, 2021
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 UGI Utilities Total Balance September 30, 2019 $ 2,004 $ 930 $ 340 $ 182 $ 3,456 Dispositions — — (5) — (5) Purchase accounting adjustments — (2) — — (2) Foreign currency translation — 69 — — 69 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 Intangible assets comprise the following at September 30: 2021 2020 Customer relationships $ 1,054 $ 1,083 Trademarks and tradenames 12 12 Noncompete agreements and other 75 76 Accumulated amortization (607) (543) Intangible assets, net (definite-lived) 534 628 Trademarks and tradenames (indefinite-lived) 49 49 Total intangible assets, net $ 583 $ 677 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 $76, $83 and $59 for Fiscal 2021, Fiscal 2020 and Fiscal 2019, respectively. Estimated amortization expense of intangible assets during the next five fiscal years is as follows: Fiscal 2022 — $61; Fiscal 2023 — $57; Fiscal 2024 — $55; Fiscal 2025 — $53; Fiscal 2026 — $52.

Equity

Equity	12 Months Ended
	Sep. 30, 2021
Equity [Abstract]
Equity	Note 13 — Equity On January 25, 2018, UGI’s Board of Directors authorized the repurchase of up to 8,000,000 shares of UGI Corporation Common Stock over a four-year period. Pursuant to these authorizations, during Fiscal 2020 and Fiscal 2019, the Company purchased and placed in treasury stock 950,000 and 300,000 shares at a total cost of $38 and $17, respectively. There were no such repurchases during Fiscal 2021. UGI Preferred Stock and Common Stock share activity for Fiscal 2021, Fiscal 2020 and Fiscal 2019 is as follows: Preferred Stock Common Stock Issued/Outstanding Issued Treasury Outstanding Balance at September 30, 2018 — 174,142,997 (394,022) 173,748,975 Issued: Employee and director plans — 548,285 430,847 979,132 AmeriGas Merger — 34,612,847 — 34,612,847 Sale of reacquired common stock — — 15,759 15,759 Repurchases of common stock — — (300,000) (300,000) Reacquired common stock – employee and director plans — — (51,924) (51,924) 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 Balance at September 30, 2020 — 209,514,044 (1,159,606) 208,354,438 Issued: Equity Unit offering 220,000 — — — Employee and director plans — 329,252 554,315 883,567 Reacquired common stock – employee and director plans — — (21,870) (21,870) Balance at September 30, 2021 220,000 209,843,296 (627,161) 209,216,135 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, 2021 or 2020. 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, recording $213 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. 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, 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’s common stock on the purchase contract settlement date, which is scheduled to occur on June 1, 2024. The number of shares of UGI’s 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’s 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’s 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’s 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’s common stock equal to 85% of the number of shares of UGI’s 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’s common stock or a combination of cash and shares of UGI’s 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” on the Consolidated Balance Sheet. Such liability reduced “UGI Common Stock” on the Consolidated Balance Sheet at inception. 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 2021.

Equity-Based Compensation

Equity-Based Compensation	12 Months Ended
	Sep. 30, 2021
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, UGI Common Stock-based equity instruments and, prior to the AmeriGas Merger, AmeriGas Partners Common Unit-based equity instruments. We recognized total pre-tax equity-based compensation expense of $21 ($15 after-tax), $15 ($11 after-tax) and $18 ($13 after-tax) in Fiscal 2021, Fiscal 2020 and Fiscal 2019, 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 20,037,430 shares of Common Stock available for future grants under the 2021 IAP at September 30, 2021 . 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 $6.05, $5.58 and $8.70 in Fiscal 2021, Fiscal 2020 and Fiscal 2019, respectively. As of September 30, 2021, there was $7 of unrecognized compensation cost associated with unvested stock options that is expected to be recognized over a weighted-average period of 2.0 years. There were 10,204,836 stock options outstanding at September 30, 2021, of which, 7,445,827 stock options were exercisable with a weighted-average option price of $38.42. 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 2021, Fiscal 2020, and Fiscal 2019 was $41.41, $41.47 and $55.40, respectively. As of September 30, 2021, there was a total of $19 unrecognized compensation cost associated with UGI Unit awards outstanding that is expected to be recognized over a weighted-average period of 1.9 years. As of September 30, 2021, there were 1,124,369 UGI Unit awards outstanding with a weighted-average grant-date fair value of $33.41 per share.

Partnership Distributions

Partnership Distributions	12 Months Ended
	Sep. 30, 2021
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. Prior to the AmeriGas Merger, distributions of Available Cash were made 98% to limited partners and 2% to the General Partner (representing a 1% General Partner interest in AmeriGas Partners and 1.01% interest in AmeriGas OLP) in accordance with available cash and target distribution tiers (as defined in the Partnership Agreement). When available cash exceeded a certain distribution tier in any quarter, the General Partner would receive a greater percentage of the total Partnership distribution (the “incentive distribution”) but only with respect to the amount by which the distribution exceeded the defined amount. During Fiscal 2019 (prior to the AmeriGas Merger), the Partnership made quarterly distributions in excess of the defined amount. As a result, the General Partner received a greater percentage of the total Partnership distribution than its aggregate 2% general partner interest in AmeriGas OLP and AmeriGas Partners. During Fiscal 2019, distributions received by the

Leases

Leases	12 Months Ended
	Sep. 30, 2021
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: 2021 2020 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 390 $ 415 Other assets Finance lease ROU assets 49 52 Property, plant and equipment Total ROU assets $ 439 $ 467 Lease liabilities: Operating lease liabilities — current $ 81 $ 87 Other current liabilities Operating lease liabilities — noncurrent 318 334 Other noncurrent liabilities Finance lease liabilities — current 4 5 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 41 Long-term debt Total lease liabilities $ 444 $ 467 The components of lease cost for Fiscal 2021 and Fiscal 2020 are as follows: 2021 2020 Operating lease cost $ 101 $ 102 Finance lease cost: Amortization of ROU assets 4 5 Interest on lease liabilities 3 3 Variable lease cost 4 5 Short-term lease cost 2 3 Total lease cost $ 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 2021 and Fiscal 2020: 2021 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 99 $ 103 Operating cash flows — finance leases $ 3 $ 3 Financing cash flows — finance leases $ 3 $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (a) $ 85 $ 506 ROU assets obtained in exchange for finance lease liabilities $ 1 $ 22 (a) Fiscal 2020 includes the impact of the adoption of ASC842. The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2021 2020 Operating leases 6.3 6.2 Finance leases 2.4 2.4 Weighted-average discount rate (%) 2021 2020 Operating leases 3.6% 3.8% Finance leases 1.5% 1.9% 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, 2021, were as follows: 2022 2023 2024 2025 2026 After 2026 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 92 $ 81 $ 71 $ 55 $ 44 $ 103 $ 446 $ (47) $ 399 Finance leases $ 4 $ 4 $ 3 $ 3 $ 3 $ 81 $ 98 $ (53) $ 45 Approximately 85% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2021, 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: 2021 2020 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 390 $ 415 Other assets Finance lease ROU assets 49 52 Property, plant and equipment Total ROU assets $ 439 $ 467 Lease liabilities: Operating lease liabilities — current $ 81 $ 87 Other current liabilities Operating lease liabilities — noncurrent 318 334 Other noncurrent liabilities Finance lease liabilities — current 4 5 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 41 Long-term debt Total lease liabilities $ 444 $ 467 The components of lease cost for Fiscal 2021 and Fiscal 2020 are as follows: 2021 2020 Operating lease cost $ 101 $ 102 Finance lease cost: Amortization of ROU assets 4 5 Interest on lease liabilities 3 3 Variable lease cost 4 5 Short-term lease cost 2 3 Total lease cost $ 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 2021 and Fiscal 2020: 2021 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 99 $ 103 Operating cash flows — finance leases $ 3 $ 3 Financing cash flows — finance leases $ 3 $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (a) $ 85 $ 506 ROU assets obtained in exchange for finance lease liabilities $ 1 $ 22 (a) Fiscal 2020 includes the impact of the adoption of ASC842. The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2021 2020 Operating leases 6.3 6.2 Finance leases 2.4 2.4 Weighted-average discount rate (%) 2021 2020 Operating leases 3.6% 3.8% Finance leases 1.5% 1.9% 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, 2021, were as follows: 2022 2023 2024 2025 2026 After 2026 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 92 $ 81 $ 71 $ 55 $ 44 $ 103 $ 446 $ (47) $ 399 Finance leases $ 4 $ 4 $ 3 $ 3 $ 3 $ 81 $ 98 $ (53) $ 45 Approximately 85% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2021, 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: 2021 2020 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 390 $ 415 Other assets Finance lease ROU assets 49 52 Property, plant and equipment Total ROU assets $ 439 $ 467 Lease liabilities: Operating lease liabilities — current $ 81 $ 87 Other current liabilities Operating lease liabilities — noncurrent 318 334 Other noncurrent liabilities Finance lease liabilities — current 4 5 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 41 Long-term debt Total lease liabilities $ 444 $ 467 The components of lease cost for Fiscal 2021 and Fiscal 2020 are as follows: 2021 2020 Operating lease cost $ 101 $ 102 Finance lease cost: Amortization of ROU assets 4 5 Interest on lease liabilities 3 3 Variable lease cost 4 5 Short-term lease cost 2 3 Total lease cost $ 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 2021 and Fiscal 2020: 2021 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 99 $ 103 Operating cash flows — finance leases $ 3 $ 3 Financing cash flows — finance leases $ 3 $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (a) $ 85 $ 506 ROU assets obtained in exchange for finance lease liabilities $ 1 $ 22 (a) Fiscal 2020 includes the impact of the adoption of ASC842. The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2021 2020 Operating leases 6.3 6.2 Finance leases 2.4 2.4 Weighted-average discount rate (%) 2021 2020 Operating leases 3.6% 3.8% Finance leases 1.5% 1.9% 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, 2021, were as follows: 2022 2023 2024 2025 2026 After 2026 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 92 $ 81 $ 71 $ 55 $ 44 $ 103 $ 446 $ (47) $ 399 Finance leases $ 4 $ 4 $ 3 $ 3 $ 3 $ 81 $ 98 $ (53) $ 45 Approximately 85% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2021, operating and finance leases that had not yet commenced were not material. Lessor

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Sep. 30, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 17 — Commitments and Contingencies Environmental Matters UGI Utilities, Inc. From the late 1800s through the mid-1900s, UGI Utilities, Inc. 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, Inc. 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, Inc. divested all of its utility operations other than certain gas and electric operations. Beginning in 2006 and 2008, UGI Utilities, Inc. also owned and operated two acquired subsidiaries, with similar histories of owning, and in some cases operating, MGPs in Pennsylvania. Prior to October 1, 2020, UGI Utilities, Inc. was subject to three COAs with the PADEP to address the remediation of specified former MGP sites in Pennsylvania and in the case of one COA, the plugging of specified natural gas wells. Effective October 1, 2020, the three COAs were consolidated into one agreement that supersedes the existing agreements and which is scheduled to terminate at the end of 2031. In accordance with the consolidated COA, UGI Utilities, Inc. 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 consolidated COA is $5. The consolidated COA permits the transfer of the specified wells, with related costs counted towards the annual minimum expenditure. At September 30, 2021 and 2020, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the current COA and the predecessor agreements totaled $50 and $53, respectively. We do not expect the costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to UGI Utilities, Inc.’s results of operations because UGI Utilities, Inc. 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, Inc. 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, Inc. is notified of sites outside Pennsylvania on which private parties allege MGPs were formerly owned or operated by UGI Utilities, Inc. 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, Inc. 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, Inc. directly operated, or that were owned or operated by a former subsidiary of UGI Utilities, Inc. if a court were to conclude that (1) the subsidiary’s separate corporate form should be disregarded, or (2) UGI Utilities, Inc. 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, Inc.’s MGP sites outside Pennsylvania was 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, 2021 and 2020, the Partnership has an undiscounted environmental remediation liability of $8 related to the site. Our share of the actual remediation costs could be significantly more or less than the accrued amount. Other Matters Purported Class Action Lawsuits. Between May and October of 2014, purported class action lawsuits were filed in multiple jurisdictions against the Partnership/UGI and a competitor by certain of their direct and indirect customers. The class action lawsuits allege, among other things, that the Partnership and its competitor colluded, beginning in 2008, to reduce the fill level of portable propane cylinders from 17 pounds to 15 pounds and combined to persuade their common customer, Walmart Stores, Inc., to accept that fill reduction, resulting in increased cylinder costs to retailers and end-user customers in violation of federal and certain state antitrust laws. The claims seek treble damages, injunctive relief, attorneys’ fees and costs on behalf of the putative classes. On October 16, 2014, the United States Judicial Panel on Multidistrict Litigation transferred all of these purported class action cases to the Western Missouri District Court. As the result of rulings on a series of procedural filings, including petitions filed with the Eighth Circuit and the U.S. Supreme Court, both the federal and state law claims of the direct customer plaintiffs and the state law claims of the indirect customer plaintiffs were remanded to the Western Missouri District Court. The decision of the Western Missouri District Court to dismiss the federal antitrust claims of the indirect customer plaintiffs was upheld by the Eighth Circuit. On April 15, 2019, the Western Missouri District Court ruled that it has jurisdiction over the indirect purchasers’ state law claims and that the indirect customer plaintiffs have standing to pursue those claims. On August 21, 2019, the District Court partially granted the Company’s motion for judgment on the pleadings and dismissed the claims of indirect customer plaintiffs from ten states and the District of Columbia. On October 2, 2019, the Partnership reached an agreement to resolve the claims of the direct purchaser class of plaintiffs; the agreement received final court approval on June 18, 2020. On September 18, 2020, the Partnership and counsel for the indirect purchaser plaintiffs filed a joint statement with the court that they had reached an agreement in principle to settle the claims of the remaining classes and plaintiffs, the settlement received final court approval on March 30, 2021. As of September 30, 2021 there were no further liabilities associated with this matter. 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, 2021
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, 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 September 30, 2020 Derivative instruments: Assets: Commodity contracts $ 68 $ 39 $ — $ 107 Foreign currency contracts $ — $ 32 $ — $ 32 Liabilities: Commodity contracts $ (54) $ (64) $ — $ (118) Foreign currency contracts $ — $ (14) $ — $ (14) Interest rate contracts $ — $ (55) $ — $ (55) Non-qualified supplemental postretirement grantor trust investments (a) $ 42 $ — $ — $ 42 (a) Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans (see Note 8). 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. The remainder of our derivative instruments are designated as Level 2. The fair values of certain non-exchange-traded commodity derivatives designated as Level 2 are based upon indicative price quotations available through brokers, industry price publications or recent market transactions and related market indicators. The fair values of our Level 2 interest rate contracts and foreign currency contracts are based upon third-party quotes or indicative values based on recent market transactions. The fair values of investments held in grantor trusts are derived from quoted market prices as substantially all of the investments in these trusts have active markets. Other Financial Instruments The carrying amounts of other financial instruments included in current assets and current liabilities (except for current maturities of long-term debt) approximate their fair values because of their short-term nature. We estimate the fair value of long-term debt by using current market rates and by discounting future cash flows using rates available for similar type debt (Level 2). The carrying amounts and estimated fair values of our long-term debt (including current maturities but excluding unamortized debt issuance costs) were as follows: 2021 2020 Carrying amount $ 6,491 $ 6,081 Estimated fair value $ 6,996 $ 6,504

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Sep. 30, 2021
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 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 Gas Utility’s annual PGC filings, 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 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 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, 2021, 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 $4. 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 U.S. dollar 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. In order to reduce exposure to foreign exchange rate volatility related to our foreign LPG operations, we previously entered into forward foreign currency exchange contracts to hedge a portion of anticipated U.S. dollar-denominated LPG product purchases primarily during the heating-season months of October through March. The last such contracts expired in September 2019. We accounted for these foreign currency exchange contracts as cash flow hedges. Net Investment Hedges From time to time we also enter into certain forward foreign currency exchange contracts to reduce the volatility of the U.S. dollar value of a portion of our UGI International euro-denominated net investments. We account for these foreign currency exchange contracts as net investment hedges and all changes in the fair value of these contracts are reported in the cumulative translation adjustment component in AOCI. We use the spot rate method to measure ineffectiveness of our net investment hedges. Our euro-denominated long-term debt has also been designated as net investment hedges of a portion of our UGI International euro-denominated net investment. We recognized pre-tax gains (losses) associated with these net investment hedges in the cumulative translation adjustment component in AOCI of $9 and $(53) during Fiscal 2021 and 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, 2021 and 2020 and the final settlement dates of the Company's open derivative contracts as of September 30, 2021, excluding those derivatives that qualified for the NPNS exception: Notional Amounts September 30, Type Units Settlements Extending Through 2021 2020 Commodity Price Risk: Regulated Utility Operations Gas Utility NYMEX natural gas futures and option contracts Dekatherms September 2022 20 22 Non-utility Operations LPG swaps Gallons November 2023 708 846 Natural gas futures, forward, basis swap, options and pipeline contracts Dekatherms April 2026 355 339 Electricity forward and futures contracts Kilowatt hours January 2026 4,302 4,705 Interest Rate Risk: Interest rate swaps Euro October 2022 € 300 € 300 Interest rate swaps USD September 2024 $ 1,421 $ 1,344 Foreign Currency Exchange Rate Risk: Forward foreign exchange contracts USD September 2024 $ 509 $ 511 Net investment hedge forward foreign exchange contracts Euro October 2024 € 173 € 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, 2021, 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 $1,687. 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, 2021, we had received cash collateral from derivative instrument counterparties totaling $468. 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, 2021, 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: 2021 2020 Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 20 $ 17 Derivatives subject to PGC and DS mechanisms: Commodity contracts 58 7 Derivatives not designated as hedging instruments: Commodity contracts 1,591 100 Foreign currency contracts 18 15 1,609 115 Total derivative assets – gross 1,687 139 Gross amounts offset in the balance sheet (216) (57) Cash collateral received (468) — Total derivative assets – net $ 1,003 $ 82 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts $ (29) $ (55) Derivatives subject to PGC and DS mechanisms: Commodity contracts (23) — Derivatives not designated as hedging instruments: Commodity contracts (257) (118) Foreign currency contracts (8) (14) (265) (132) Total derivative liabilities – gross (317) (187) Gross amounts offset in the balance sheet 216 57 Cash collateral pledged 3 7 Total derivative liabilities – net $ (98) $ (123) 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 2021, Fiscal 2020 and Fiscal 2019: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from 2021 2020 2019 2021 2020 2019 Cash Flow Hedges: Foreign currency contracts $ — $ — $ 1 $ — $ — $ 2 Cost of sales Interest rate contracts 4 (53) (11) (25) (13) (6) Interest expense Total $ 4 $ (53) $ (10) $ (25) $ (13) $ (4) Net Investment Hedges: Foreign currency contracts $ 4 $ (1) $ 17 Gain (Loss) Location of 2021 2020 2019 Derivatives Not Designated as Hedging Instruments: Commodity contracts $ (17) $ 10 $ 7 Revenues Commodity contracts 1,545 (32) (344) Cost of sales Commodity contracts 5 — — Other operating income, net Foreign currency contracts 9 (20) 38 Other non-operating income (expense), net Total $ 1,542 $ (42) $ (299) 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, 2021
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 table below presents changes in AOCI, net of tax, during Fiscal 2021, Fiscal 2020 and Fiscal 2019: Postretirement Derivative Foreign Total AOCI - September 30, 2018 $ (11) $ (16) $ (83) $ (110) Other comprehensive loss before reclassification adjustments (after-tax) (13) (7) (83) (103) Amounts reclassified from AOCI 1 2 — 3 Other comprehensive loss attributable to UGI (12) (5) (83) (100) Reclassification of stranded income tax effects related to TCJA (3) (4) — (7) AOCI - September 30, 2019 $ (26) $ (25) $ (166) $ (217) Other comprehensive (loss) income before reclassification adjustments (after-tax) (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 (after-tax) 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 Operating Income, Net and

Other Operating Income, Net and Other Non-Operating Income (Expense), Net	12 Months Ended
	Sep. 30, 2021
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: 2021 2020 2019 Finance charges $ 17 $ 9 $ 17 Gains on sales of fixed assets, net 11 5 3 Gain on early derivative termination 5 — — Interest and interest-related income — 2 6 Utility non-tariff service income — — 1 Other, net — 5 4 Total other operating income, net $ 33 $ 21 $ 31 Other Non-Operating Income (Expense), Net Other non-operating income (expense), net comprises the following: 2021 2020 2019 Gains (losses) on foreign currency contracts, net $ 9 $ (20) $ 38 Amortization of excluded components of certain net investment hedges 2 — — Pension and other postretirement plans non-service income, net 1 — 1 Total other non-operating income (expense), net $ 12 $ (20) $ 39

Equity Method Investments

Equity Method Investments	12 Months Ended
	Sep. 30, 2021
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Note 22 — Equity Method Investments Our equity method investments, which are included within “Other assets” on the Consolidated Balance Sheets, primarily comprises PennEast, Pennant and Pine Run. 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, PennEast ceased further development of the proposed pipeline project. 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. The carrying value of our investment in PennEast at September 30, 2021 was not material. Pennant . Energy Services holds a 47% membership interest in Pennant, a natural gas gathering system located in northeast Ohio and western Pennsylvania. Pennant is accounted for as an equity method investment as we have the ability to exercise significant influence, but not control, over Pennant. The carrying value of our investment in Pennant at September 30, 2021 and 2020 was $93 and $94, respectively. Pine Run. In February 2021, Pine Run, a company jointly owned by Stonehenge and UGI Pine Run, LLC, a wholly-owned subsidiary of Energy Services, completed the acquisition of Pine Run Midstream, LLC from an affiliate of PennEnergy and minority partners for a preliminary purchase price of $205. Pine Run Midstream, LLC operates 43 miles of dry gas gathering pipeline and compression assets in Butler and Armstrong counties 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, 2021 was $60.

Segment Information

Segment Information	12 Months Ended
	Sep. 30, 2021
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) UGI 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 in France and in northern, central and eastern European countries. 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. 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 and the panhandle of West Virginia. 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 UGI Utilities segment primarily derives its revenues principally from the sale and distribution of natural gas to customers in eastern and central Pennsylvania and, to a lesser extent, from the sale and distribution of electricity in two northeastern Pennsylvania counties. In September 2021, UGI acquired Mountaineer, the largest natural gas distributor in West Virginia. Mountaineer is now included within our UGI Utilities reportable segment (see Note 5). 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 debt incurred by UGI Corporation 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 UGI Utilities Corporate & 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 (c) $ 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 Total Elim- AmeriGas UGI International Midstream UGI Utilities Corporate & 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 $ — $ — 2019 Revenues from external customers $ 7,320 $ — $ 2,682 $ 2,372 $ 1,281 $ 981 $ 4 Intersegment revenues $ — $ (306) (b) $ — $ — $ 235 $ 68 $ 3 Cost of sales $ 4,323 $ (301) (b) $ 1,191 $ 1,416 $ 1,241 $ 481 $ 295 Operating income (loss) $ 617 $ — $ 404 $ 229 $ 105 $ 224 $ (345) Income from equity investees 9 — — — 9 — — Loss on extinguishments of debt (6) — — — — — (6) Other non-operating income (expense), net 39 (1) — 5 — 2 33 Earnings (loss) before interest expense and income taxes 659 (1) 404 234 114 226 (318) Interest expense (258) — (167) (25) (9) (50) (7) Income tax (expense) benefit (93) — (26) (64) (27) (43) 67 Noncontrolling interests’ net (income) loss (52) — (143) — — — 91 Net income (loss) attributable to UGI $ 256 $ (1) $ 68 $ 145 $ 78 $ 133 $ (167) Depreciation and amortization $ 448 $ — $ 179 $ 124 $ 51 $ 93 $ 1 Total assets $ 13,347 $ (353) $ 4,095 $ 2,975 $ 2,745 $ 3,560 $ 325 Short-term borrowings $ 796 $ — $ 328 $ 211 $ 91 $ 166 $ — Capital expenditures (including the effects of accruals) $ 707 $ — $ 107 $ 106 $ 138 $ 355 $ 1 Investments in equity investees $ 190 $ — $ — $ 12 $ 178 $ — $ — (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 2021, Fiscal 2020 and Fiscal 2019: Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing 2021 Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (15) Net gains on commodity derivative instruments not associated with current-period transactions Cost of Sales $ 167 $ 1,065 $ 173 Unrealized gains on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 8 $ — Business transformation expenses Operating and administrative expenses $ (54) $ (33) $ — Impairment of customer relationship intangible Operating and administrative expenses $ — $ (20) $ — Impairment of investment in PennEast (Loss) income from equity method 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 (expense) income, 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) 2019 Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ 4 Net losses on commodity derivative instruments not associated with current-period transactions Cost of Sales $ (117) $ (143) $ (35) Unrealized gains on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 32 $ — Loss on extinguishments of debt Loss on extinguishment of debt $ — $ (6) $ — AmeriGas Merger expenses Operating and administrative expenses $ (6) $ — $ — Acquisition and integration expenses associated with the CMG Acquisition Operating and administrative expenses $ — $ — $ (16) Business transformation expenses Operating and administrative expenses $ (15) $ (9) $ — (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane. (c) Beginning October 1, 2019, UGI International is allocated a portion of indirect corporate expenses. Prior to October 1, 2019, these expenses were billed to its parent company, which is included in Corporate & Other.

Business Transformation Initiat

Business Transformation Initiatives	12 Months Ended
	Sep. 30, 2021
Restructuring and Related Activities [Abstract]
Business Transformation Initiatives	Note 24 — Business Transformation Initiatives AmeriGas and UGI International. During the fourth quarter of Fiscal 2019, we began executing on multi-year business transformation initiatives at our AmeriGas Propane and UGI International business segments. These initiatives are designed to improve long-term operational performance by, among other things, reducing costs and improving efficiency in the areas of sales and marketing, supply and logistics, operations, purchasing, and administration. In addition, these business transformation initiatives focus on enhancing the customer experience through, among other things, enhanced customer relationship management and an improved digital customer experience. These business transformation initiatives are substantially complete, and during Fiscal 2021, Fiscal 2020 and Fiscal 2019 we incurred $87, $62 and $24 respectively, of costs principally comprising consulting, advisory, marketing and employee-related costs. These costs are primarily reflected in “Operating and administrative expenses” on the Consolidated Statements of Income.

Impact of Global Pandemic

Impact of Global Pandemic	12 Months Ended
	Sep. 30, 2021
Unusual or Infrequent Items, or Both [Abstract]
Impact of Global Pandemic	Note 25 — Impact of Global Pandemic In March 2020, the WHO declared a global pandemic attributable to the outbreak and continued spread of COVID-19 that has had a significant impact throughout the global economy. In connection with the mitigation and containment procedures recommended by the WHO, the CDC, and as imposed by federal, state, and local governmental authorities, including shelter-in-place orders, quarantines and similar restrictions, the Company implemented a variety of procedures to protect our employees, third-party business partners, and customers worldwide. The Company continues to provide essential products and services to its global customers in a safe and reliable manner, and will continue to do so in compliance with mandated restrictions presented by each of the markets it serves. The Company continues to evaluate and react to the potential effects of a prolonged disruption and the continued impact on its results of operations. These items may include, but are not limited to: the financial condition of its customers; decreased availability and demand for its products and services; realization of accounts receivable; impairment considerations related to certain current assets, long-lived assets and goodwill; delays related to current and future projects; and the effects of government stimulus efforts including tax legislation in response to COVID-19. While its operations and financial performance continue to be impacted by COVID-19, the Company cannot predict the duration or magnitude of the pandemic and the total effects on its business, financial position, results of operations, liquidity or cash flows at this time.

SCHEDULE I _ CONDENSED FINANCIA

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)	12 Months Ended
	Sep. 30, 2021
Condensed Financial Information Disclosure [Abstract]
SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)	BALANCE SHEETS (Millions of dollars) September 30, 2021 2020 ASSETS Current assets: Cash and cash equivalents $ 14 $ 67 Accounts receivable – related parties 18 11 Prepaid expenses and other current assets 11 15 Total current assets 43 93 Property, plant and equipment, net 2 2 Investments in subsidiaries 6,479 4,898 Other assets 107 87 Total assets $ 6,631 $ 5,080 LIABILITIES AND COMMON STOCKHOLDERS’ EQUITY Current liabilities: Current maturities of long-term debt $ 70 $ 30 Accounts and notes payable 24 15 Accrued liabilities 62 29 Total current liabilities 156 74 Long-term debt 875 817 Other noncurrent liabilities 78 61 Total liabilities 1,109 952 Commitments and contingencies (Note 1) Equity: Preferred Stock, without par value (authorized - 5,000,000; issued - 220,000 and 0, respectively) 213 — Common Stock, without par value (authorized – 450,000,000 shares; issued – 209,843,296 and 209,514,044 shares, respectively) 1,394 1,416 Retained earnings 4,081 2,908 Accumulated other comprehensive loss (140) (147) Treasury stock, at cost (26) (49) Total common stockholders’ equity 5,522 4,128 Total liabilities and common stockholders’ equity $ 6,631 $ 5,080 Note 1 — Commitments and Contingencies: At September 30, 2021, UGI Corporation had agreed to indemnify the issuers of $75 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 $397 of such obligations were outstanding as of September 30, 2021. Scheduled principal repayments of long-term debt during the next five fiscal years include $70 in Fiscal 2022, $38 in Fiscal 2023, $327 in Fiscal 2024 and $515 in Fiscal 2025. STATEMENTS OF INCOME (Millions of dollars, except per share amounts) Year Ended September 30, 2021 2020 2019 Revenues $ — $ — $ — Costs and expenses: Operating and administrative expenses 94 56 50 Other operating income, net (a) (65) (54) (50) 29 2 — Operating loss (29) (2) — Pension and other postretirement plans non-service expense — — (1) Interest expense (27) (32) (6) Loss before income taxes (56) (34) (7) Income tax expense (benefit) 9 17 (3) Loss before equity in income of unconsolidated subsidiaries (65) (51) (4) Equity in income of unconsolidated subsidiaries 1,532 583 260 Net income attributable to UGI Corporation $ 1,467 $ 532 $ 256 Other comprehensive income (loss) 7 (12) (3) Equity in other comprehensive income (loss) of unconsolidated subsidiaries — 82 (97) Comprehensive income attributable to UGI Corporation $ 1,474 $ 602 $ 156 Earnings per common share attributable to UGI Corporation stockholders: Basic $ 7.02 $ 2.55 $ 1.44 Diluted $ 6.92 $ 2.54 $ 1.41 Weighted - average common shares outstanding (thousands): Basic 209,063 208,928 178,417 Diluted 212,126 209,869 181,111 (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, 2021 2020 2019 NET CASH PROVIDED BY OPERATING ACTIVITIES (a) $ 300 $ 322 $ 170 CASH FLOWS FROM INVESTING ACTIVITIES: Net investments in unconsolidated subsidiaries (401) — (768) Net cash used by investing activities (401) — (768) CASH FLOWS FROM FINANCING ACTIVITIES: Payment of dividends on Common Stock (282) (273) (200) Issuances of debt, net of issuance costs 483 60 846 Repayments of long-term debt (385) (60) — Issuance of preferred stock 213 — — Issuances of Common Stock 19 2 17 Repurchases of UGI Common Stock — (38) (17) Other — — (7) Net cash provided (used) by financing activities 48 (309) 639 Cash and cash equivalents (decrease) increase $ (53) $ 13 $ 41 Cash and cash equivalents: End of year $ 14 $ 67 $ 54 Beginning of year 67 54 13 Cash and cash equivalents (decrease) increase $ (53) $ 13 $ 41 (a) Includes dividends received from unconsolidated subsidiaries of $354, $352 and $163 for the years ended September 30, 2021, 2020 and 2019, respectively.

SCHEDULE II _ VALUATION AND QUA

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS	12 Months Ended
	Sep. 30, 2021
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, 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 Year Ended September 30, 2019 Reserves deducted from assets in the consolidated balance sheet: Allowance for doubtful accounts $ 35 $ 29 $ (32) (1) $ 32 Other reserves: Deferred tax assets valuation allowance $ 117 $ (26) $ — $ 91 (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, 2021
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	ertain prior-year amounts have been reclassified to conform to the current-year presentation.
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. Prior to the AmeriGas Merger, we also reported the public’s interest in the Partnership as a noncontrolling interest. 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 valued at their cost less impairment (if any).
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 UGI 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 intangible assets. The allocation of the purchase price may be modified up to one year after the acquisition date, under certain circumstances, as more information is obtained about the fair value of assets acquired and liabilities assumed.
Foreign Currency Translation	Foreign Currency Translation Balance sheets of international subsidiaries are translated into U.S. dollars using the exchange rate at the balance sheet date. Income statements and equity investee results are translated into U.S. dollars 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” on the Consolidated Statements of Income. Depreciation expense associated with the Partnership and UGI International delivery vehicles is classified in “Depreciation and amortization” on the Consolidated Statements of Income.
Income Taxes	Income Taxes AmeriGas Partners and AmeriGas OLP are not directly subject to federal income taxes. Instead, their taxable income or loss is allocated to the individual partners which, prior to the AmeriGas Merger, included public holders of AmeriGas Partners Common Units. 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. UGI 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. UGI 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
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 business. The amounts assigned to property, plant and equipment of acquired businesses are based upon estimated fair value at
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 (other than customer relationships acquired in the CMG Acquisition), certain tradenames and noncompete agreements, generally do not exceed 15 years. The estimated useful lives of customer relationships acquired in the CMG Acquisition is 35 years (see Note 5). 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.
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.
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-
New Accounting Standards Adopted in Fiscal 2021 and Not Yet Adopted	New Accounting Standards Adopted in Fiscal 2021 Credit Losses. Effective October 1, 2020, the Company adopted ASU 2016-13, “Measurement of Credit Losses on Financial Instruments,” including subsequent amendments, using a modified retrospective transition approach. This ASU, as subsequently amended, requires entities to estimate lifetime expected credit losses for financial instruments not measured at fair value through net income, including trade and other receivables, net investments in leases, financial receivables, debt securities, and other financial instruments, which may result in earlier recognition of credit losses. Further, the new current expected credit loss model may affect how entities estimate their allowance for losses related to receivables that are current with respect to their payment terms. The adoption of the new guidance did not have a material impact on our consolidated financial statements. New Accounting Standard Adopted Effective October 1, 2021 Income Taxes. In December 2019, the FASB issued ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” 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. Effective October 1, 2021, the Company adopted this ASU, as updated, using a prospective approach. The adoption of the new guidance did not have a material impact on our consolidated financial statements. Accounting Standard Not Yet Adopted Debt and Derivatives and Hedging. In August 2020, the FASB issued ASU 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40).” The amendments in this ASU affect entities that issue convertible instruments and/or contracts indexed to and potentially settled in an entity’s own equity. This ASU reduces the number of accounting models for convertible debt instruments and convertible preferred stock, expands disclosure requirements for convertible instruments, and simplifies the related earnings per share guidance. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2022 (Fiscal 2023). Early adoption is permitted. The amendments in this ASU may be adopted using the modified or full retrospective transition methods. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the transition method and the period in which the new guidance will be adopted.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Sep. 30, 2021
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) 2021 2020 2019 Weighted-average common shares outstanding for basic computation (a) 209,063 208,928 178,417 Incremental shares issuable for stock options, common stock awards and Equity Units (b) (c) 3,063 941 2,694 Weighted-average common shares outstanding for diluted computation 212,126 209,869 181,111 (a) Fiscal 2019 includes the partial-year impact from the August 2019 issuance of 34,613 shares of UGI Common Stock in connection with the AmeriGas Merger (see Note 5). (b) Fiscal 2021 includes the partial-year 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). (c) For Fiscal 2021, Fiscal 2020 and Fiscal 2019 there were 5,267 shares, 7,056 shares and 1,162 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. 2021 2020 2019 Cash and cash equivalents $ 855 $ 336 $ 447 Restricted cash 22 21 64 Cash, cash equivalents and restricted cash $ 877 $ 357 $ 511
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. 2021 2020 2019 Cash and cash equivalents $ 855 $ 336 $ 447 Restricted cash 22 21 64 Cash, cash equivalents and restricted cash $ 877 $ 357 $ 511

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Sep. 30, 2021
Revenue from Contract with Customer [Abstract]
Schedule of Disaggregation of Revenue By Reportable Segment	The following table presents our disaggregated revenues by reportable segment during Fiscal 2021, Fiscal 2020 and Fiscal 2019: 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI 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 UGI 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 2019 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 553 $ — $ — $ — $ — $ 553 $ — Commercial & Industrial 226 — — — — 226 — Large delivery service 138 — — — — 138 — Off-system sales and capacity releases 46 (65) — — — 111 — Other (c) 15 (3) — — — 18 — Total Utility 978 (68) — — — 1,046 — Non-Utility: LPG: Retail 4,008 — 2,341 1,667 — — — Wholesale 233 — 64 169 — — — Energy Marketing 1,521 (134) — 448 1,207 — — Midstream: Pipeline 95 — — — 95 — — Peaking 17 (97) — — 114 — — Other 2 — — — 2 — — Electricity Generation 43 — — — 43 — — Other 314 (3) 213 55 49 — — Total Non-Utility 6,233 (234) 2,618 2,339 1,510 — — Total revenues from contracts with customers 7,211 (302) 2,618 2,339 1,510 1,046 — Other revenues (b) 109 (4) 64 33 6 3 7 Total revenues $ 7,320 $ (306) $ 2,682 $ 2,372 $ 1,516 $ 1,049 $ 7 (a) Includes intersegment revenues principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane. (b) Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, revenues from alternative revenue programs at UGI Utilities, Inc., and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP. (c) UGI Utilities includes an unallocated negative surcharge revenue reduction of $(6) during Fiscal 2019 as a result of a PAPUC Order issued May 17, 2018, related to the TCJA (see Note 9).

AmeriGas Merger, Acquisitions_2

AmeriGas Merger, Acquisitions and Dispositions (Tables)	12 Months Ended
	Sep. 30, 2021
Business Combinations [Abstract]
Components of the Purchase Price Allocations	The Company has accounted for the Mountaineer Acquisition using the acquisition method. At September 30, 2021, the allocation of the purchase price is substantially complete but remains preliminary pending the finalization of the valuation of the net assets acquired, including the evaluation of certain acquired contracts, regulatory assets, and deferred income taxes, among others. The purchase price allocation will be finalized once these items have been resolved. Accordingly, the fair value estimates presented below relating to these items are subject to change within the measurement period not to exceed one year from the date of acquisition. The components of the preliminary 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 26 Other noncurrent liabilities 29 Total liabilities assumed $ 379 Goodwill 255 Net consideration transferred $ 400 The Company has accounted for the CMG Acquisition using the acquisition method. The components of the final CMG purchase price allocations are as follows: Assets acquired: Accounts receivable $ 10 Prepaid expenses and other current assets 1 Property, plant and equipment 614 Investment in Pennant 88 Intangible assets (a) 250 Total assets acquired $ 963 Liabilities assumed: Accounts payable 3 Total liabilities assumed $ 3 Goodwill 324 Net consideration transferred (including working capital adjustments) $ 1,284 (a) Represents customer relationships having an average amortization period of 35 years.
Total Cash Paid and Liabilities Incurred	Total cash paid and liabilities incurred in connection with these acquisitions were as follows: 2021 2020 2019 UGI International Midstream & Marketing UGI International Midstream & Marketing Total cash paid $ 18 $ 16 $ 49 $ 15 Liabilities incurred — 7 — — Total purchase price $ 18 $ 23 $ 49 $ 15

Debt (Tables)

Debt (Tables)	12 Months Ended
	Sep. 30, 2021
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, 2021 and 2020, 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, 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, Inc. (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 % September 30, 2020 AmeriGas OLP (a) December 2022 $ 600 $ 186 $ 62 $ 352 2.61 % UGI International, LLC (b) October 2023 € 300 € — € — € 300 N.A. Energy Services (c) March 2025 $ 260 $ — $ — $ 260 N.A. UGI Utilities, Inc. (d) June 2024 $ 350 $ 141 $ — $ 209 1.12 % UGI Corporation (f) August 2024 $ 300 $ 300 $ — $ — 2.41 % (a) The AmeriGas OLP Credit Agreement includes a $150 sublimit for letters of credit. (b) The UGI International Credit Facilities Agreement permits UGI International, LLC to borrow in euros or dollars. UGI International repaid all borrowings outstanding on this facility in September 2020. (c) The Energy Services Credit Agreement includes a $50 sublimit for letters of credit and is guaranteed by certain subsidiaries of Energy Services. This credit agreement is collateralized by substantially all of the assets of Energy Services, subject to certain exceptions and carveouts including, but not limited to, accounts receivables and certain real property. (d) UGI Utilities, Inc. 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, 2021 and 2020, management intended to maintain a substantial portion of amounts outstanding under the 2021 UGI Corporation Senior Credit Facility and its predecessor agreement beyond twelve months from the respective balance sheet dates. As such, borrowings outstanding are classified as “Long-term debt” on the Consolidated Balance Sheets. In October 2021 and 2020, the Company repaid $70 and $30, respectively, of such borrowings and classified these repayments as “Current maturities of long-term debt” on the Consolidated Balance Sheet. 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: 2021 2020 2019 Trade receivables transferred to ESFC during the year $ 1,353 $ 1,046 $ 1,373 ESFC trade receivables sold to the bank during the year $ 308 $ 182 $ 179 ESFC trade receivables - end of year (a) $ 61 $ 50 $ 55 (a) At September 30, 2021 there were no ESFC trade receivables sold to the bank. At September 30, 2020, the amounts of ESFC trade receivables sold to the bank was $19, and is reflected as “Short-term borrowings” on the Consolidated Balance Sheets.
Schedule of Long-term Debt Instruments	Long-term debt comprises the following at September 30: 2021 2020 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 5 Unamortized debt issuance costs (16) (20) Total AmeriGas Propane 2,560 2,560 UGI International: 3.25% Senior Notes due November 2025 405 410 UGI International, LLC variable-rate term loan due October 2023 (a) 347 352 Other 23 23 Unamortized debt issuance costs (5) (7) Total UGI International 770 778 Midstream & Marketing: Energy Services variable-rate term loan due through August 2026 (b) 684 691 Other 42 41 Unamortized discount and debt issuance costs (10) (12) Total Energy Services 716 720 UGI Utilities: Senior Notes: 4.12%, due September 2046 200 200 4.98%, due March 2044 175 175 3.12% due April 2050 150 150 4.55%, due February 2049 150 150 4.12%, due October 2046 100 100 6.21%, due September 2036 100 100 2.95%, due June 2026 100 100 1.59% due June 2026 100 — 1.64% due September 2026 75 — Medium-Term Notes: 6.13%, due October 2034 20 20 6.50%, due August 2033 20 20 Mountaineer senior notes (c) 164 — Variable-rate term loan due through October 2022 (d) 102 108 Other 1 3 Unamortized debt issuance costs (6) (5) Total UGI Utilities 1,451 1,121 UGI Corporation: UGI Corporation revolving credit facility maturing August 2024 (e) 185 300 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 — Unamortized debt issuance costs (5) (3) Total UGI Corporation 945 847 Other 7 8 Total long-term debt 6,449 6,034 Less: current maturities (110) (53) Total long-term debt due after one year $ 6,339 $ 5,981 (a) At September 30, 2021 and 2020, the effective interest rates on the term loan were 1.89% and 2.04%, respectively. 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, 2021 and 2020, the effective interest rates on the term loan were 5.23% and 5.30%, 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) As a result of the Mountaineer Acquisition, total long-term debt at September 30, 2021, includes $140 of Mountaineer senior secured notes (including unamortized premium of $24). The face interest rates on the Mountaineer senior notes range from 3.50% to 4.41%, with maturities ranging from 2027 to 2034. (d) The effective interest rate on this term loan was 4.00% at both September 30, 2021 and 2020. 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, 2021 and 2020, the effective interest rates on credit facility borrowings were 3.27% and 2.41%, 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, 2021 and 2020, the effective interest rate on this term loan 3.26% and 3.51%, 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, 2021 and 2020, the effective interest rates on this term loan were 3.56% and 3.50%, 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: 2022 2023 2024 2025 2026 AmeriGas Propane $ 1 $ — $ 675 $ 700 $ 675 UGI International 21 2 347 — 405 Midstream & Marketing 10 7 7 7 656 UGI Utilities 7 96 — — 275 UGI Corporation (a) 70 38 327 515 — Other 1 6 — — — Total $ 110 $ 149 $ 1,356 $ 1,222 $ 2,011 (a) In October 2021, the Company repaid $70 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 2021 Consolidated Balance Sheet.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Sep. 30, 2021
Income Tax Disclosure [Abstract]
Income Before Income Taxes	Income before income taxes comprises the following: 2021 2020 2019 Domestic $ 647 $ 424 $ 330 Foreign 1,342 243 71 Total income before income taxes $ 1,989 $ 667 $ 401
Provisions for Income Taxes	The provisions for income taxes consist of the following: 2021 2020 2019 Current expense (benefit): Federal $ (48) $ (85) $ 52 State 7 4 14 Foreign 85 70 70 Total current (benefit) expense 44 (11) 136 Deferred expense (benefit): Federal 168 135 3 State 48 19 4 Foreign 262 (8) (50) Total deferred expense (benefit) 478 146 (43) Total income tax expense $ 522 $ 135 $ 93
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: 2021 2020 2019 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % Difference in tax rate due to: Effect of U.S. tax legislation (0.8) (4.7) 0.2 Effect of tax rate changes - International (1.3) 0.3 (0.5) Noncontrolling interests not subject to tax — — (2.7) State income taxes, net of federal benefit 1.9 2.8 3.6 Valuation allowance adjustments 1.0 — — Effects of foreign operations 4.6 1.3 1.8 Excess tax benefits on share-based payments (0.1) (0.2) (1.0) Other, net (0.1) (0.3) 0.7 Effective tax rate 26.2 % 20.2 % 23.1 %
Deferred Tax Liabilities (Assets)	Deferred tax liabilities (assets) comprise the following at September 30: 2021 2020 Excess book basis over tax basis of property, plant and equipment $ 937 $ 830 Utility regulatory assets 105 112 Intangible assets and goodwill 77 107 Derivative instrument assets 322 — Other 36 32 Gross deferred tax liabilities 1,477 1,081 Investment in AmeriGas Partners (102) (216) Pension plan liabilities (29) (48) Employee-related benefits (45) (46) Operating loss carryforwards (53) (34) Foreign tax credit carryforwards (79) (81) Utility regulatory liabilities (102) (94) Derivative instrument liabilities — (26) Utility environmental liabilities (16) (16) Other (107) (54) Gross deferred tax assets (533) (615) Deferred tax assets valuation allowance 138 105 Net deferred tax liabilities $ 1,082 $ 571

Employee Retirement Plans (Tabl

Employee Retirement Plans (Tables)	12 Months Ended
	Sep. 30, 2021
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, 2021 and 2020. 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 2021 2020 Change in benefit obligations: Benefit obligations — beginning of year $ 782 $ 750 Service cost 12 11 Interest cost 22 23 Actuarial (gain) loss (30) 27 Plan amendments 2 — Acquisitions 114 — Curtailments — (2) Foreign currency (gain) loss (1) 3 Benefits paid (31) (30) Benefit obligations — end of year (a) $ 870 $ 782 Change in plan assets: Pension Benefits 2021 2020 Fair value of plan assets — beginning of year $ 585 $ 547 Actual gain on plan assets 75 53 Foreign currency — 1 Employer contributions 14 13 Acquisitions 92 — Benefits paid (30) (29) Fair value of plan assets — end of year $ 736 $ 585 Funded status of the plans — end of year (b) $ (134) $ (197) Amounts recorded in UGI Corporation stockholders’ equity (pre-tax): Prior service cost $ 3 $ 1 Net actuarial loss 13 24 Total $ 16 $ 25 Amounts recorded in regulatory assets and liabilities (pre-tax): Net actuarial loss 108 174 Total $ 108 $ 174 (a) The ABO for the U.S. Pension Plans was $756 and $687 as of September 30, 2021 and 2020, respectively. (b) Amounts are reflected in “Other noncurrent liabilities” on the Consolidated Balance Sheets.
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 2021 2020 2019 Weighted-average assumptions: Discount rate – benefit obligations 3.13 % 2.90 % 3.30 % Discount rate – benefit cost 2.90 % 3.30 % 4.40 % Expected return on plan assets 7.10 % 7.20 % 7.30 % 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 2021 2020 2019 Service cost $ 12 $ 11 $ 10 Interest cost 22 23 27 Expected return on assets (40) (38) (36) Curtailment gain — (1) — Amortization of: Prior service cost — 1 — Actuarial loss 14 15 8 Net cost $ 8 $ 11 $ 9
Expected Payments for Pension Benefits and Other Postretirement Welfare Benefits	Expected payments for pension benefits are as follows: Pension Fiscal 2022 $ 36 Fiscal 2023 $ 36 Fiscal 2024 $ 41 Fiscal 2025 $ 41 Fiscal 2026 $ 43 Fiscal 2027 - 2031 $ 230
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) 2021 2020 2021 2020 Equity investments: U.S. equities 22.2 % 26.5 % 25.3 % 29.0 % Non-U.S. equities 21.7 % 25.0 % 21.4 % 24.5 % Global equities (a) 16.0 % 12.3 % 13.1 % 11.5 % Total 59.9 % 63.8 % 59.8 % 65.0 % Fixed income funds & cash equivalents 36.4 % 36.2 % 34.4 % 35.0 % Alternative investments 3.7 % — % 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, 2021 and 2020 are as follows: 2021 2020 U.S. Pension Plans: Domestic equity investments: UGI Corporation Common Stock $ 35 $ 27 Total domestic equity investments (a) 35 27 Common collective trust funds: U.S. equity index investments 124 123 Non-U.S. equity index investments 155 141 Global equity index investments 115 70 Bond index investments 254 200 Cash equivalents 7 5 Total common collective trust funds (b) 655 539 Alternative investments (b) 27 — Total $ 717 $ 566 (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, 2021
Regulated Operations [Abstract]
Schedule of Regulatory Assets	The following regulatory assets and liabilities associated with our UGI Utilities reportable segment are included in our Consolidated Balance Sheets at September 30: 2021 2020 Regulatory assets (a): Income taxes recoverable $ 143 $ 124 Underfunded pension and postretirement plans 108 175 Environmental costs 58 61 Deferred fuel and power costs 11 — Removal costs, net 24 26 Other 53 11 Total regulatory assets $ 397 $ 397 Regulatory liabilities (a): Postretirement benefit overcollections $ 13 $ 13 Deferred fuel and power refunds 36 29 State income tax benefits — distribution system repairs 32 28 PAPUC Temporary Rates Order — 7 Excess federal deferred income taxes 287 274 Other 20 2 Total regulatory liabilities $ 388 $ 353 (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 UGI Utilities reportable segment are included in our Consolidated Balance Sheets at September 30: 2021 2020 Regulatory assets (a): Income taxes recoverable $ 143 $ 124 Underfunded pension and postretirement plans 108 175 Environmental costs 58 61 Deferred fuel and power costs 11 — Removal costs, net 24 26 Other 53 11 Total regulatory assets $ 397 $ 397 Regulatory liabilities (a): Postretirement benefit overcollections $ 13 $ 13 Deferred fuel and power refunds 36 29 State income tax benefits — distribution system repairs 32 28 PAPUC Temporary Rates Order — 7 Excess federal deferred income taxes 287 274 Other 20 2 Total regulatory liabilities $ 388 $ 353 (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, 2021
Inventory Disclosure [Abstract]
Components of Inventories	Inventories comprise the following at September 30: 2021 2020 Non-utility LPG and natural gas $ 278 $ 164 Utility natural gas 68 20 Energy certificates 53 3 Materials, supplies and other 70 54 Total inventories $ 469 $ 241

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Sep. 30, 2021
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment comprise the following at September 30: 2021 2020 Estimated Useful Life Utility: Distribution $ 4,306 $ 3,630 Transmission 111 111 General and other 507 425 Work in process 98 99 Total Utility 5,022 4,265 Non-utility: Land 186 191 Buildings and improvements 436 431 10 - 40 years Transportation equipment 232 248 3 - 10 years Equipment, primarily cylinders and tanks 3,785 3,712 5 - 30 years Electric generation 211 211 25 - 40 years Pipeline and related assets 1,218 1,098 25 - 40 years Other 342 306 1 - 12 years Work in process 76 196 Total non-utility 6,486 6,393 Total property, plant and equipment $ 11,508 $ 10,658
Average Composite Depreciation Rates	The average composite depreciation rates at our regulated natural gas utilities (inclusive of Gas Utility and Mountaineer) and Electric Utility were as follows: 2021 2020 2019 Regulated natural gas utilities 2.6 % 2.5 % 2.2 % Electric Utility 2.3 % 2.2 % 2.1 %

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Sep. 30, 2021
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 UGI Utilities Total Balance September 30, 2019 $ 2,004 $ 930 $ 340 $ 182 $ 3,456 Dispositions — — (5) — (5) Purchase accounting adjustments — (2) — — (2) Foreign currency translation — 69 — — 69 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
Schedule of Finite-Lived Intangible Assets	Intangible assets comprise the following at September 30: 2021 2020 Customer relationships $ 1,054 $ 1,083 Trademarks and tradenames 12 12 Noncompete agreements and other 75 76 Accumulated amortization (607) (543) Intangible assets, net (definite-lived) 534 628 Trademarks and tradenames (indefinite-lived) 49 49 Total intangible assets, net $ 583 $ 677
Schedule of Indefinite-Lived Intangible Assets	Intangible assets comprise the following at September 30: 2021 2020 Customer relationships $ 1,054 $ 1,083 Trademarks and tradenames 12 12 Noncompete agreements and other 75 76 Accumulated amortization (607) (543) Intangible assets, net (definite-lived) 534 628 Trademarks and tradenames (indefinite-lived) 49 49 Total intangible assets, net $ 583 $ 677

Equity (Tables)

Equity (Tables)	12 Months Ended
	Sep. 30, 2021
Equity [Abstract]
Common Stock Share Activity	UGI Preferred Stock and Common Stock share activity for Fiscal 2021, Fiscal 2020 and Fiscal 2019 is as follows: Preferred Stock Common Stock Issued/Outstanding Issued Treasury Outstanding Balance at September 30, 2018 — 174,142,997 (394,022) 173,748,975 Issued: Employee and director plans — 548,285 430,847 979,132 AmeriGas Merger — 34,612,847 — 34,612,847 Sale of reacquired common stock — — 15,759 15,759 Repurchases of common stock — — (300,000) (300,000) Reacquired common stock – employee and director plans — — (51,924) (51,924) 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 Balance at September 30, 2020 — 209,514,044 (1,159,606) 208,354,438 Issued: Equity Unit offering 220,000 — — — Employee and director plans — 329,252 554,315 883,567 Reacquired common stock – employee and director plans — — (21,870) (21,870) Balance at September 30, 2021 220,000 209,843,296 (627,161) 209,216,135

Leases (Tables)

Leases (Tables)	12 Months Ended
	Sep. 30, 2021
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: 2021 2020 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 390 $ 415 Other assets Finance lease ROU assets 49 52 Property, plant and equipment Total ROU assets $ 439 $ 467 Lease liabilities: Operating lease liabilities — current $ 81 $ 87 Other current liabilities Operating lease liabilities — noncurrent 318 334 Other noncurrent liabilities Finance lease liabilities — current 4 5 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 41 Long-term debt Total lease liabilities $ 444 $ 467
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 2021 and Fiscal 2020 are as follows: 2021 2020 Operating lease cost $ 101 $ 102 Finance lease cost: Amortization of ROU assets 4 5 Interest on lease liabilities 3 3 Variable lease cost 4 5 Short-term lease cost 2 3 Total lease cost $ 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 2021 and Fiscal 2020: 2021 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 99 $ 103 Operating cash flows — finance leases $ 3 $ 3 Financing cash flows — finance leases $ 3 $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (a) $ 85 $ 506 ROU assets obtained in exchange for finance lease liabilities $ 1 $ 22 (a) Fiscal 2020 includes the impact of the adoption of ASC842. The following table presents the weighted-average remaining lease term and weighted-average discount rate: Weighted-average remaining lease term (in years) 2021 2020 Operating leases 6.3 6.2 Finance leases 2.4 2.4 Weighted-average discount rate (%) 2021 2020 Operating leases 3.6% 3.8% Finance leases 1.5% 1.9%
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, 2021, were as follows: 2022 2023 2024 2025 2026 After 2026 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 92 $ 81 $ 71 $ 55 $ 44 $ 103 $ 446 $ (47) $ 399 Finance leases $ 4 $ 4 $ 3 $ 3 $ 3 $ 81 $ 98 $ (53) $ 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, 2021, were as follows: 2022 2023 2024 2025 2026 After 2026 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 92 $ 81 $ 71 $ 55 $ 44 $ 103 $ 446 $ (47) $ 399 Finance leases $ 4 $ 4 $ 3 $ 3 $ 3 $ 81 $ 98 $ (53) $ 45

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Sep. 30, 2021
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, 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 September 30, 2020 Derivative instruments: Assets: Commodity contracts $ 68 $ 39 $ — $ 107 Foreign currency contracts $ — $ 32 $ — $ 32 Liabilities: Commodity contracts $ (54) $ (64) $ — $ (118) Foreign currency contracts $ — $ (14) $ — $ (14) Interest rate contracts $ — $ (55) $ — $ (55) Non-qualified supplemental postretirement grantor trust investments (a) $ 42 $ — $ — $ 42 (a) Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans (see Note 8).
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: 2021 2020 Carrying amount $ 6,491 $ 6,081 Estimated fair value $ 6,996 $ 6,504

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Sep. 30, 2021
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, 2021 and 2020 and the final settlement dates of the Company's open derivative contracts as of September 30, 2021, excluding those derivatives that qualified for the NPNS exception: Notional Amounts September 30, Type Units Settlements Extending Through 2021 2020 Commodity Price Risk: Regulated Utility Operations Gas Utility NYMEX natural gas futures and option contracts Dekatherms September 2022 20 22 Non-utility Operations LPG swaps Gallons November 2023 708 846 Natural gas futures, forward, basis swap, options and pipeline contracts Dekatherms April 2026 355 339 Electricity forward and futures contracts Kilowatt hours January 2026 4,302 4,705 Interest Rate Risk: Interest rate swaps Euro October 2022 € 300 € 300 Interest rate swaps USD September 2024 $ 1,421 $ 1,344 Foreign Currency Exchange Rate Risk: Forward foreign exchange contracts USD September 2024 $ 509 $ 511 Net investment hedge forward foreign exchange contracts Euro October 2024 € 173 € 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: 2021 2020 Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 20 $ 17 Derivatives subject to PGC and DS mechanisms: Commodity contracts 58 7 Derivatives not designated as hedging instruments: Commodity contracts 1,591 100 Foreign currency contracts 18 15 1,609 115 Total derivative assets – gross 1,687 139 Gross amounts offset in the balance sheet (216) (57) Cash collateral received (468) — Total derivative assets – net $ 1,003 $ 82 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts $ (29) $ (55) Derivatives subject to PGC and DS mechanisms: Commodity contracts (23) — Derivatives not designated as hedging instruments: Commodity contracts (257) (118) Foreign currency contracts (8) (14) (265) (132) Total derivative liabilities – gross (317) (187) Gross amounts offset in the balance sheet 216 57 Cash collateral pledged 3 7 Total derivative liabilities – net $ (98) $ (123)
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 2021, Fiscal 2020 and Fiscal 2019: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from 2021 2020 2019 2021 2020 2019 Cash Flow Hedges: Foreign currency contracts $ — $ — $ 1 $ — $ — $ 2 Cost of sales Interest rate contracts 4 (53) (11) (25) (13) (6) Interest expense Total $ 4 $ (53) $ (10) $ (25) $ (13) $ (4) Net Investment Hedges: Foreign currency contracts $ 4 $ (1) $ 17 Gain (Loss) Location of 2021 2020 2019 Derivatives Not Designated as Hedging Instruments: Commodity contracts $ (17) $ 10 $ 7 Revenues Commodity contracts 1,545 (32) (344) Cost of sales Commodity contracts 5 — — Other operating income, net Foreign currency contracts 9 (20) 38 Other non-operating income (expense), net Total $ 1,542 $ (42) $ (299)

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Sep. 30, 2021
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	The table below presents changes in AOCI, net of tax, during Fiscal 2021, Fiscal 2020 and Fiscal 2019: Postretirement Derivative Foreign Total AOCI - September 30, 2018 $ (11) $ (16) $ (83) $ (110) Other comprehensive loss before reclassification adjustments (after-tax) (13) (7) (83) (103) Amounts reclassified from AOCI 1 2 — 3 Other comprehensive loss attributable to UGI (12) (5) (83) (100) Reclassification of stranded income tax effects related to TCJA (3) (4) — (7) AOCI - September 30, 2019 $ (26) $ (25) $ (166) $ (217) Other comprehensive (loss) income before reclassification adjustments (after-tax) (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 (after-tax) 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 Operating Income, Net a_2

Other Operating Income, Net and Other Non-Operating Income (Expense), Net (Tables)	12 Months Ended
	Sep. 30, 2021
Component of Operating Income [Abstract]
Other Operating Income, Net	Other operating income, net, comprises the following: 2021 2020 2019 Finance charges $ 17 $ 9 $ 17 Gains on sales of fixed assets, net 11 5 3 Gain on early derivative termination 5 — — Interest and interest-related income — 2 6 Utility non-tariff service income — — 1 Other, net — 5 4 Total other operating income, net $ 33 $ 21 $ 31
Schedule of Other Non-Operating Income (Expense), Net	Other non-operating income (expense), net comprises the following: 2021 2020 2019 Gains (losses) on foreign currency contracts, net $ 9 $ (20) $ 38 Amortization of excluded components of certain net investment hedges 2 — — Pension and other postretirement plans non-service income, net 1 — 1 Total other non-operating income (expense), net $ 12 $ (20) $ 39

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Sep. 30, 2021
Segment Reporting [Abstract]
Schedule of Segment Reporting Information	Total Elim- AmeriGas UGI International Midstream UGI Utilities Corporate & 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 (c) $ 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 Total Elim- AmeriGas UGI International Midstream UGI Utilities Corporate & 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 $ — $ — 2019 Revenues from external customers $ 7,320 $ — $ 2,682 $ 2,372 $ 1,281 $ 981 $ 4 Intersegment revenues $ — $ (306) (b) $ — $ — $ 235 $ 68 $ 3 Cost of sales $ 4,323 $ (301) (b) $ 1,191 $ 1,416 $ 1,241 $ 481 $ 295 Operating income (loss) $ 617 $ — $ 404 $ 229 $ 105 $ 224 $ (345) Income from equity investees 9 — — — 9 — — Loss on extinguishments of debt (6) — — — — — (6) Other non-operating income (expense), net 39 (1) — 5 — 2 33 Earnings (loss) before interest expense and income taxes 659 (1) 404 234 114 226 (318) Interest expense (258) — (167) (25) (9) (50) (7) Income tax (expense) benefit (93) — (26) (64) (27) (43) 67 Noncontrolling interests’ net (income) loss (52) — (143) — — — 91 Net income (loss) attributable to UGI $ 256 $ (1) $ 68 $ 145 $ 78 $ 133 $ (167) Depreciation and amortization $ 448 $ — $ 179 $ 124 $ 51 $ 93 $ 1 Total assets $ 13,347 $ (353) $ 4,095 $ 2,975 $ 2,745 $ 3,560 $ 325 Short-term borrowings $ 796 $ — $ 328 $ 211 $ 91 $ 166 $ — Capital expenditures (including the effects of accruals) $ 707 $ — $ 107 $ 106 $ 138 $ 355 $ 1 Investments in equity investees $ 190 $ — $ — $ 12 $ 178 $ — $ — (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 2021, Fiscal 2020 and Fiscal 2019: Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing 2021 Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (15) Net gains on commodity derivative instruments not associated with current-period transactions Cost of Sales $ 167 $ 1,065 $ 173 Unrealized gains on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 8 $ — Business transformation expenses Operating and administrative expenses $ (54) $ (33) $ — Impairment of customer relationship intangible Operating and administrative expenses $ — $ (20) $ — Impairment of investment in PennEast (Loss) income from equity method 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 (expense) income, 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) 2019 Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ 4 Net losses on commodity derivative instruments not associated with current-period transactions Cost of Sales $ (117) $ (143) $ (35) Unrealized gains on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 32 $ — Loss on extinguishments of debt Loss on extinguishment of debt $ — $ (6) $ — AmeriGas Merger expenses Operating and administrative expenses $ (6) $ — $ — Acquisition and integration expenses associated with the CMG Acquisition Operating and administrative expenses $ — $ — $ (16) Business transformation expenses Operating and administrative expenses $ (15) $ (9) $ — (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane. (c) Beginning October 1, 2019, UGI International is allocated a portion of indirect corporate expenses. Prior to October 1, 2019, these expenses were billed to its parent company, which is included in Corporate & Other.

SCHEDULE I _ CONDENSED FINANC_2

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) (Tables)	12 Months Ended
	Sep. 30, 2021
Condensed Financial Information Disclosure [Abstract]
Balance Sheets	BALANCE SHEETS (Millions of dollars) September 30, 2021 2020 ASSETS Current assets: Cash and cash equivalents $ 14 $ 67 Accounts receivable – related parties 18 11 Prepaid expenses and other current assets 11 15 Total current assets 43 93 Property, plant and equipment, net 2 2 Investments in subsidiaries 6,479 4,898 Other assets 107 87 Total assets $ 6,631 $ 5,080 LIABILITIES AND COMMON STOCKHOLDERS’ EQUITY Current liabilities: Current maturities of long-term debt $ 70 $ 30 Accounts and notes payable 24 15 Accrued liabilities 62 29 Total current liabilities 156 74 Long-term debt 875 817 Other noncurrent liabilities 78 61 Total liabilities 1,109 952 Commitments and contingencies (Note 1) Equity: Preferred Stock, without par value (authorized - 5,000,000; issued - 220,000 and 0, respectively) 213 — Common Stock, without par value (authorized – 450,000,000 shares; issued – 209,843,296 and 209,514,044 shares, respectively) 1,394 1,416 Retained earnings 4,081 2,908 Accumulated other comprehensive loss (140) (147) Treasury stock, at cost (26) (49) Total common stockholders’ equity 5,522 4,128 Total liabilities and common stockholders’ equity $ 6,631 $ 5,080
Statements of Income	STATEMENTS OF INCOME (Millions of dollars, except per share amounts) Year Ended September 30, 2021 2020 2019 Revenues $ — $ — $ — Costs and expenses: Operating and administrative expenses 94 56 50 Other operating income, net (a) (65) (54) (50) 29 2 — Operating loss (29) (2) — Pension and other postretirement plans non-service expense — — (1) Interest expense (27) (32) (6) Loss before income taxes (56) (34) (7) Income tax expense (benefit) 9 17 (3) Loss before equity in income of unconsolidated subsidiaries (65) (51) (4) Equity in income of unconsolidated subsidiaries 1,532 583 260 Net income attributable to UGI Corporation $ 1,467 $ 532 $ 256 Other comprehensive income (loss) 7 (12) (3) Equity in other comprehensive income (loss) of unconsolidated subsidiaries — 82 (97) Comprehensive income attributable to UGI Corporation $ 1,474 $ 602 $ 156 Earnings per common share attributable to UGI Corporation stockholders: Basic $ 7.02 $ 2.55 $ 1.44 Diluted $ 6.92 $ 2.54 $ 1.41 Weighted - average common shares outstanding (thousands): Basic 209,063 208,928 178,417 Diluted 212,126 209,869 181,111
Statements of Cash Flows	STATEMENTS OF CASH FLOWS (Millions of dollars) Year Ended September 30, 2021 2020 2019 NET CASH PROVIDED BY OPERATING ACTIVITIES (a) $ 300 $ 322 $ 170 CASH FLOWS FROM INVESTING ACTIVITIES: Net investments in unconsolidated subsidiaries (401) — (768) Net cash used by investing activities (401) — (768) CASH FLOWS FROM FINANCING ACTIVITIES: Payment of dividends on Common Stock (282) (273) (200) Issuances of debt, net of issuance costs 483 60 846 Repayments of long-term debt (385) (60) — Issuance of preferred stock 213 — — Issuances of Common Stock 19 2 17 Repurchases of UGI Common Stock — (38) (17) Other — — (7) Net cash provided (used) by financing activities 48 (309) 639 Cash and cash equivalents (decrease) increase $ (53) $ 13 $ 41 Cash and cash equivalents: End of year $ 14 $ 67 $ 54 Beginning of year 67 54 13 Cash and cash equivalents (decrease) increase $ (53) $ 13 $ 41 (a) Includes dividends received from unconsolidated subsidiaries of $354, $352 and $163 for the years ended September 30, 2021, 2020 and 2019, respectively.

Nature of Operations (Details)

Nature of Operations (Details) customer in Thousands, $ in Millions	Sep. 01, 2021USD ($)countycustomer	Aug. 21, 2019USD ($)shares	Aug. 20, 2019	Sep. 30, 2019shares
AmeriGas Propane | AmeriGas Partners
Investment [Line Items]
General Partner held a general partner interest in AmeriGas Partners (as a percentage)			1.00%
Percentage of limited partnership interest in AmeriGas Partners (as a percentage)			25.50%
Merger Sub
Investment [Line Items]
Total cash paid		$ 529
Enterprise value		$ 2,228
Merger Sub | AmeriGas Propane | AmeriGas OLP
Investment [Line Items]
Effective ownership interest in AmeriGas OLP (as a percentage)			27.00%
Merger Sub | Common Stock
Investment [Line Items]
Consideration paid (in shares) | shares		34,612,847		34,613,000
Mountaineer
Investment [Line Items]
Enterprise value	$ 540
Assumption of debt	$ 140
Customers served | customer	214
Number of counties of operation | county	50

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Revenue Recognition (Details)	12 Months Ended
	Sep. 30, 2021
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	Aug. 21, 2019	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Weighted-average common shares outstanding for basic computation (in shares)		209,063,000	208,928,000	178,417,000
Incremental shares issuable for stock options, common stock awards and Equity Units (in shares)		3,063,000	941,000	2,694,000
Weighted-average common shares outstanding for diluted computation (in shares)		212,126,000	209,869,000	181,111,000
Antidilutive securities excluded from computation of earnings per share (in shares)		5,267,000	7,056,000	1,162,000
Common Stock | Merger Sub
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Consideration paid (in shares)	34,612,847			34,613,000

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	Sep. 30, 2021	May 25, 2021	Sep. 30, 2020
Class of Stock [Line Items]
Shares issued on conversion settlement (in shares)		1
Carrying value	$ 7,558		$ 6,960
Midstream & Marketing | Certain natural gas gathering systems
Class of Stock [Line Items]
Carrying value	$ 100
Capital Units | Preferred Stock
Class of Stock [Line Items]
Notional value		$ 220
Liquidation preference (in USD per share)		$ 1,000
Convertible Preferred Stock
Class of Stock [Line Items]
Liquidation preference (in USD per share)		$ 1,000

Summary of Significant Accoun_7

Summary of Significant Accounting Policies - Reconciliation of the total cash, cash equivalents and restricted cash (Details) - USD ($) $ in Millions	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Accounting Policies [Abstract]
Cash and cash equivalents	$ 855	$ 336	$ 447
Restricted cash	22	21	64
Cash, cash equivalents and restricted cash	$ 877	$ 357	$ 511	$ 462

Summary of Significant Accoun_8

Summary of Significant Accounting Policies- Property, Plant and Equipment and Related Depreciation (Details)	12 Months Ended
	Sep. 30, 2021
UGI Utilities
Public Utility, Property, Plant and Equipment [Line Items]
Amortization period	5 years

Summary of Significant Accoun_9

Summary of Significant Accounting Policies - Goodwill and Intangible Assets (Details) - USD ($)	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Finite-Lived Intangible Assets [Line Items]
Accumulated impairment losses	$ 0	$ 0
Provision for goodwill or other intangible asset impairments	$ 0	$ 0	$ 0
Customer relationships, noncompete agreements, and other
Finite-Lived Intangible Assets [Line Items]
Useful life	15 years
CMG | Customer Relationships
Finite-Lived Intangible Assets [Line Items]
Useful life	35 years

Summary of Significant Accou_10

Summary of Significant Accounting Policies - Impairment of Long-Lived Assets and Cost Basis Investments (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2019
Accounting Policies [Abstract]
Impairment charges	$ 20	$ 0

Summary of Significant Accou_11

Summary of Significant Accounting Policies - Refundable Tank and Cylinder Deposits (Details) - USD ($) $ in Millions	Sep. 30, 2021	Sep. 30, 2020
Accounting Policies [Abstract]
Customer paid deposits primarily on owned tanks and cylinders	$ 296	$ 300

Revenue from Contracts with C_3

Revenue from Contracts with Customers - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Disaggregation of Revenue [Line Items]
Contract liabilities	$ 149	$ 161
Contract liabilities, recognized revenue	$ 138	$ 122	$ 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]
Revenue, remaining performance obligation	$ 2,000
UGI Utilities
Disaggregation of Revenue [Line Items]
Revenue, remaining performance obligation	$ 200

Revenue from Contracts with C_4

Revenue from Contracts with Customers - Schedule of Disaggregation of Revenue By Reportable Segment (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 7,348	$ 6,452	$ 7,211
Other revenues	99	107	109
Total revenues	7,447	6,559	7,320
Negative surcharge			6
Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	568	563	553
Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	218	215	226
Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	148	142	138
Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	51	48	46
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	21	14	15
Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,006	982	978
Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	3,957	3,499	4,008
Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	328	211	233
Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,564	1,233	1,521
Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	181	168	95
Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	16	6	17
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	8	7	2
Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	13	34	43
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	275	312	314
Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	6,342	5,470	6,233
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(288)	(229)	(302)
Other revenues	(3)	(3)	(4)
Total revenues	(291)	(232)	(306)
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	(62)	(45)	(65)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(2)	(2)	(3)
Eliminations | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(64)	(47)	(68)
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	(126)	(79)	(134)
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	(98)	(100)	(97)
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	(3)	(3)
Eliminations | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(224)	(182)	(234)
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	224	182	235
Eliminations | UGI Utilities
Disaggregation of Revenue [Line Items]
Total revenues	64	47	68
Operating Segments | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,548	2,315	2,618
Other revenues	66	66	64
Total revenues	2,614	2,381	2,682
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	2,203	2,037	2,341
Operating Segments | AmeriGas Propane | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	139	63	64
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	206	215	213
Operating Segments | AmeriGas Propane | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,548	2,315	2,618
Operating Segments | UGI International
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,617	2,104	2,339
Other revenues	34	23	33
Total revenues	2,651	2,127	2,372
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	1,754	1,462	1,667
Operating Segments | UGI International | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	189	148	169
Operating Segments | UGI International | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	605	434	448
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	69	60	55
Operating Segments | UGI International | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,617	2,104	2,339
Operating Segments | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,401	1,233	1,510
Other revenues	5	14	6
Total revenues	1,406	1,247	1,516
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	1,085	878	1,207
Operating Segments | Midstream & Marketing | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	181	168	95
Operating Segments | Midstream & Marketing | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	114	106	114
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	8	7	2
Operating Segments | Midstream & Marketing | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	13	34	43
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	40	49
Operating Segments | Midstream & Marketing | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,401	1,233	1,510
Operating Segments | UGI Utilities
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,070	1,029	1,046
Other revenues	9	1	3
Total revenues	1,079	1,030	1,049
Operating Segments | UGI Utilities | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	568	563	553
Operating Segments | UGI Utilities | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	218	215	226
Operating Segments | UGI Utilities | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	148	142	138
Operating Segments | UGI Utilities | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	113	93	111
Operating Segments | UGI Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	23	16	18
Operating Segments | UGI Utilities | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,070	1,029	1,046
Operating Segments | UGI Utilities | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Operating Segments | UGI Utilities | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Operating Segments | UGI Utilities | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Operating Segments | UGI Utilities | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Operating Segments | UGI Utilities | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Operating Segments | UGI Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Operating Segments | UGI Utilities | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Operating Segments | UGI Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0
Operating Segments | UGI 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	(12)	6	7
Total revenues	(12)	6	7
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

AmeriGas Merger, Acquisitions_3

AmeriGas Merger, Acquisitions and Dispositions - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	Sep. 01, 2021	Aug. 21, 2019	Aug. 01, 2019	Sep. 30, 2020	Jun. 30, 2020	Sep. 30, 2019	Sep. 30, 2021	Jul. 31, 2020
Statement [Line Items]
Impairment of assets held-for-sale					$ 52
Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations | HVAC Business
Statement [Line Items]
Loss on sale of business				$ 2
Jointly Owned Electricity Generation Plant
Statement [Line Items]
Proportionate ownership share, percent (as a percentage)								5.97%
Mountaineer
Statement [Line Items]
Total purchase price	$ 540
Liabilities incurred	$ 140
Transaction costs							$ 13
Merger Sub
Statement [Line Items]
Total purchase price		$ 2,228
Transaction costs		8
Total cash paid		529
Operating expenses		$ 6
Deferred tax asset, step up in tax basis of the underlying assets						$ 512
Merger Sub | Common Stock
Statement [Line Items]
Consideration paid (in shares)		34,612,847				34,613,000
Merger Sub | Merger Agreement, Proposed Consideration One | Common Stock
Statement [Line Items]
Business combination, consideration transferred, equity interests issuable per acquiree share (in shares)		0.6378
Merger Sub | Merger Agreement, Proposed Consideration Two | Common Stock
Statement [Line Items]
Business combination, consideration transferred, equity interests issuable per acquiree share (in shares)		0.500
Merger Sub | Merger Agreement, Proposed Consideration Two | Cash Without Interest
Statement [Line Items]
Business combination, consideration transferred, equity interests issuable per share (in dollars per share)		$ 7.63
Merger Sub | Merger Agreement, Proposed Consideration Three | Cash Without Interest
Statement [Line Items]
Business combination, consideration transferred, equity interests issuable per share (in dollars per share)		$ 35.325
Pennant | Affiliated Entity | CMG
Statement [Line Items]
Percentage of voting interests acquired (as a percentage)			47.00%
CMG
Statement [Line Items]
Transaction costs						$ 15
Total cash paid			$ 1,284

AmeriGas Merger, Acquisitions_4

AmeriGas Merger, Acquisitions and Dispositions - Components of the Preliminary Mountaineer Purchase Price Allocation (Details) - USD ($) $ in Millions	Sep. 30, 2021	Sep. 01, 2021	Sep. 30, 2020	Sep. 30, 2019
Liabilities assumed:
Goodwill	$ 3,770		$ 3,518	$ 3,456
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		26
Other noncurrent liabilities		29
Total liabilities assumed		379
Goodwill		255
Net consideration transferred (including working capital adjustments)		$ 400

AmeriGas Merger, Acquisitions_5

AmeriGas Merger, Acquisitions and Dispositions - Components of the Final CMG Purchase Price Allocation (Details) - USD ($) $ in Millions	Aug. 01, 2019	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Liabilities assumed:
Goodwill		$ 3,770	$ 3,518	$ 3,456
CMG
Assets acquired:
Accounts receivable	$ 10
Prepaid expenses and other current assets	1
Property, plant and equipment	614
Investment in Pennant	88
Intangible assets	250
Total assets acquired	963
Liabilities assumed:
Accounts payable	3
Total liabilities assumed	3
Goodwill	324
Net consideration transferred (including working capital adjustments)	$ 1,284
CMG | Customer Relationships
Liabilities assumed:
Average intangible amortization period	35 years

AmeriGas Merger, Acquisitions_6

AmeriGas Merger, Acquisitions and Dispositions - Total Cash Paid and Liabilities Incurred (Details) $ in Millions	12 Months Ended
	Sep. 30, 2021USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)mi
Business Acquisition [Line Items]
Natural gas lines, acquired (in miles) | mi			21
Payments to acquire long-term investments			$ 20
UGI International
Business Acquisition [Line Items]
Total cash paid	$ 18		49
Liabilities incurred	0		0
Total purchase price	$ 18		49
Midstream & Marketing
Business Acquisition [Line Items]
Total cash paid		$ 16	15
Liabilities incurred		7	0
Total purchase price		$ 23	$ 15

Debt - Mountaineer (Details)

Debt - Mountaineer (Details) - Mountaineer	Sep. 01, 2021USD ($)extension	Sep. 30, 2021USD ($)
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 100,000,000	$ 100,000,000
Option to increase capacity	$ 200,000,000
Number of extensions | extension	2
Extension period	1 year

Debt - UGI Utilities, Inc. (Det

Debt - UGI Utilities, Inc. (Details) - UGI Utilities, Inc. - Senior Notes - USD ($)	Sep. 30, 2021	May 07, 2021
1.59% due June 2026
Debt Instrument [Line Items]
Aggregate principal amount		$ 100,000,000
Stated interest rate (as a percentage)	1.59%	1.59%
1.64% due September 2026
Debt Instrument [Line Items]
Aggregate principal amount		$ 75,000,000
Stated interest rate (as a percentage)	1.64%	1.64%

Debt - UGI Corporation (Details

Debt - UGI Corporation (Details) - 2021 UGI Corporation Senior Credit Facility - USD ($)	May 04, 2021	May 03, 2021	Jun. 09, 2021	Jun. 08, 2021
Term Loan
Debt Instrument [Line Items]
Debt term (in years)	4 years	3 years
Maximum borrowing capacity		$ 300,000,000	$ 215,000,000	$ 300,000,000
Line of Credit | Prime Rate | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate (as a percentage)	0.125%
Line of Credit | Prime Rate | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate (as a percentage)	1.50%
Line of Credit | LIBOR | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate (as a percentage)	1.125%
Line of Credit | LIBOR | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate (as a percentage)	2.50%

Debt - Schedule of Credit Facil

Debt - Schedule of Credit Facilities and Short-term Borrowings (Details)	Sep. 30, 2021USD ($)	Sep. 30, 2021EUR (€)	Sep. 01, 2021USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2020EUR (€)
AmeriGas OLP
Short-term Debt [Line Items]
Total Capacity	$ 600,000,000			$ 600,000,000
Borrowings Outstanding	170,000,000			186,000,000
Letters of Credit and Guarantees Outstanding	60,000,000			62,000,000
Available Borrowing Capacity	$ 370,000,000			$ 352,000,000
Weighted Average Interest Rate - End of Year	2.58%	2.58%		2.61%	2.61%
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, Inc.
Short-term Debt [Line Items]
Total Capacity	350,000,000			350,000,000
Borrowings Outstanding	130,000,000			141,000,000
Letters of Credit and Guarantees Outstanding	0			0
Available Borrowing Capacity	$ 220,000,000			$ 209,000,000
Weighted Average Interest Rate - End of Year	1.35%	1.35%		1.12%	1.12%
Mountaineer
Short-term Debt [Line Items]
Total Capacity	$ 100,000,000		$ 100,000,000
Borrowings Outstanding	67,000,000
Letters of Credit and Guarantees Outstanding	0
Available Borrowing Capacity	33,000,000
UGI Corporation
Short-term Debt [Line Items]
Total Capacity	300,000,000			$ 300,000,000
Borrowings Outstanding	185,000,000			300,000,000
Letters of Credit and Guarantees Outstanding	0			0
Available Borrowing Capacity	$ 115,000,000			$ 0
Weighted Average Interest Rate - End of Year				2.41%	2.41%

Debt - Schedule of Short-term D

Debt - Schedule of Short-term Debt (Footnotes) (Details) - USD ($)	1 Months Ended
	Oct. 31, 2021	Oct. 31, 2020	Sep. 30, 2021	Sep. 01, 2021	Sep. 30, 2020
Subsequent Event
Short-term Debt [Line Items]
Repayment of debt	$ 70,000,000
AmeriGas OLP
Short-term Debt [Line Items]
Maximum borrowing capacity			$ 600,000,000		$ 600,000,000
Energy Services
Short-term Debt [Line Items]
Maximum borrowing capacity			260,000,000		260,000,000
UGI Utilities, Inc.
Short-term Debt [Line Items]
Maximum borrowing capacity			350,000,000		350,000,000
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
Line of Credit | AmeriGas OLP | Letter of Credit | AmeriGas OLP Credit Agreement
Short-term Debt [Line Items]
Maximum borrowing capacity			150,000,000
Line of Credit | Energy Services | Letter of Credit | Energy Services Credit Agreement
Short-term Debt [Line Items]
Maximum borrowing capacity			50,000,000
Line of Credit | UGI Utilities, Inc. | Letter of Credit | UGI Utilities, Inc. Credit Agreement
Short-term Debt [Line Items]
Maximum borrowing capacity			100,000,000
Line of Credit | Mountaineer | Letter of Credit | Mountaineer Credit Agreement
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		$ 30,000,000
Line of Credit | UGI Corporation | 2021 UGI Corporation Senior Credit Facility | Subsequent Event
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

Debt - Accounts Receivable Secu

Debt - Accounts Receivable Securitization Facility (Details) - USD ($)	6 Months Ended
	Oct. 31, 2019	Apr. 30, 2019
Energy Services | Receivables Facility | Energy Services Receivables Facility
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 ($)	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Short-term Debt [Line Items]
Trade receivables transferred to ESFC during the year	$ 1,353,000,000	$ 1,046,000,000	$ 1,373,000,000
ESFC trade receivables sold to the bank during the year	308,000,000	182,000,000	179,000,000
ESFC trade receivables - end of year	61,000,000	50,000,000	$ 55,000,000
Outstanding balance of trade receivables sold	$ 0	$ 19,000,000

Debt - Schedule of Long-term De

Debt - Schedule of Long-term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2021	May 07, 2021	Sep. 30, 2020
Debt Instrument [Line Items]
Total long-term debt	$ 6,449		$ 6,034
Less: current maturities	(110)		(53)
Total long-term debt due after one year	6,339		5,981
AmeriGas Propane
Debt Instrument [Line Items]
Unamortized debt issuance costs	(16)		(20)
Total long-term debt	2,560		2,560
AmeriGas Propane | Other
Debt Instrument [Line Items]
Long-term debt, gross	$ 1		5
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	(5)		(7)
Total long-term debt	$ 770		778
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	$ 405		410
UGI International | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	347		352
Other
Debt Instrument [Line Items]
Total long-term debt	7		8
Other | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	23		23
Midstream & Marketing
Debt Instrument [Line Items]
Unamortized debt issuance costs	(10)		(12)
Total long-term debt	716		720
Midstream & Marketing | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	42		41
Midstream & Marketing | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	684		691
UGI Utilities
Debt Instrument [Line Items]
Unamortized debt issuance costs	(6)		(5)
Total long-term debt	1,451		1,121
UGI Utilities | Mountaineer senior notes
Debt Instrument [Line Items]
Long-term debt, gross	$ 164		0
UGI 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
UGI 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
UGI 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
UGI 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
UGI 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
UGI 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
UGI 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
UGI Utilities | Senior Notes | 1.59% due June 2026
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	1.59%	1.59%
Long-term debt, gross	$ 100		0
UGI Utilities | Senior Notes | 1.64% due September 2026
Debt Instrument [Line Items]
Stated interest rate (as a percentage)	1.64%	1.64%
Long-term debt, gross	$ 75		0
UGI Utilities | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	1		3
UGI Utilities | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	$ 102		108
UGI 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
UGI 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	(5)		(3)
Total long-term debt	945		847
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		0
UGI Corporation | Line of Credit
Debt Instrument [Line Items]
Long-term debt, gross	$ 185		$ 300

Debt - Schedule of Long-term _2

Debt - Schedule of Long-term Debt (Footnotes) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Debt Instrument [Line Items]
Long-term debt	$ 6,449,000,000	$ 6,034,000,000
Senior Secured Notes | Mountaineer senior notes
Debt Instrument [Line Items]
Long-term debt	140,000,000
Unamortized premium	$ 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)	4.41%
AmeriGas Propane
Debt Instrument [Line Items]
Long-term debt	$ 2,560,000,000	2,560,000,000
UGI International
Debt Instrument [Line Items]
Long-term debt	$ 770,000,000	$ 778,000,000
UGI International | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	1.89%	2.04%
Midstream & Marketing
Debt Instrument [Line Items]
Long-term debt	$ 716,000,000	$ 720,000,000
Midstream & Marketing | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	5.23%	5.30%
Quarterly Installments	$ 2,000,000
UGI Utilities
Debt Instrument [Line Items]
Long-term debt	$ 1,451,000,000	$ 1,121,000,000
Weighted Average Interest Rate - End of Year	1.35%	1.12%
UGI Utilities | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	4.00%	4.00%
Quarterly Installments	$ 2,000,000
UGI Corporation
Debt Instrument [Line Items]
Long-term debt	$ 945,000,000	$ 847,000,000
Weighted Average Interest Rate - End of Year		2.41%
UGI Corporation | Term Loan | 3-year Term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	3.26%	3.51%
UGI Corporation | Term Loan | 5-year Term Loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	3.56%	3.50%
Quarterly Installments	$ 9,000,000
UGI Corporation | Term Loan | 7-Year Term Loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	1.88%
UGI Corporation | Line of Credit
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	3.27%	2.41%
Weighted Average Interest Rate - End of Year	3.27%

Debt - Schedule of Principal Re

Debt - Schedule of Principal Repayments of Long-term Debt (Details) - USD ($) $ in Millions	1 Months Ended
	Oct. 31, 2021	Sep. 30, 2021
Debt Instrument [Line Items]
2022		$ 110
2023		149
2024		1,356
2025		1,222
2026		2,011
Subsequent Event
Debt Instrument [Line Items]
Repayment of debt	$ 70
AmeriGas Propane
Debt Instrument [Line Items]
2022		1
2023		0
2024		675
2025		700
2026		675
Midstream & Marketing
Debt Instrument [Line Items]
2022		10
2023		7
2024		7
2025		7
2026		656
UGI International
Debt Instrument [Line Items]
2022		21
2023		2
2024		347
2025		0
2026		405
UGI Utilities
Debt Instrument [Line Items]
2022		7
2023		96
2024		0
2025		0
2026		275
UGI Corporation
Debt Instrument [Line Items]
2022		70
2023		38
2024		327
2025		515
2026		0
Other
Debt Instrument [Line Items]
2022		1
2023		6
2024		0
2025		0
2026		$ 0

Debt - Restricted Net Assets (D

Debt - Restricted Net Assets (Details) $ in Millions	Sep. 30, 2021USD ($)
Debt Disclosure [Abstract]
Restricted net assets	$ 2,500

Income Taxes - Income Before In

Income Taxes - Income Before Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Income Tax Disclosure [Abstract]
Domestic	$ 647	$ 424	$ 330
Foreign	1,342	243	71
Income before income taxes	$ 1,989	$ 667	$ 401

Income Taxes - Provisions for I

Income Taxes - Provisions for Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Current expense (benefit):
Federal	$ (48)	$ (85)	$ 52
State	7	4	14
Foreign	85	70	70
Total current (benefit) expense	44	(11)	136
Deferred expense (benefit):
Federal	168	135	3
State	48	19	4
Foreign	262	(8)	(50)
Total deferred expense (benefit)	478	146	(43)
Total income tax expense	$ 522	$ 135	$ 93

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($)	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Income Tax Examination [Line Items]
Foreign tax credits	$ 0	$ 0	$ 10,000,000
Foreign tax credit carryforwards	79,000,000	81,000,000
Net operating loss carryback	15,000,000	32,000,000
Income taxes receivable	128,000,000	80,000,000
Tax Cuts And Jobs Act of 2017, transition tax for accumulated foreign earnings, provisional Income tax expense (benefit)	8,000,000	0	2,000,000
Deferred tax assets relating to operating loss carryforwards	53,000,000	34,000,000
Increase (decrease) in valuation allowance	33,000,000	(14,000,000)
Unrecognized tax benefits if recognized would impact the reported effective tax rate	4,000,000	4,000,000	11,000,000
Future capital losses from PennEast and Hudson investments
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance	30,000,000
Future FTC's realizable
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance	(10,000,000)
Notional interest deduction carryover
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance	10,000,000	16,000,000
AmeriGas Propane
Income Tax Examination [Line Items]
Operating loss carryforwards	7,000,000
Other Subsidiaries
Income Tax Examination [Line Items]
Deferred tax assets relating to operating loss carryforwards	52,000,000
Fiscal 2020 carryback to Fiscal 2015
Income Tax Examination [Line Items]
Income taxes receivable		90,000,000
Fiscal 2021 carryback to Fiscal 2016
Income Tax Examination [Line Items]
Income taxes receivable	38,000,000
Foreign | Flaga
Income Tax Examination [Line Items]
Operating loss carryforwards	10,000,000
Foreign | UGI France
Income Tax Examination [Line Items]
Operating loss carryforwards	19,000,000
Foreign | Italy
Income Tax Examination [Line Items]
Foreign tax credit carryforwards	23,000,000
Foreign | Netherlands
Income Tax Examination [Line Items]
Operating loss carryforwards	5,000,000
State
Income Tax Examination [Line Items]
Decrease in income tax expense due to state tax flow through of accelerated depreciation	9,000,000	$ 11,000,000	$ 7,000,000
Operating loss carryforwards	606,000,000
Domestic | Mountaintop Energy Holding, LLC
Income Tax Examination [Line Items]
Operating loss carryforwards	$ 24,000,000

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of U.S. Federal Statutory Tax Rate to Effective Tax Rate (Details)	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Operating Loss Carryforwards [Line Items]
U.S. federal statutory tax rate	21.00%	21.00%	21.00%
Difference in tax rate due to:
Noncontrolling interests not subject to tax	0.00%	0.00%	(2.70%)
State income taxes, net of federal benefit	1.90%	2.80%	3.60%
Valuation allowance adjustments	1.00%	0.00%	0.00%
Effects of foreign operations	4.60%	1.30%	1.80%
Excess tax benefits on share-based payments	(0.10%)	(0.20%)	(1.00%)
Other, net	(0.10%)	(0.30%)	0.70%
Effective tax rate	26.20%	20.20%	23.10%
Effect of U.S. tax legislation
Difference in tax rate due to:
Effect of tax rate change	(0.80%)	(4.70%)	0.20%
Effect of tax rate changes - International
Difference in tax rate due to:
Effect of tax rate change	(1.30%)	0.30%	(0.50%)

Income Taxes - Deferred Tax Lia

Income Taxes - Deferred Tax Liabilities (Assets) (Details) - USD ($) $ in Millions	Sep. 30, 2021	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Excess book basis over tax basis of property, plant and equipment	$ 937	$ 830
Utility regulatory assets	105	112
Intangible assets and goodwill	77	107
Derivative instrument assets	322	0
Other	36	32
Gross deferred tax liabilities	1,477	1,081
Investment in AmeriGas Partners	(102)	(216)
Pension plan liabilities	(29)	(48)
Employee-related benefits	(45)	(46)
Operating loss carryforwards	(53)	(34)
Foreign tax credit carryforwards	(79)	(81)
Utility regulatory liabilities	(102)	(94)
Derivative instrument liabilities	0	(26)
Utility environmental liabilities	(16)	(16)
Other	(107)	(54)
Gross deferred tax assets	(533)	(615)
Deferred tax assets valuation allowance	138	105
Net deferred tax liabilities	$ 1,082	$ 571

Employee Retirement Plans - Nar

Employee Retirement Plans - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Defined Benefit Plan Disclosure [Line Items]
ABO	$ 31	$ 31	$ 24
Fair value of plan assets	19	19	17
Expected amortization of net actuarial losses	0	0
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected amortization of net actuarial losses	7	7
Contribution made to Pension Plan		14	13
Projected benefit obligations of unfunded and non qualified supplemental executive retirement plans	870	870	782	$ 750
Costs associated with the plans		8	11	9
Net actuarial loss	13	13	24
Payments for defined benefit retirement plan		30	29
Supplemental Employee Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligations of unfunded and non qualified supplemental executive retirement plans	57	57	59
Costs associated with the plans		0	0
Net actuarial loss	10	10	12
Payments for defined benefit retirement plan	12		0	0
Fair value of pension and other postretirement benefit contributions	$ 44	44	35
U.S. | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Contribution made to Pension Plan		$ 13	$ 13	$ 12

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, 2021	Sep. 30, 2020	Sep. 30, 2019
Change in benefit obligations:
Benefit obligations — beginning of year	$ 782	$ 750
Service cost	12	11	$ 10
Interest cost	22	23	27
Actuarial (gain) loss	(30)	27
Plan amendments	2	0
Acquisitions	114	0
Curtailments	0	(2)
Foreign currency (gain) loss	(1)	3
Benefits paid	(31)	(30)
Benefit obligations — end of year	870	782	750
Change in plan assets:
Fair value of plan assets — beginning of year	585	547
Actual gain on plan assets	75	53
Foreign currency	0	1
Employer contributions	14	13
Acquisitions	92	0
Benefits paid	(30)	(29)
Fair value of plan assets — end of year	736	585	$ 547
Funded status of the plans — end of year	(134)	(197)
Amounts recorded in UGI Corporation stockholders’ equity (pre-tax):
Prior service cost	3	1
Net actuarial loss	13	24
Total	16	25
Amounts recorded in regulatory assets and liabilities (pre-tax):
Net actuarial loss	108	174
Total	108	174
ABO for the pension plans	$ 756	$ 687

Employee Retirement Plans - Act

Employee Retirement Plans - Actuarial Assumptions for Domestic Plans (Details) - Pension Benefits	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Weighted-average assumptions:
Discount rate – benefit obligations	3.13%	2.90%	3.30%
Discount rate – benefit cost	2.90%	3.30%	4.40%
Expected return on plan assets	7.10%	7.20%	7.30%
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, 2021	Sep. 30, 2020	Sep. 30, 2019
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 12	$ 11	$ 10
Interest cost	22	23	27
Expected return on assets	(40)	(38)	(36)
Curtailment gain	0	(1)	0
Amortization of:
Prior service cost	0	1	0
Actuarial loss	14	15	8
Net cost	$ 8	$ 11	$ 9

Employee Retirement Plans - Exp

Employee Retirement Plans - Expected Payments for Pension Benefits and Other Postretirement Welfare Benefits (Details) - Pension Benefits $ in Millions	Sep. 30, 2021USD ($)
Defined Benefit Plan Disclosure [Line Items]
Fiscal 2022	$ 36
Fiscal 2023	36
Fiscal 2024	41
Fiscal 2025	41
Fiscal 2026	43
Fiscal 2027 - 2031	$ 230

Employee Retirement Plans - Pen

Employee Retirement Plans - Pension Plans Assets (Details) - Pension Benefits - U.S.	Sep. 30, 2021	Sep. 30, 2020
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	100.00%	100.00%
Target Asset Allocation	100.00%	100.00%
Target allocation range	5.00%
U.S. equities
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	22.20%	26.50%
Target Asset Allocation	25.30%	29.00%
Non-U.S. equities
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	21.70%	25.00%
Target Asset Allocation	21.40%	24.50%
Global equities
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	16.00%	12.30%
Target Asset Allocation	13.10%	11.50%
Equity investments
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	59.90%	63.80%
Target Asset Allocation	59.80%	65.00%
Fixed income funds & cash equivalents
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	36.40%	36.20%
Target Asset Allocation	34.40%	35.00%
Alternative investments
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	3.70%	0.00%
Target Asset Allocation	5.80%	0.00%

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, 2021	Sep. 30, 2020	Sep. 30, 2019
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 736	$ 585	$ 547
U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	717	566
U.S. | U.S. equities
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	35	27
U.S. | UGI Corporation Common Stock
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	35	27
U.S. | Total common collective trust funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	655	539
U.S. | U.S. equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	124	123
U.S. | Non-U.S. equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	155	141
U.S. | Global equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	115	70
U.S. | Bond index mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	254	200
U.S. | Cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	7	5
U.S. | Alternative investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 27	$ 0

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, 2021	Sep. 30, 2020	Sep. 30, 2019
Defined Contribution Plan Disclosure [Line Items]
Costs of benefits under savings plans	$ 21	$ 21	$ 19
Total fair values of grantor trust investment assets	$ 9	$ 7

Utility Regulatory Assets and_3

Utility Regulatory Assets and Liabilities and Regulatory Matters - Regulatory Assets and Liabilities Associated with Utilities (Details) - UGI Utilities - USD ($) $ in Millions	Sep. 30, 2021	Sep. 30, 2020
Regulatory Assets [Line Items]
Regulatory assets	$ 397	$ 397
Regulatory Liabilities [Line Items]
Regulatory liabilities	388	353
Postretirement benefit overcollections
Regulatory Liabilities [Line Items]
Regulatory liabilities	13	13
Deferred fuel and power refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities	36	29
State income tax benefits — distribution system repairs
Regulatory Liabilities [Line Items]
Regulatory liabilities	32	28
PAPUC Temporary Rates Order
Regulatory Liabilities [Line Items]
Regulatory liabilities	0	7
Excess federal deferred income taxes
Regulatory Liabilities [Line Items]
Regulatory liabilities	287	274
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities	20	2
Income taxes recoverable
Regulatory Assets [Line Items]
Regulatory assets	143	124
Underfunded pension and postretirement plans
Regulatory Assets [Line Items]
Regulatory assets	108	175
Environmental costs
Regulatory Assets [Line Items]
Regulatory assets	58	61
Deferred fuel and power costs
Regulatory Assets [Line Items]
Regulatory assets	11	0
Removal costs, net
Regulatory Assets [Line Items]
Regulatory assets	24	26
Other
Regulatory Assets [Line Items]
Regulatory assets	$ 53	$ 11

Utility Regulatory Assets and_4

Utility Regulatory Assets and Liabilities and Regulatory Matters - Narrative (Details) - USD ($)	Nov. 09, 2021	Feb. 08, 2021	Oct. 08, 2020	Jan. 28, 2020	Oct. 11, 2019	Jan. 28, 2019	Oct. 27, 2018	Oct. 19, 2016	Sep. 30, 2021	Sep. 30, 2020
Regulatory Assets [Line Items]
Regulatory asset, amortization period							20 years
UGI Gas
Regulatory Assets [Line Items]
Effective period						12 months
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		$ 71,000,000
Approved rate increase, amount			$ 20,000,000		$ 30,000,000
Property, plant and equipment, net threshold			2,875,000,000
Energy Efficiency and Conservation and Growth extension tariff, extension term					5 years
Tax benefit to be returned						$ 24,000,000
Pennsylvania Public Utility Commission | UGI Gas | Subsequent Event
Regulatory Assets [Line Items]
Approved rate increase, amount	$ 6,000,000
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
Postretirement benefit overcollections
Regulatory Assets [Line Items]
Regulatory liability, amortization period								10 years
Regulated natural gas utilities
Regulatory Assets [Line Items]
Fair value of unrealized gains (losses)									$ 35,000,000	$ 8,000,000
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, 2021	Sep. 30, 2020
Public Utilities, Inventory
Total inventories	$ 469	$ 241
Non-utility LPG and natural gas
Public Utilities, Inventory
Total inventories	278	164
Utility natural gas
Public Utilities, Inventory
Total inventories	68	20
Energy certificates
Public Utilities, Inventory
Total inventories	53	3
Materials, supplies and other
Public Utilities, Inventory
Total inventories	$ 70	$ 54

Property, Plant and Equipment -

Property, Plant and Equipment - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Property, Plant and Equipment
Utility	$ 5,022	$ 4,265
Non-utility	6,486	6,393
Total property, plant and equipment	11,508	10,658
Distribution
Property, Plant and Equipment
Utility	4,306	3,630
Transmission
Property, Plant and Equipment
Utility	111	111
General and other
Property, Plant and Equipment
Utility	507	425
Work in process
Property, Plant and Equipment
Utility	98	99
Non-utility	76	196
Land
Property, Plant and Equipment
Non-utility	186	191
Buildings and improvements
Property, Plant and Equipment
Non-utility	$ 436	431
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	$ 232	248
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	$ 3,785	3,712
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	$ 211	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	$ 1,218	1,098
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	$ 342	$ 306
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, 2021	Sep. 30, 2020	Sep. 30, 2019
Property, Plant and Equipment
Depreciation	$ 437	$ 416	$ 389
Regulated natural gas utilities
Property, Plant and Equipment
Average composite depreciation rates (as a percentage)	2.60%	2.50%	2.20%
Electric Utility
Property, Plant and Equipment
Average composite depreciation rates (as a percentage)	2.30%	2.20%	2.10%

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, 2021	Sep. 30, 2020
Goodwill
Balance at beginning of period	$ 3,518	$ 3,456
Acquisitions	261
Dispositions		(5)
Purchase accounting adjustments	1	(2)
Foreign currency translation	(10)	69
Balance at end of period	3,770	3,518
AmeriGas Propane
Goodwill
Balance at beginning of period	2,004	2,004
Acquisitions	0
Dispositions		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	997	930
Acquisitions	6
Dispositions		0
Purchase accounting adjustments	0	(2)
Foreign currency translation	(10)	69
Balance at end of period	993	997
Midstream & Marketing
Goodwill
Balance at beginning of period	335	340
Acquisitions	0
Dispositions		(5)
Purchase accounting adjustments	1	0
Foreign currency translation	0	0
Balance at end of period	336	335
UGI Utilities
Goodwill
Balance at beginning of period	182	182
Acquisitions	255
Dispositions		0
Purchase accounting adjustments	0	0
Foreign currency translation	0	0
Balance at end of period	$ 437	$ 182

Goodwill and Intangible Asset_3

Goodwill and Intangible Assets - Components of Intangible Assets (Details) - USD ($) $ in Millions	Sep. 30, 2021	Sep. 30, 2020
Goodwill and Intangible Assets Disclosure [Abstract]
Customer relationships	$ 1,054	$ 1,083
Trademarks and tradenames	12	12
Noncompete agreements and other	75	76
Accumulated amortization	(607)	(543)
Intangible assets, net (definite-lived)	534	628
Trademarks and tradenames (indefinite-lived)	49	49
Total intangible assets, net	$ 583	$ 677

Goodwill and Intangible Asset_4

Goodwill and Intangible Assets - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Goodwill and Intangible Assets Disclosure [Abstract]
Impairment charges	$ 20			$ 0
Amortization expense of intangible assets		$ 76	$ 83	$ 59
Fiscal 2022	61	61
Fiscal 2023	57	57
Fiscal 2024	55	55
Fiscal 2025	53	53
Fiscal 2026	$ 52	$ 52

Equity - Narrative (Details)

Equity - Narrative (Details) - USD ($)	Jun. 01, 2024	May 25, 2021	Jan. 25, 2018	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019	May 17, 2021
Class of Stock [Line Items]
Treasury stock acquired				$ 26,000,000	$ 49,000,000
Preferred Stock, shares authorized (in shares)				5,000,000	5,000,000
Preferred Stock, shares outstanding (in shares)				0	0
Recorded value				$ 213,000,000	$ 0
Shares issued on conversion settlement (in shares)		1
Sale price (in USD 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
Maximum settlement rate		2.2826
Number of common stock deliverable percentage		85.00%
Quarterly contract adjustment payments percentage		7.125%
2024 Purchase Contracts | Forecast
Class of Stock [Line Items]
Contract redemption obligation	$ 100
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
Treasury stock acquired					$ 38,000,000	$ 17,000,000
Common Stock | Treasury stock
Class of Stock [Line Items]
Repurchases of common stock - Treasury (in shares)				0	(950,000)	(300,000)
Capital 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 USD per share)		$ 100
Undivided beneficial ownership interest		10.00%
Liquidation preference (in USD per share)		$ 1,000
Issuance of preferred stock		$ 213,000,000
Convertible Preferred Stock
Class of Stock [Line Items]
Liquidation preference (in USD per share)		$ 1,000
Dividend rate		0.125%
Shares issued on conversion (in shares)		19.0215
Stock conversion price (in USD 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
Recorded value		$ 213,000,000
Series B preferred stock
Class of Stock [Line Items]
Preferred Stock, shares authorized (in shares)				220,000

Equity - Common Stock Share Act

Equity - Common Stock Share Activity (Details) - shares	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Common Stock Share Activity
Beginning balance - shares Outstanding (in shares)	0	0	0
Issued:
Ending balance - shares Outstanding (in shares)		0	0
Common Stock
Common Stock Share Activity
Beginning balance - shares Issued/Treasury (in shares)	209,843,296	209,514,044	209,304,129	174,142,997
Beginning balance - shares Outstanding (in shares)	208,354,438	209,004,789	173,748,975
Issued:
Employee and director plans - shares Issued/Treasury (in shares)	329,252	209,915	548,285
Employee and director plans - shares Outstanding (in shares)	883,567	389,965	979,132
AmeriGas Merger -Issued (in shares)			34,612,847
AmeriGas Merger - Outstanding (in shares)			34,612,847
Sale of reacquired common stock - Outstanding (in shares)			15,759
Reacquired common stock, employee and director plans - Outstanding (in shares)	(21,870)	(90,316)	(51,924)
Ending balance - shares Issued/Treasury (in shares)	209,843,296	209,514,044	209,304,129	174,142,997
Ending balance - shares Outstanding (in shares)	209,216,135	208,354,438	209,004,789
Common Stock | Treasury stock
Common Stock Share Activity
Beginning balance - shares Issued/Treasury (in shares)	627,161	1,159,606	299,340	394,022
Issued:
Employee and director plans - shares Issued/Treasury (in shares)	554,315	180,050	430,847
AmeriGas Merger -Issued (in shares)			0
Sale of reacquired common stock - Treasury (in shares)			15,759
Treasury stock acquired (in shares)	0	950,000	300,000
Reacquired common stock, employee and director plans - Treasury (in shares)	(21,870)	(90,316)	(51,924)
Ending balance - shares Issued/Treasury (in shares)	627,161	1,159,606	299,340	394,022
Preferred stock, without par value
Common Stock Share Activity
Beginning balance - shares Issued/Treasury (in shares)	220,000	0	0	0
Issued:
Ending balance - shares Issued/Treasury (in shares)	220,000	0	0	0
Ending balance - shares Outstanding (in shares)	220,000
Stock Issued During Period, Shares, New Issues	220,000

Equity-Based Compensation - Nar

Equity-Based Compensation - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 29, 2021	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award
Pre-tax equity-based compensation expense		$ 21	$ 15	$ 18
After tax equity-based compensation expense		$ 15	$ 11	$ 13
Weighted-average fair value of stock option granted under stock plans (in dollars per share)		$ 6.05	$ 5.58	$ 8.70
Options outstanding (in shares)		10,204,836
Options exercisable (in shares)		7,445,827
Weighted average exercise price (in dollars per share)		$ 38.42
UGI Stock Option Awards
Share-based Compensation Arrangement by Share-based Payment Award
Unrecognized compensation cost associated with unvested unit awards		$ 7
Weighted-average period of recognition for unvested unit awards		2 years
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)		$ 41.41	$ 41.47	$ 55.40
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)		0.00%
UGI Performance Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted (as a percentage)		200.00%
UGI Performance Units and Stock Units
Share-based Compensation Arrangement by Share-based Payment Award
Unrecognized compensation cost associated with unvested unit awards		$ 19
Weighted-average period of recognition for unvested unit awards		1 year 10 months 24 days
UGI Unit awards outstanding (in shares)		1,124,369
Weighted average grant date fair value, outstanding (in dollars per share)		$ 33.41
Common Stock | 2021 IAP
Share-based Compensation Arrangement by Share-based Payment Award
Common Stock awards granted (up to)	20,500,000
Number of common unit awards available for future grant (in shares)		20,037,430
Expiration period	10 years

Partnership Distributions (Deta

Partnership Distributions (Details) - USD ($) $ in Millions	11 Months Ended	12 Months Ended
	Aug. 21, 2019	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Distribution Made to Limited Partner
Partnership distributions to partners (days following quarter end)		45 days
Pre-Incentive distribution of available cash to General Partners (as a percentage)		2.00%	2.00%	2.00%
General Partners distribution based on ownership interest			$ 55	$ 55
Incentive distributions received by the General Partner			$ 45	$ 45
Limited Partner
Distribution Made to Limited Partner
Distribution of available cash, percent	98.00%
General Partner
Distribution Made to Limited Partner
Distribution of available cash, percent	2.00%
AmeriGas Partners
Distribution Made to Limited Partner
Distribution of available cash, percent	1.00%
AmeriGas OLP
Distribution Made to Limited Partner
Distribution of available cash, percent	1.01%

Leases - Addition Details (Deta

Leases - Addition Details (Details)	12 Months Ended
	Sep. 30, 2021USD ($)
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	85.00%
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, 2021	Sep. 30, 2020
ROU assets:
Operating lease ROU assets	$ 390	$ 415
Finance lease ROU assets	49	52
Total ROU assets	$ 439	$ 467
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]	Carrying value	Carrying value
Lease liabilities:
Operating lease liabilities — current	$ 81	$ 87
Operating lease liabilities — noncurrent	318	334
Finance lease liabilities — current	4	5
Finance lease liabilities — noncurrent	41	41
Total lease liabilities	$ 444	$ 467
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, 2021	Sep. 30, 2020
Leases [Abstract]
Operating lease cost	$ 101	$ 102
Finance lease cost:
Amortization of ROU assets	4	5
Interest on lease liabilities	3	3
Variable lease cost	4	5
Short-term lease cost	2	3
Total lease cost	114	118
Cash paid related to lease liabilities:
Operating cash flows — operating leases	99	103
Operating cash flows — finance leases	3	3
Financing cash flows — finance leases	3	4
Non-cash lease liability activities:
ROU assets obtained in exchange for operating lease liabilities	85	506
ROU assets obtained in exchange for finance lease liabilities	$ 1	$ 22
Weighted-average remaining lease term (in years)
Operating leases	6 years 3 months 18 days	6 years 2 months 12 days
Finance leases	2 years 4 months 24 days	2 years 4 months 24 days
Weighted-average discount rate (%)
Operating leases	3.60%	3.80%
Finance leases	1.50%	1.90%

Leases - Operating and Finance

Leases - Operating and Finance Leases, Liability, Maturity (Details) $ in Millions	Sep. 30, 2021USD ($)
Operating leases
2022	$ 92
2023	81
2024	71
2025	55
2026	44
After 2026	103
Total Lease Payments	446
Imputed Interest	(47)
Lease Liabilities	399
Finance leases
2022	4
2023	4
2024	3
2025	3
2026	3
After 2026	81
Total Lease Payments	98
Imputed Interest	(53)
Lease Liabilities	$ 45

Commitments and Contingencies -

Commitments and Contingencies - Contingencies (Details) $ in Millions	Oct. 01, 2020agreement	Sep. 30, 2020USD ($)agreement	Dec. 31, 2017record_of_decision	Dec. 31, 2008lb	Dec. 31, 2007lb	Sep. 30, 2021USD ($)subsidiary	Sep. 30, 2017USD ($)
Loss Contingencies [Line Items]
Environmental expenditures cap during year						$ 5
Amount of propane in cylinders being sold | lb					17
Reduced amount of propane in cylinders being sold | lb				15
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.
Loss Contingencies [Line Items]
Number of COAs | agreement	1	3
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) - Recurring Basis - USD ($) $ in Millions	Sep. 30, 2021	Sep. 30, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-qualified supplemental postretirement grantor trust investments	$ 53	$ 42
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-qualified supplemental postretirement grantor trust investments	53	42
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	1,649	107
Derivative instruments, Liabilities	(280)	(118)
Commodity contracts | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	641	68
Derivative instruments, Liabilities	(264)	(54)
Commodity contracts | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	1,008	39
Derivative instruments, Liabilities	(16)	(64)
Commodity contracts | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	0	0
Derivative instruments, Liabilities	0	0
Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	38	32
Derivative instruments, Liabilities	(8)	(14)
Foreign currency contracts | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	0	0
Derivative instruments, Liabilities	0	0
Foreign currency contracts | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	38	32
Derivative instruments, Liabilities	(8)	(14)
Foreign currency contracts | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	0	0
Derivative instruments, Liabilities	0	0
Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Liabilities	(29)	(55)
Interest rate contracts | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Liabilities	0	0
Interest rate contracts | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Liabilities	(29)	(55)
Interest rate contracts | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Liabilities	$ 0	$ 0

Fair Value Measurements - Long-

Fair Value Measurements - Long-term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2021	Sep. 30, 2020
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,491	$ 6,081
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,996	$ 6,504

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Narrative (Details) - USD ($)	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Derivative [Line Items]
Pre-tax net losses associated with interest rate hedges	$ 4,000,000
Pre-tax (losses) gains associated with net investment hedges	9,000,000	$ (53,000,000)
Total derivative assets – gross	1,687,000,000	139,000,000
Maximum amount of loss	1,687,000,000
Cash collateral received	(468,000,000)	0
IRPA
Derivative [Line Items]
Notional amount	$ 0	$ 0
Foreign Exchange Forward
Derivative [Line Items]
Potential exposure coverage, percent (as a percentage)	90.00%

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	Sep. 30, 2021USD ($)galDTHkWh	Sep. 30, 2021EUR (€)galDTHkWh	Sep. 30, 2020USD ($)DTHgalkWh	Sep. 30, 2020EUR (€)DTHgalkWh
Commodity contracts | Propane
Derivative [Line Items]
Notional amount (in units) | gal	708	708	846	846
Commodity contracts | Electricity
Derivative [Line Items]
Notional amount (in units) | kWh	4,302	4,302	4,705	4,705
Natural gas futures, forward, basis swap, options and pipeline contracts | Natural Gas
Derivative [Line Items]
Notional amount (in units)	355	355	339	339
Interest rate swaps
Derivative [Line Items]
Notional amount	$ 1,421	€ 300	$ 1,344	€ 300
Forward foreign exchange contracts
Derivative [Line Items]
Notional amount	$ 509	€ 173	$ 511	€ 173
Regulated Utility Operations | Commodity contracts | Natural Gas
Derivative [Line Items]
Notional amount (in units)	20	20	22	22

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, 2021	Sep. 30, 2020
Derivative assets:
Fair value of derivative instruments	$ 1,687	$ 139
Gross amounts offset in the balance sheet	(216)	(57)
Cash collateral received	(468)	0
Total derivative assets – net	1,003	82
Derivative liabilities:
Total derivative liabilities – gross	(317)	(187)
Gross amounts offset in the balance sheet	216	57
Cash collateral pledged	3	7
Total derivative liabilities – net	(98)	(123)
Commodity contract - subject to PGC and DS mechanisms
Derivative assets:
Fair value of derivative instruments	58	7
Derivative liabilities:
Total derivative liabilities – gross	(23)	0
Derivatives designated as hedging instruments | Foreign currency contracts
Derivative assets:
Fair value of derivative instruments	20	17
Derivatives designated as hedging instruments | Interest rate contracts
Derivative liabilities:
Total derivative liabilities – gross	(29)	(55)
Derivatives not designated as hedging instruments
Derivative assets:
Fair value of derivative instruments	1,609	115
Derivative liabilities:
Total derivative liabilities – gross	(265)	(132)
Derivatives not designated as hedging instruments | Foreign currency contracts
Derivative assets:
Fair value of derivative instruments	18	15
Derivative liabilities:
Total derivative liabilities – gross	(8)	(14)
Derivatives not designated as hedging instruments | Commodity contracts
Derivative assets:
Fair value of derivative instruments	1,591	100
Derivative liabilities:
Total derivative liabilities – gross	$ (257)	$ (118)

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, 2021	Sep. 30, 2020	Sep. 30, 2019
Derivatives Not Designated as Hedging Instruments:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 1,542	$ (42)	$ (299)
Derivatives Not Designated as Hedging Instruments: | Foreign currency contracts | Other non-operating income (expense), net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	9	(20)	38
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Revenues
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(17)	10	7
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	1,545	(32)	(344)
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Other operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	5	0	0
Cash Flow Hedges:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	4	(53)	(10)
Gain (Loss) Reclassified from AOCI into Income	(25)	(13)	(4)
Cash Flow Hedges: | Foreign currency contracts
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	0	0	1
Cash Flow Hedges: | Foreign currency contracts | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Reclassified from AOCI into Income	0	0	2
Cash Flow Hedges: | Interest rate contracts
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	4	(53)	(11)
Cash Flow Hedges: | Interest rate contracts | Interest expense
Derivative Instruments, Gain (Loss)
Gain (Loss) Reclassified from AOCI into Income	(25)	(13)	(6)
Net Investment Hedges: | Foreign currency contracts
Derivative Instruments, Gain (Loss)
Foreign currency contracts	$ 4	$ (1)	$ 17

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	$ 4,137	$ 3,827
Other comprehensive (loss) income before reclassification adjustments (after-tax)	(13)	58	$ (103)
Amounts reclassified from AOCI	20	12	3
Other comprehensive (loss) income attributable to UGI	7	70	(100)
Reclassification of stranded income tax effects related to TCJA			(7)
Balance, end of year	5,531	4,137	3,827
Postretirement Benefit Plans
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(26)	(26)	(11)
Other comprehensive (loss) income before reclassification adjustments (after-tax)	7	(3)	(13)
Amounts reclassified from AOCI	2	3	1
Other comprehensive (loss) income attributable to UGI	9	0	(12)
Reclassification of stranded income tax effects related to TCJA			(3)
Balance, end of year	(17)	(26)	(26)
Derivative Instruments
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(54)	(25)	(16)
Other comprehensive (loss) income before reclassification adjustments (after-tax)	3	(38)	(7)
Amounts reclassified from AOCI	18	9	2
Other comprehensive (loss) income attributable to UGI	21	(29)	(5)
Reclassification of stranded income tax effects related to TCJA			(4)
Balance, end of year	(33)	(54)	(25)
Foreign Currency
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(67)	(166)	(83)
Other comprehensive (loss) income before reclassification adjustments (after-tax)	(23)	99	(83)
Amounts reclassified from AOCI	0	0	0
Other comprehensive (loss) income attributable to UGI	(23)	99	(83)
Reclassification of stranded income tax effects related to TCJA			0
Balance, end of year	(90)	(67)	(166)
Accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(147)	(217)	(110)
Reclassification of stranded income tax effects related to TCJA			(7)
Balance, end of year	$ (140)	$ (147)	$ (217)

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, 2021	Sep. 30, 2020	Sep. 30, 2019
Component of Operating Income [Abstract]
Finance charges	$ 17	$ 9	$ 17
Gains on sales of fixed assets, net	11	5	3
Gain on early derivative termination	5	0	0
Interest and interest-related income	0	2	6
Utility non-tariff service income	0	0	1
Other, net	0	5	4
Total other operating income, net	$ 33	$ 21	$ 31

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, 2021	Sep. 30, 2020	Sep. 30, 2019
Component of Operating Income [Abstract]
Gains (losses) on foreign currency contracts, net	$ 9	$ (20)	$ 38
Gain (Loss) on Derivative Instruments, Net, Pretax	2	0	0
Pension and other postretirement plans non-service income, net	1	0	1
Total other non-operating income (expense), net	$ 12	$ (20)	$ 39

Equity Method Investments (Deta

Equity Method Investments (Details) $ in Millions	1 Months Ended
	Jun. 30, 2021USD ($)	Feb. 28, 2021USD ($)mi	Sep. 30, 2021USD ($)mi	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)
Schedule of Equity Method Investments [Line Items]
Equity method investments			$ 174	$ 200	$ 190
Pine Run Midstream L L C Member
Schedule of Equity Method Investments [Line Items]
Total purchase price		$ 205
Area of natural gas pipeline to be operated (in miles) | mi		43
PennEast
Schedule of Equity Method Investments [Line Items]
Pretax impairment charge	$ 93
PennEast | Level 2
Schedule of Equity Method Investments [Line Items]
Equity method investments			$ 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 percentage (as a percentage)			20.00%
PennEast | Southern Company | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Ownership percentage (as a percentage)			20.00%
PennEast | New Jersey Resources | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Ownership percentage (as a percentage)			20.00%
PennEast | South Jersey Industries | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Ownership percentage (as a percentage)			20.00%
PennEast | Enbridge Inc | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Ownership percentage (as a percentage)			20.00%
Pennant
Schedule of Equity Method Investments [Line Items]
Equity method investments			$ 93	$ 94
Pennant | Energy Services
Schedule of Equity Method Investments [Line Items]
Ownership percentage (as a percentage)			47.00%
Pine Run Midstream L L C Member
Schedule of Equity Method Investments [Line Items]
Equity method investments			$ 60

Segment Information - Narrative

Segment Information - Narrative (Details)	12 Months Ended
	Sep. 30, 2021statesegment
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)	20.00%
France | Geographic Concentration Risk | Long-lived Assets
Segment Reporting Information [Line Items]
Concentration risk, percentage (as a percentage)	10.00%

Segment Information - Schedule

Segment Information - Schedule of Segment Reporting (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Segment Reporting Information [Line Items]
Revenues	$ 7,447	$ 6,559	$ 7,320
Cost of sales	2,614	3,149	4,323
Operating income (loss)	2,350	982	617
(Loss) income from equity investees	(63)	27	9
Loss on extinguishments of debt	0	0	(6)
Other non-operating income, net	12	(20)	39
Earnings (loss) before interest expense and income taxes	2,299	989	659
Interest expense	(310)	(322)	(258)
Income tax (expense) benefit	(522)	(135)	(93)
Noncontrolling interests’ net (income) loss	0	0	(52)
Net income attributable to UGI Corporation	1,467	532	256
Depreciation and amortization	502	484	448
Total assets	16,723	13,985	13,347
Short-term borrowings	367	347	796
Capital expenditures (including the effects of accruals)	674	665	707
Investments in equity investees	174	200	190
Eliminations
Segment Reporting Information [Line Items]
Revenues	(291)	(232)	(306)
Cost of sales	(288)	(229)	(301)
Operating income (loss)	0	0	0
(Loss) income from equity investees	0	0	0
Loss on extinguishments of debt			0
Other non-operating income, net	0	0	(1)
Earnings (loss) before interest expense and income taxes	0	0	(1)
Interest expense	0	0	0
Income tax (expense) benefit	0	0	0
Noncontrolling interests’ net (income) loss			0
Net income attributable to UGI Corporation	0	0	(1)
Depreciation and amortization	0	0	0
Total assets	(241)	(282)	(353)
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	224	182	235
Eliminations | UGI Utilities
Segment Reporting Information [Line Items]
Revenues	64	47	68
Operating Segments | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	2,614	2,381	2,682
Cost of sales	1,217	960	1,191
Operating income (loss)	385	373	404
(Loss) income from equity investees	0	0	0
Loss on extinguishments of debt			0
Other non-operating income, net	0	0	0
Earnings (loss) before interest expense and income taxes	385	373	404
Interest expense	(159)	(164)	(167)
Income tax (expense) benefit	(58)	(53)	(26)
Noncontrolling interests’ net (income) loss			(143)
Net income attributable to UGI Corporation	168	156	68
Depreciation and amortization	173	178	179
Total assets	4,485	4,327	4,095
Short-term borrowings	170	186	328
Capital expenditures (including the effects of accruals)	130	135	107
Investments in equity investees	0	0	0
Operating Segments | UGI International
Segment Reporting Information [Line Items]
Revenues	2,651	2,127	2,372
Cost of sales	1,598	1,191	1,416
Operating income (loss)	314	241	229
(Loss) income from equity investees	0	0	0
Loss on extinguishments of debt			0
Other non-operating income, net	3	18	5
Earnings (loss) before interest expense and income taxes	317	259	234
Interest expense	(27)	(31)	(25)
Income tax (expense) benefit	(69)	(55)	(64)
Noncontrolling interests’ net (income) loss			0
Net income attributable to UGI Corporation	221	173	145
Depreciation and amortization	134	125	124
Total assets	4,421	3,123	2,975
Short-term borrowings	0	1	211
Capital expenditures (including the effects of accruals)	107	89	106
Investments in equity investees	11	10	12
Operating Segments | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	1,406	1,247	1,516
Revenues from external customers	1,182	1,065	1,281
Cost of sales	1,033	892	1,241
Operating income (loss)	160	140	105
(Loss) income from equity investees	30	27	9
Loss on extinguishments of debt			0
Other non-operating income, net	0	1	0
Earnings (loss) before interest expense and income taxes	190	168	114
Interest expense	(42)	(42)	(9)
Income tax (expense) benefit	(41)	(34)	(27)
Noncontrolling interests’ net (income) loss			0
Net income attributable to UGI Corporation	107	92	78
Depreciation and amortization	76	75	51
Total assets	3,010	2,775	2,745
Short-term borrowings	0	19	91
Capital expenditures (including the effects of accruals)	43	93	138
Investments in equity investees	163	190	178
Operating Segments | UGI Utilities
Segment Reporting Information [Line Items]
Revenues	1,079	1,030	1,049
Revenues from external customers	1,015	983	981
Cost of sales	458	448	481
Operating income (loss)	241	229	224
(Loss) income from equity investees	0	0	0
Loss on extinguishments of debt			0
Other non-operating income, net	1	0	2
Earnings (loss) before interest expense and income taxes	242	229	226
Interest expense	(56)	(54)	(50)
Income tax (expense) benefit	(42)	(39)	(43)
Noncontrolling interests’ net (income) loss			0
Net income attributable to UGI Corporation	144	136	133
Depreciation and amortization	119	105	93
Total assets	4,859	3,809	3,560
Short-term borrowings	197	141	166
Capital expenditures (including the effects of accruals)	394	348	355
Investments in equity investees	0	0	0
Corporate & Other
Segment Reporting Information [Line Items]
Revenues	(12)	6	7
Revenues from external customers	(15)	3	4
Cost of sales	(1,404)	(113)	295
Operating income (loss)	1,250	(1)	(345)
(Loss) income from equity investees	(93)	0	0
Loss on extinguishments of debt			(6)
Other non-operating income, net	8	(39)	33
Earnings (loss) before interest expense and income taxes	1,165	(40)	(318)
Interest expense	(26)	(31)	(7)
Income tax (expense) benefit	(312)	46	67
Noncontrolling interests’ net (income) loss			91
Net income attributable to UGI Corporation	827	(25)	(167)
Depreciation and amortization	0	1	1
Total assets	189	233	325
Short-term borrowings	0	0	0
Capital expenditures (including the effects of accruals)	0	0	1
Investments in equity investees	0	0	0
Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishments of debt			0
Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Loss on extinguishments of debt			(6)
Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishments 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, 2021	Sep. 30, 2020	Sep. 30, 2019
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	$ 1,398	$ 81	$ (259)
Loss on extinguishments of debt	0	0	(6)
Loss on disposals of Conemaugh and HVAC	0	(54)	0
Corporate & Other
Segment Reporting Information [Line Items]
Loss on extinguishments of debt			(6)
Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishments of debt			0
Loss on disposals of Conemaugh and HVAC		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	167	72	(117)
Corporate & Other | AmeriGas Propane | Other non-operating (expense) income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0
Corporate & Other | AmeriGas Propane | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas Merger expenses			(6)
Acquisition and integration expenses associated with the CMG Acquisition		0	0
Business transformation expenses	(54)	(44)	(15)
Impairment of customer relationship intangible	0
Corporate & Other | AmeriGas Propane | (Loss) income from equity method investees
Segment Reporting Information [Line Items]
Impairment of investment in PennEast	0
Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Loss on extinguishments of debt			(6)
Loss on disposals of Conemaugh and HVAC		0
Corporate & Other | UGI International | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	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	1,065	0	(143)
Corporate & Other | UGI International | Other non-operating (expense) income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	8	(36)	32
Corporate & Other | UGI International | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas Merger expenses			0
Acquisition and integration expenses associated with the CMG Acquisition		0	0
Business transformation expenses	(33)	(18)	(9)
Impairment of customer relationship intangible	(20)
Corporate & Other | UGI International | (Loss) income from equity method investees
Segment Reporting Information [Line Items]
Impairment of investment in PennEast	0
Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishments of debt			0
Loss on disposals of Conemaugh and HVAC		(54)
Corporate & Other | Midstream & Marketing | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(15)	3	4
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	173	42	(35)
Corporate & Other | Midstream & Marketing | Other non-operating (expense) income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0
Corporate & Other | Midstream & Marketing | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas Merger expenses			0
Acquisition and integration expenses associated with the CMG Acquisition		(2)	(16)
Business transformation expenses	0	$ 0	$ 0
Impairment of customer relationship intangible	0
Corporate & Other | Midstream & Marketing | (Loss) income from equity method investees
Segment Reporting Information [Line Items]
Impairment of investment in PennEast	$ (93)

Business Transformation Initi_2

Business Transformation Initiatives (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Restructuring Cost and Reserve [Line Items]
Costs principally comprising consulting, advisory and employee-related costs	$ 87	$ 62	$ 24
Corporate Services Member
Restructuring Cost and Reserve [Line Items]
Costs principally comprising consulting, advisory and employee-related costs	$ 14

SCHEDULE I _ CONDENSED FINANC_3

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) - BALANCE SHEETS (Details) - USD ($) $ in Millions	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Current assets
Cash and cash equivalents	$ 855	$ 336	$ 447
Prepaid expenses and other current assets	101	59
Total current assets	3,270	1,543
Other assets	831	854
Total assets	16,723	13,985	$ 13,347
Current liabilities
Current maturities of long-term debt	110	53
Total current liabilities	2,297	1,755
Long-term debt	6,339	5,981
Other noncurrent liabilities	1,381	1,413
Total liabilities	11,192	9,848
Commitments and contingencies (Note 1)
Equity:
Preferred Stock, without par value (authorized 5,000,000 shares; issued 220,000 and 0 Series A shares, respectively)	213	0
Common Stock, without par value (authorized – 450,000,000 shares; issued – 209,843,296 and 209,514,044 shares, respectively)	1,394	1,416
Retained earnings	4,081	2,908
Accumulated other comprehensive loss	(140)	(147)
Treasury stock, at cost	(26)	(49)
Total UGI Corporation stockholders’ equity	5,522	4,128
Total liabilities and equity	$ 16,723	$ 13,985
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	0
Common Stock, shares authorized (in shares)	450,000,000	450,000,000
Common Stock, shares issued (in shares)	209,843,296	209,514,044
Parent Company
Current assets
Cash and cash equivalents	$ 14	$ 67
Accounts receivable – related parties	18	11
Prepaid expenses and other current assets	11	15
Total current assets	43	93
Property, plant and equipment, net	2	2
Investments in subsidiaries	6,479	4,898
Other assets	107	87
Total assets	6,631	5,080
Current liabilities
Current maturities of long-term debt	70	30
Accounts and notes payable	24	15
Accrued liabilities	62	29
Total current liabilities	156	74
Long-term debt	875	817
Other noncurrent liabilities	78	61
Total liabilities	1,109	952
Commitments and contingencies (Note 1)
Equity:
Preferred Stock, without par value (authorized 5,000,000 shares; issued 220,000 and 0 Series A shares, respectively)	213	0
Common Stock, without par value (authorized – 450,000,000 shares; issued – 209,843,296 and 209,514,044 shares, respectively)	1,394	1,416
Retained earnings	4,081	2,908
Accumulated other comprehensive loss	(140)	(147)
Treasury stock, at cost	(26)	(49)
Total UGI Corporation stockholders’ equity	5,522	4,128
Total liabilities and equity	$ 6,631	$ 5,080
Condensed Financial Information of Registrant [Abstract]
Common Stock, shares authorized (in shares)	450,000,000	450,000,000
Common Stock, shares issued (in shares)	209,843,296	209,514,044

SCHEDULE I _ CONDENSED FINANC_4

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) - Narrative (Details) $ in Millions	12 Months Ended
	Sep. 30, 2021USD ($)
Guarantee Obligations [Line Items]
Debt repayment in year 2022	$ 110
Debt repayment in year 2023	149
Debt repayment in year 2024	1,356
Debt repayment in year 2025	1,222
Parent Company
Guarantee Obligations [Line Items]
Surety bonds indemnified	75
Maximum amount authorized to guarantee obligations to suppliers and customers (up to)	475
Current carrying value	397
Debt repayment in year 2022	70
Debt repayment in year 2023	38
Debt repayment in year 2024	327
Debt repayment in year 2025	$ 515

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, 2021	Sep. 30, 2020	Sep. 30, 2019
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 7,447	$ 6,559	$ 7,320
Costs and expenses:
Operating and administrative expenses	2,014	1,911	1,963
Other operating income, net	33	21	31
Total costs and expenses	5,097	5,577	6,703
Operating income	2,350	982	617
Pension and other postretirement plans non-service expense	1	0	1
Income tax expense (benefit)	522	135	93
Equity in income of unconsolidated subsidiaries	(63)	27	9
Net income attributable to UGI Corporation	1,467	532	256
Comprehensive income attributable to UGI Corporation	$ 1,474	$ 602	$ 156
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ 7.02	$ 2.55	$ 1.44
Diluted (in dollars per share)	$ 6.92	$ 2.54	$ 1.41
Weighted - average common shares outstanding (thousands):
Basic (in shares)	209,063	208,928	178,417
Diluted (in shares)	212,126	209,869	181,111
Parent Company
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 0	$ 0	$ 0
Costs and expenses:
Operating and administrative expenses	94	56	50
Other operating income, net	(65)	(54)	(50)
Total costs and expenses	29	2	0
Operating income	(29)	(2)	0
Pension and other postretirement plans non-service expense	0	0	(1)
Interest expense	(27)	(32)	(6)
Loss before income taxes	(56)	(34)	(7)
Income tax expense (benefit)	9	17	(3)
Loss before equity in income of unconsolidated subsidiaries	(65)	(51)	(4)
Equity in income of unconsolidated subsidiaries	1,532	583	260
Net income attributable to UGI Corporation	1,467	532	256
Other comprehensive income (loss)	7	(12)	(3)
Equity in other comprehensive income (loss) of unconsolidated subsidiaries	0	82	(97)
Comprehensive income attributable to UGI Corporation	$ 1,474	$ 602	$ 156
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ 7.02	$ 2.55	$ 1.44
Diluted (in dollars per share)	$ 6.92	$ 2.54	$ 1.41
Weighted - average common shares outstanding (thousands):
Basic (in shares)	209,063	208,928	178,417
Diluted (in shares)	212,126	209,869	181,111

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, 2021	Sep. 30, 2020	Sep. 30, 2019
Condensed Financial Statements, Captions [Line Items]
NET CASH PROVIDED BY OPERATING ACTIVITIES	$ 1,481	$ 1,102	$ 1,078
CASH FLOWS FROM INVESTING ACTIVITIES
Net cash used by investing activities	(1,113)	(649)	(2,055)
CASH FLOWS FROM FINANCING ACTIVITIES
Payment of dividends on Common Stock	(282)	(273)	(200)
Issuances of debt, net of issuance costs	656	209	2,412
Issuances of Common Stock	19	2	17
Repurchases of UGI Common Stock	0	(38)	(17)
Other	0	0	(11)
Net cash provided (used) by financing activities	166	(635)	1,042
Cash, cash equivalents and restricted cash increase (decrease)	520	(154)	49
Cash and cash equivalents:
Cash, cash equivalents and restricted cash at end of year	877	357	511
Cash, cash equivalents and restricted cash at beginning of year	357	511	462
Cash and cash equivalents (decrease) increase	520	(154)	49
Parent Company
Condensed Financial Statements, Captions [Line Items]
NET CASH PROVIDED BY OPERATING ACTIVITIES	300	322	170
CASH FLOWS FROM INVESTING ACTIVITIES
Net investments in unconsolidated subsidiaries	(401)	0	(768)
Net cash used by investing activities	(401)	0	(768)
CASH FLOWS FROM FINANCING ACTIVITIES
Payment of dividends on Common Stock	(282)	(273)	(200)
Issuances of debt, net of issuance costs	483	60	846
Repayments of long-term debt	(385)	(60)	0
Issuance of preferred stock	213	0	0
Issuances of Common Stock	19	2	17
Repurchases of UGI Common Stock	0	(38)	(17)
Other	0	0	(7)
Net cash provided (used) by financing activities	48	(309)	639
Cash, cash equivalents and restricted cash increase (decrease)	(53)	13	41
Cash and cash equivalents:
Cash, cash equivalents and restricted cash at end of year	14	67	54
Cash, cash equivalents and restricted cash at beginning of year	67	54	13
Cash and cash equivalents (decrease) increase	(53)	13	41
Dividends from unconsolidated subsidiaries	$ 354	$ 352	$ 163

SCHEDULE II _ VALUATION AND Q_2

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2019
Allowance for doubtful accounts
Valuation and Qualifying Account
Balance at beginning of year	$ 42	$ 32	$ 35
Charged (credited) to costs and expenses	36	32	29
Other	(25)	(22)	(32)
Balance at end of year	53	42	32
Deferred tax assets valuation allowance
Valuation and Qualifying Account
Balance at beginning of year	105	91	117
Charged (credited) to costs and expenses	23	0	(26)
Other	10	14	0
Balance at end of year	$ 138	$ 105	$ 91