UGI (UGI) 10-K 20 Nov 20 2020 FY Annual report Financial data

Cover Page

Cover Page - USD ($)	12 Months Ended
	Sep. 30, 2020	Nov. 13, 2020	Mar. 31, 2020
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Sep. 30, 2020
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
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	UGI
Security Exchange Name	NYSE
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			$ 5,523,368,628
Entity Common Stock, Shares Outstanding		208,421,288
Entity Central Index Key	0000884614
Amendment Flag	false
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--09-30
Documents Incorporated by Reference	Portions of the Proxy Statement for the Annual Meeting of Shareholders to be held on January 29, 2021 are incorporated by reference into Part III of this Form 10-K.

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019
Current assets
Cash and cash equivalents	$ 336	$ 447
Restricted cash	21	64
Accounts receivable (less allowances for doubtful accounts of $42 and $32, respectively)	652	641
Accrued utility revenues	14	15
Income taxes receivable	80	0
Inventories	241	230
Derivative instruments	44	29
Prepaid expenses	96	72
Other current assets	59	68
Total current assets	1,543	1,566
Property, plant and equipment
Non-utility	6,393	6,135
Utility	4,265	3,938
Total property, plant and equipment	10,658	10,073
Accumulated depreciation	(3,698)	(3,385)
Total property, plant and equipment	6,960	6,688
Goodwill	3,518	3,456
Intangible assets, net	677	709
Utility regulatory assets	395	387
Derivative instruments	38	43
Other assets	854	498
Total assets	13,985	13,347
Current liabilities
Current maturities of long-term debt	53	24
Short-term borrowings	347	796
Accounts payable	475	439
Employee compensation and benefits accrued	162	133
Deposits and advances	204	168
Derivative instruments	64	85
Accrued interest	64	63
Other current liabilities	386	320
Total current liabilities	1,755	2,028
Noncurrent liabilities
Long-term debt	5,981	5,780
Deferred income taxes	640	541
Derivative instruments	59	48
Other noncurrent liabilities	1,413	1,123
Total liabilities	9,848	9,520
Commitments and contingencies (Note 17)
UGI Corporation stockholders’ equity:
UGI Common Stock, without par value (authorized – 450,000,000 shares; issued – 209,514,044 and 209,304,129 shares, respectively)	1,416	1,397
Retained earnings	2,908	2,653
Accumulated other comprehensive loss	(147)	(217)
Treasury stock, at cost	(49)	(16)
Total UGI Corporation stockholders’ equity	4,128	3,817
Noncontrolling interests	9	10
Total equity	4,137	3,827
Total liabilities and equity	$ 13,985	$ 13,347

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 42	$ 32
Common stock, shares authorized (in shares)	450,000,000	450,000,000
Common stock, shares issued (in shares)	209,514,044	209,304,129

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Income Statement [Abstract]
Revenues	$ 1,124	$ 1,199	$ 2,229	$ 2,007	$ 1,150	$ 1,364	$ 2,606	$ 2,200	$ 6,559	$ 7,320	$ 7,651
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)									3,149	4,323	4,075
Operating and administrative expenses									1,911	1,963	2,013
Impairment of Partnership tradenames and trademarks									0	0	75
Loss on disposals of Conemaugh and HVAC									54	0	0
Depreciation and amortization									484	448	455
Other operating income, net									(21)	(31)	(32)
Total costs and expenses									5,577	6,703	6,586
Operating income	69	174	362	377	(99)	9	539	168	982	617	1,065
Income (loss) from equity investees									27	9	4
Loss on extinguishments of debt				(4)					0	(6)
Other non-operating (expense) income, net									(20)	39	16
Interest expense									(322)	(258)	(230)
Income before income taxes									667	401	855
Income tax expense									(135)	(93)	(33)
Net income including noncontrolling interests	10	84	226	212	(131)	(46)	396	89	532	308	822
Deduct net income attributable to noncontrolling interests, principally in AmeriGas Partners prior to the AmeriGas Merger									0	(52)	(103)
Net income attributable to UGI Corporation	$ 9	$ 85	$ 226	$ 212	$ (52)	$ (2)	$ 246	$ 64	$ 532	$ 256	$ 719
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ 0.05	$ 0.41	$ 1.08	$ 1.01	$ (0.27)	$ (0.01)	$ 1.41	$ 0.37	$ 2.55	$ 1.44	$ 4.13
Diluted (in dollars per share)	$ 0.05	$ 0.41	$ 1.07	$ 1	$ (0.27)	$ (0.01)	$ 1.38	$ 0.36	$ 2.54	$ 1.41	$ 4.06
Weighted-average common shares outstanding:
Basic (in shares)	208,655	208,598	208,941	209,439	189,905	174,759	174,501	174,413	208,928	178,417	173,908
Diluted (in shares)	209,357	208,975	209,808	211,258	189,905	174,759	177,318	177,566	209,869	181,111	176,905

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Statement of Comprehensive Income [Abstract]
Net income including noncontrolling interests	$ 532	$ 308	$ 822
Net (losses) gains on derivative instruments (net of tax of $15, $3, and $(1), respectively)	(38)
Net (losses) gains on derivative instruments (net of tax of $15, $3, and $(1), respectively)		(7)	1
Reclassifications of net losses on derivative instruments (net of tax of $(4), $(2), and $(3), respectively)		2	4
Reclassifications of net losses on derivative instruments (net of tax of $(4), $(2), and $(3), respectively)	9
Foreign currency translation adjustments (net of tax of $12, $(13), and $(1), respectively)	15	(24)	(21)
Foreign currency gains (losses) on long-term intra-company transactions	84	(59)	(9)
Benefit plans, principally actuarial (losses) gains (net of tax of $1, $5, and $(5), respectively)	(3)	(13)	10
Reclassifications of benefit plans actuarial losses and net prior service benefit (net of tax of $(1), $(1), and $1, respectively)	3	1	(2)
Other comprehensive income (loss)	70	(100)	(17)
Comprehensive income including noncontrolling interests	602	208	805
Deduct comprehensive income attributable to noncontrolling interests, principally in AmeriGas Partners prior to the AmeriGas Merger	0	(52)	(103)
Comprehensive income attributable to UGI Corporation	$ 602	$ 156	$ 702

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Statement of Comprehensive Income [Abstract]
Net (losses) gains on derivative instruments, tax	$ 15
Net (losses) gains on derivative instruments, tax		$ 3	$ (1)
Reclassifications of net losses (gains) on derivative instruments, tax	4
Reclassifications of net losses (gains) on derivative instruments, tax		(2)	(3)
Foreign currency translation adjustments, tax	12	(13)	(1)
Benefit plans, principally actuarial (losses) gains, tax	1	5	(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, 2020	Sep. 30, 2019	Sep. 30, 2018
CASH FLOWS FROM OPERATING ACTIVITIES
Net income including noncontrolling interests	$ 532	$ 308	$ 822
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization	484	448	455
Deferred income tax expense (benefit), net	146	(43)	(69)
Provision for uncollectible accounts	32	29	36
Changes in unrealized gains and losses on derivative instruments	(81)	259	(133)
Impairment of Partnership tradenames and trademarks	0	0	75
Loss on disposals of Conemaugh and HVAC	54	0	0
Equity-based compensation expense	15	18	23
Other, net	(6)	6	7
Net change in:
Accounts receivable and accrued utility revenues	(18)	83	(148)
Income taxes receivable	(80)	0	0
Inventories	(5)	84	(37)
Utility deferred fuel costs, net of changes in unsettled derivatives	17	(30)	31
Accounts payable	3	(97)	65
Derivative instruments collateral received (paid)	22	(41)	4
Other current assets	38	45	(27)
Other current liabilities	(51)	9	(19)
Net cash provided by operating activities	1,102	1,078	1,085
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(655)	(705)	(574)
Acquisitions of businesses and assets, net of cash and restricted cash acquired	(16)	(1,362)	(187)
Other, net	22	12	12
Net cash used by investing activities	(649)	(2,055)	(749)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(273)	(200)	(177)
Distributions on AmeriGas Partners publicly held Common Units	0	(263)	(263)
Issuances of debt, net of issuance costs	209	2,412	124
Repayments of debt, including redemption premiums	(86)	(738)	(149)
Receivables Facility net (repayments) borrowings	(27)	44	(37)
(Decrease) increase in short-term borrowings	(422)	327	94
Issuances of UGI Common Stock	2	17	35
Repurchases of UGI Common Stock	(38)	(17)	(60)
Cash paid for AmeriGas Merger	0	(529)	0
Other	0	(11)	(5)
Net cash (used) provided by financing activities	(635)	1,042	(438)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	28	(16)	(5)
Cash, cash equivalents and restricted cash (decrease) increase	(154)	49	(107)
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of year	357	511	462
Cash, cash equivalents and restricted cash at beginning of year	511	462	569
Cash, cash equivalents and restricted cash (decrease) increase	(154)	49	(107)
Cash paid for:
Interest	311	248	222
Income taxes	$ 75	$ 74	$ 118

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Total UGI Corporation stockholders’ equity	Common stock, without par value	Retained earnings	Accumulated other comprehensive income (loss)	Treasury stock	Noncontrolling interests
Balance, beginning of year at Sep. 30, 2017			$ 1,189	$ 2,107	$ (93)	$ (39)	$ 578
Common stock issued:
Employee and director plans (including losses on treasury stock transactions), net of tax withheld			(2)
Employee and director plans, net of tax withheld						87
Equity-based compensation expense			14
Net income including noncontrolling interests	$ 822			719			103
Cash dividends on common stock ($1.31, $1.145, and $1.02 per share, respectively)				(177)
Losses on treasury stock transactions in connection with employee and director plans				(38)
Net (losses) gains on derivative instruments	1				1
Reclassification of net losses on derivative instruments	4				4
Benefit plans, principally actuarial (losses) gains	10				10
Reclassification of benefit plans actuarial losses and net prior service benefits	(2)				(2)
Foreign currency gains (losses) on long-term intra-company transactions	(9)				(9)
Foreign currency translation adjustments	(21)				(21)
Repurchases of common stock						(60)
Reacquired common stock – employee and director plans						(8)
Dividends and distributions							(263)
Other							1
Balance, end of year at Sep. 30, 2018	$ 4,101	$ 3,682	1,201	2,611	(110)	(20)	419
Balance, end of year (ASC 606) at Sep. 30, 2018				(7)
Common stock issued:
Accounting Standards Update [Extensible List]	us-gaap:AccountingStandardsUpdate201409Member
Employee and director plans (including losses on treasury stock transactions), net of tax withheld			11
Employee and director plans, net of tax withheld						24
Equity-based compensation expense			15
AmeriGas Merger-related adjustments			170				(199)
Net income including noncontrolling interests	$ 308			256			52
Cash dividends on common stock ($1.31, $1.145, and $1.02 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 (losses) gains on derivative instruments	(7)				(7)
Reclassification of net losses on derivative instruments	2				2
Benefit plans, principally actuarial (losses) gains	(13)				(13)
Reclassification of benefit plans actuarial losses and net prior service benefits	1				1
Foreign currency gains (losses) on long-term intra-company transactions	(59)				(59)
Foreign currency translation adjustments	(24)				(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	1,397	2,653	(217)	(16)	10
Common stock issued:
Employee and director plans (including losses on treasury stock transactions), net of tax withheld			2
Employee and director plans, net of tax withheld						8
Equity-based compensation expense			17
Net income including noncontrolling interests	532			532
Cash dividends on common stock ($1.31, $1.145, and $1.02 per share, respectively)				(273)
Losses on treasury stock transactions in connection with employee and director plans				(4)
Net (losses) gains on derivative instruments					(38)
Reclassification of net losses on derivative instruments	9				9
Benefit plans, principally actuarial (losses) gains	(3)				(3)
Reclassification of benefit plans actuarial losses and net prior service benefits	3				3
Foreign currency gains (losses) on long-term intra-company transactions	84				84
Foreign currency translation adjustments	15				15
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	$ 1,416	$ 2,908	$ (147)	$ (49)	$ 9

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Statement of Stockholders' Equity [Abstract]
Cash dividends on common stock (in dollars per share)	$ 1.31	$ 1.145	$ 1.02

Nature of Operations

Nature of Operations	12 Months Ended
	Sep. 30, 2020
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, energy marketing, midstream transmission, LNG storage, natural gas gathering and processing, natural gas production, electricity generation and energy services businesses primarily in the Mid-Atlantic region of the U.S., eastern Ohio and the panhandle of West Virginia. In July 2020, Energy Services acquired GHI, which is primarily focused on providing vehicle fleets with renewable natural gas by coordinating supply from a portfolio of sources throughout the country. UGID owns electricity generation facilities principally located in Pennsylvania. Energy Services and its subsidiaries’ storage, LNG and portions of its midstream transmission operations are subject to regulation by the FERC. UGI Utilities 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 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.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Sep. 30, 2020
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. 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. 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). Our investments in such entities totaled $256 and $242 at September 30, 2020 and 2019, respectively, and are included in “Other assets” on the Consolidated Balance Sheets. Our equity method investments primarily comprise PennEast and Pennant. Equity Method Investments Pennant. During Fiscal 2019, Energy Services completed the CMG Acquisition including CMG’s approximately 47% interest in Pennant. Pennant is accounted for as an equity method investment as we have the ability to exercise significant influence, but not control, over Pennant. Our investment in Pennant at September 30, 2020 and 2019 totaled $94 and $91, respectively. For additional information regarding the CMG Acquisition, see Note 5. 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. Affiliates of all members plan to be customers of the pipeline under 15-year contracts. PennEast is accounted for as an equity method investment as we have the ability to exercise significant influence, but not control, over PennEast. We are obligated to provide capital contributions based upon our ownership percentage. Our investment in PennEast at September 30, 2020 and 2019 totaled $96 and $85, respectively. 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. The Third Circuit subsequently denied PennEast’s petition for rehearing en banc. PennEast also filed a petition for declaratory order with the FERC regarding interpretation of the Natural Gas Act; the FERC issued an order favorable to PennEast’s position on January 30, 2020. PennEast filed a petition for a writ of certiorari to seek U.S. Supreme Court review of the Third Circuit decision on February 18, 2020. On June 29, 2020, the U.S. Supreme Court invited the U.S. Solicitor General to file a brief in the case expressing the views of the U.S. The ultimate outcome of these matters cannot be determined at this time, and could result in delays, additional costs, or the inability to move forward with the project, resulting in an impairment of all or a portion of our investment in PennEast. Effects of Regulation UGI Utilities accounts for the financial effects of regulation in accordance with the FASB’s guidance in ASC 980. In accordance with this guidance, incurred costs and estimated future expenditures that would otherwise be charged to expense are capitalized and recorded as regulatory assets when it is probable that the incurred costs or estimated future expenditures 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 regulator. 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 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 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 and the assessment of the collectability of specific amounts. 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. For additional information regarding the tax effects of the AmeriGas Merger, see Note 7. 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. The TCJA was enacted on December 22, 2017, and included a broad range of tax reform provisions affecting the Company, including, among other things, changes in the U.S. corporate income tax rate. The TCJA reduced the corporate income tax rate from 35% to 21% for tax years beginning after December 31, 2017. We were subject to a 24.5% blended U.S. federal income tax rate for Fiscal 2018 because our fiscal year contained the effective date of the rate change from 35% to 21%. In accordance with GAAP, at the date of enactment of the TCJA our federal deferred income taxes, including deferred income taxes related to items included in AOCI, were remeasured based upon the new corporate income tax rate. For our non-utility businesses, existing deferred income tax assets or liabilities were adjusted for the reduction in the corporate income tax rate and the adjustment recorded in the provision for income taxes. Our utility businesses were also required to adjust deferred income tax assets and liabilities for the change in income tax rates. However, because it was probable that the effect of the change in income tax rates on deferred income tax balances would be recovered or refunded in future rates, our rate-regulated utility businesses recorded a regulatory asset or liability associated with these deferred income tax assets and liabilities. For additional information regarding the impact of the TCJA and associated regulatory effects, see Notes 7 and 9. 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 and common stock awards. Shares used in computing basic and diluted earnings per share are as follows: (Thousands of shares) 2020 2019 2018 Weighted-average common shares outstanding for basic computation (a) 208,928 178,417 173,908 Incremental shares issuable for stock options and common stock awards (b) 941 2,694 2,997 Weighted-average common shares outstanding for diluted computation 209,869 181,111 176,905 (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) For Fiscal 2020 and Fiscal 2019, there were 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. 2020 2019 2018 2017 Cash and cash equivalents $ 336 $ 447 $ 452 $ 558 Restricted cash 21 64 10 11 Cash, cash equivalents and restricted cash $ 357 $ 511 $ 462 $ 569 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 Gas Utility and Electric Utility inventories; specific identification for appliances; and the FIFO method for all other inventories. 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. We record depreciation expense on non-utility plant and equipment on a straight-line basis over estimated economic useful lives. At September 30, 2020, estimated useful lives by asset type were as follows: Asset Type Minimum Estimated Useful Life Maximum Estimated Useful Life Buildings and improvements 10 40 Equipment, primarily cylinders and tanks 5 30 Electricity generation facilities 25 40 Pipeline and related assets 25 40 Transportation equipment and office furniture and fixtures 3 10 Computer software 1 10 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. The average composite depreciation rates at our Gas Utility and Electric Utility were as follows: 2020 2019 2018 Gas Utility 2.5 % 2.2 % 2.3 % Electric Utility 2.2 % 2.1 % 2.2 % UGI Utilities’ IT costs associated with major IT system installations, conversions and improvements, such as software training, data conversion, business process reengineering costs, preliminary project stage costs and cloud computing, are deferred as a regulatory asset and included as a component of property, plant and equipment. As of September 30, 2020 and 2019, such costs included as a component of property, plant and equipment and not yet requested in a rate proceeding were not material. UGI Utilities amortizes computer software and related IT system installation costs on a straight-line basis over expected periods of benefit not exceeding 15 years once the installed software is ready for its intended use. We classify amortization of computer software and related IT system installation costs included in property, plant and equipment as depreciation expense. Depreciation expense totaled $416, $389 and $397 for Fiscal 2020, Fiscal 2019 and Fiscal 2018, respectively. For property subject to cost of service rate regulation including substantially all of UGI Utilities depreciable utility plant and equipment, upon retirement we charge the original cost to accumulated depreciation for financial accounting purposes. Costs incurred to retire utility plant and equipment, net of salvage, are recorded in regulatory assets and amortized over five years, consistent with prior ratemaking treatment. 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. In April 2018, the Partnership’s senior management approved a plan to discontinue the use of indefinite-lived tradenames and trademarks associated with the Partnership’s January 2012 acquisition of Heritage Propane over a period of approximately three years. As a result, the Partnership recorded a non-cash, pre-tax impairment charge of $75 during Fiscal 2018 which is reflected in “Impairment of Partnership tradenames and trademarks” on the 2018 Consolidated Statement of Income, and is amortizing the remaining fair value of these tradenames and trademarks of $8 over their estimated period of benefit of three years. 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, 2020 and 2019, and no provisions for goodwill impairments were recognized for all periods presented. For further information on our goodwill and intangible assets, see Note 12. Impairment of Long-Lived Assets Impairment testing for long-lived assets (or an asset group) is required when circumstances indicate that such assets may be impaired. If it is determined that a triggering event has occurred, we perform a recoverability test based upon estimated undiscounted cash flow projections expected to be realized over the remaining useful life of the long-lived asset. If the undiscounted cash flows used in the recoverability test are less than the long-lived asset's carrying amount, we determine its fair value. If the fair value is determined to be less than its carrying amount, the long-lived asset is reduced to its estimated fair value and an impairment loss is recognized in an amount equal to such shortfall. When determining whether a long-lived asset has been impaired, management groups assets at the lowest level that has identifiable cash flows. No material provisions for impairments of long-lived assets were recorded during Fiscal 2019 or Fiscal 2018. See Note 5 for further information on the losses associated with the dispositions of Conemaugh and HVAC during Fiscal 2020. Debt Issuance Costs We defer and amortize debt issuance costs and debt premiums and discounts over the expected lives of the respective debt issues considering maturity dates. Deferred debt issuance costs associated with long-term debt are reflected as a direct deduction from the carrying amount of such debt. Deferred debt issuance costs associated with revolving credit facilities reflected as short-term borrowings are classified as “ Other assets ” on our Consolidated Balance Sheets. Amortization of debt issuance costs is reported as interest expense. Unamortized costs associated with redemptions of debt prior to their stated maturity are generally recognized and recorded in “Loss on extinguishments of debt” on the Consolidated Statements of Income. As permitted by regulatory authorities, gains or losses resulting from refinancings of UGI Utilities’ debt are deferred and amortized over the lives of the new issuances. Leases Effective October 1, 2019, the Company adopted ASU No. 2016-02 We adopted this new guidance using the modified retrospective transition method. Amounts and disclosures related to periods prior to October 1, 2019 have not been restated and continue to be reported in accordance with ASC 840. We elected to apply the following practical expedients in accordance with the guidance upon adoption: • Short-term leases: We did not recognize short-term leases (term of 12 months or less) on the balance sheet; • Easements: We did not re-evaluate existing land easements that were not previously accounted for as leases; and • Other: We did not reassess the classification of expired or existing contracts or determine whether they are or contain a lease. We also did not reassess whether initial direct costs qualify for capitalization under ASC 842. Upon adoption, we recorded ROU assets and lease liabilities of $452 related to our operating leases. Our accounting for finance leases remained substantially unchanged. There were no cumulative-effect adjustments made to retained earnings as of October 1, 2019. The adoption did not have a significant impact on our consolidated statements of income or cash flows. See Note 16 for additional disclosures regarding our leases. 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 $300 and $280 at September 30, 2020 and 2019, 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. UGI Utilities 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

Accounting Changes

Accounting Changes	12 Months Ended
	Sep. 30, 2020
Accounting Standards Update and Change in Accounting Principle [Abstract]
Accounting Changes	Note 3 — Accounting Changes New Accounting Standards Adopted in Fiscal 2020 Derivatives and Hedging. Effective October 1, 2019, the Company adopted ASU No. 2017-12, “Targeted Improvements to Accounting for Hedging Activities.” This ASU amends and simplifies existing guidance to allow companies to more accurately present the economic effects of risk management activities in the financial statements. For cash flow and net investment hedges as of the adoption date, the guidance required a modified retrospective approach. The amended presentation and disclosure guidance was required prospectively. The adoption of the new guidance did not have a material impact on our consolidated financial statements. Leases. Effective October 1, 2019, the Company adopted new accounting guidance for leases in accordance with ASC 842. See Notes 2 and 16 for a detailed description of the impact of the new guidance and related disclosures. Reference Rate Reform. In March 2020, the FASB issued ASU 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting.” This ASU provides entities with temporary optional guidance to ease potential accounting burdens to transition away from LIBOR or other reference rates that are expected to be discontinued and replaced with alternative reference rates. This ASU applies to all entities that have contracts, hedging relationships and other transactions affected by reference rate reform. The provisions in this ASU, among other things, simplify contract modification accounting and allow hedging relationships affected by reference rate reform to continue. ASU 2020-04 is effective upon issuance and entities are able to apply the amendments prospectively through December 31, 2022. During the third quarter of Fiscal 2020, the Company elected certain optional expedients related to all outstanding cash flow hedging relationships and such elections did not have a material impact on our consolidated financial statements. New Accounting Standard Adopted Effective October 1, 2020 Credit Losses. In June 2016, the FASB issued ASU 2016-13, “Measurement of Credit Losses on Financial Instruments. ” 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. Further, the new current expected credit loss model affects how entities estimate their allowance for losses related to receivables that are current with respect to their payment terms. Effective October 1, 2020, the Company adopted this ASU, as updated, using a modified retrospective transition approach. The adoption of the new guidance did not have a material impact on our consolidated financial statements. Accounting Standard Not Yet Adopted 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. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2021 (Fiscal 2022). Early adoption is permitted. The Company is in the process of assessing the impact on our consolidated financial statements from the adoption of the new guidance and determining 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, 2020
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 PAPUC 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 and DS costs. Customers may choose to purchase their natural gas and electricity from Gas Utility or Electric Utility, 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. Gas Utility also sells excess 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 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. Fees 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. In addition, UGI International provides system balancing and procurement services to other energy marketers in the Netherlands. 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. In addition to providing natural gas and electricity to end-user customers, our energy marketing business in the Netherlands has contracts with third-party natural gas and electricity marketers to provide BRP services in the electricity and natural gas markets in the Netherlands. These contracts are typically multi-year agreements and include full BRP services that include, among other things, estimating, procuring and scheduling all energy requirements to meet third-party marketers’ needs, or provide more limited system procurement and balancing services. The amount of revenue recognized from our BRP customers is based upon the amount of energy delivered with respect to these agreements, and the level of BRP services provided. We typically receive payments from our BRP customers one month in advance of our performing the related services. Amounts received in advance are deferred on the balance sheet as contract liabilities. Based upon an evaluation of the terms and conditions of the BRP contracts and our ability to control the goods or services provided to the third-party marketers, in addition to other factors, we are considered a principal in these contracts and are required to record the revenue associated with the sale of energy to the third-party energy marketers on a gross basis. We record the associated revenue ratably over time, typically monthly, as the performance obligations are satisfied. 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 Partners 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. 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, 2020 and 2019. 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 $115 and $114 at September 30, 2020 and 2019, respectively, and are primarily included in “Deposits and Advances” on the Consolidated Balance Sheets. Revenue recognized during Fiscal 2020 and Fiscal 2019 from the amount included in contract liabilities at September 30, 2019 and October 1, 2018 was $89 and $91, respectively. Revenue Disaggregation The following table presents our disaggregated revenues by reportable segment during Fiscal 2020 and Fiscal 2019: 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, 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). 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, 2020, Midstream & Marketing and UGI Utilities expect to record approximately $1.9 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, 2020
Business Combinations [Abstract]
AmeriGas Merger, Acquisitions and Dispositions	Note 5 — AmeriGas Merger, Acquisitions and Dispositions 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. This deferred tax asset is included in “Deferred income taxes” on the September 30, 2019 Consolidated Balance Sheet. 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. For further information on the effects of the AmeriGas Merger on equity-based awards, see Note 14. 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. For additional information on the tax effects of the AmeriGas Merger, see Note 7. 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 is consistent with our growth strategies, including expanding our midstream natural gas gathering and processing assets within the Marcellus and Utica Shale production regions. The CMG Acquisition was funded with cash from borrowings under the Energy Services Term Loan and the UGI Corporation Senior Credit Facility and cash on hand. We refer to CMG and its equity interest in Pennant as “UGI Appalachia.” 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, 2017 was not material to the Company’s revenues or net income for Fiscal 2019 and Fiscal 2018. Other Acquisitions As previously mentioned, in July 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. During Fiscal 2018, UGI International acquired UniverGas, an LPG distribution business with operations in northern and central regions of Italy, and AmeriGas Propane acquired two retail propane distribution businesses. Total cash paid and liabilities incurred in connection with these acquisitions were as follows: 2020 2019 2018 Midstream & Marketing UGI International Midstream & Marketing AmeriGas Propane UGI International Total cash paid $ 16 $ 49 $ 15 $ 10 $ 122 Liabilities incurred 7 — — 3 — Total purchase price $ 23 $ 49 $ 15 $ 13 $ 122 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. During Fiscal 2018, Midstream & Marketing acquired (1) 60 miles of natural gas gathering lines and related dehydration and compression equipment, and a smaller natural gas gathering system, both located in northern Pennsylvania and (2) a 44-megawatt, natural gas-fired peaking turbine located on its Hunlock Station site in northeast Pennsylvania, for total cash consideration of $70. 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. 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. During the third quarter of Fiscal 2020, we 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 sale was completed on September 30, 2020. HVAC. In September 2020, Enterprises entered into an agreement to sell the 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. 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. During the fourth quarter of Fiscal 2020, we 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 sale was completed on September 30, 2020.

Debt

Debt	12 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Debt	Note 6 — Debt Significant Financing Activities during Fiscal 2020 Energy Services. On March 6, 2020, Energy Services entered into the Energy Services 2020 Credit Agreement, as borrower, with a group of lenders. The Energy Services 2020 Credit Agreement amends and restates the Energy Services Credit Agreement. The Energy Services 2020 Credit Agreement provides for borrowings up to $260, including a $50 sublimit for letters of credit. Energy Services may request an increase in the amount of loan commitments under the Energy Services 2020 Credit Agreement to a maximum aggregate amount of $325, subject to certain terms and conditions. Borrowings under the Energy Services 2020 Credit Agreement can be used to fund acquisitions and investments and for general corporate purposes. The Energy Services 2020 Credit Agreement is scheduled to expire in March 2025. Borrowings under the Energy Services 2020 Credit Agreement bear interest at either (i) the Alternate Base Rate plus a margin or (ii) the Adjusted LIBOR plus a margin. The Alternate Base Rate, as defined, is the highest of (a) the prime rate, (b) the federal funds rate plus 0.50%, and (c) the Adjusted LIBOR for a one-month interest period plus 1% but in no event shall the Alternative Base Rate be less than 1%. The margins on borrowings ranges from 0.75% to 2.75% and are dependent upon Energy Services’ ratio of Consolidated Total Indebtedness to Consolidated EBITDA, as defined. The initial margin on the Alternate Base Rate and Adjusted LIBOR on borrowings under the Energy Services 2020 Credit Agreement were 1.50% and 2.50%, respectively. The Energy Services 2020 Credit Agreement includes customary provisions with respect to the replacement of LIBOR. UGI Utilities. On April 16, 2020, UGI Utilities issued in a private placement $150 of UGI Utilities 3.12% Senior Notes due April 16, 2050 pursuant to a Note Purchase Agreement dated March 19, 2020, between UGI Utilities and certain note purchasers. The UGI Utilities 3.12% Senior Notes are unsecured and rank equally with UGI Utilities’ existing outstanding senior debt. The net proceeds from the issuance of the UGI Utilities 3.12% Senior Notes were used to reduce short-term borrowings and for general corporate purposes. 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, 2020 and 2019, 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 UGI Corporation Senior Credit Facility) are classified as “Short-term borrowings” on the Consolidated Balance Sheets. Expiration Date Total Capacity Borrowings Outstanding Letters of Credit and Guarantees Outstanding Available Borrowing Capacity Weighted Average Interest Rate - End of Year September 30, 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 (d) June 2024 $ 350 $ 141 $ — $ 209 1.12 % UGI Corporation (e) August 2024 $ 300 $ 300 $ — $ — 2.41 % September 30, 2019 AmeriGas OLP (a) December 2022 $ 600 $ 328 $ 63 $ 209 4.50 % UGI International, LLC (b) October 2023 € 300 € 193 € — € 107 3.64 % Energy Services (c) March 2021 $ 200 $ 45 $ — $ 155 6.25 % UGI Utilities (d) June 2024 $ 350 $ 166 $ — $ 184 3.00 % UGI Corporation (e) August 2024 $ 300 $ 300 $ — $ — 4.55 % (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. At September 30, 2019, the amount outstanding consisted of USD-denominated borrowings of $210. (c) The Energy Services 2020 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 Credit Agreement includes a $100 sublimit for letters of credit. (e) At September 30, 2020 and 2019, management intended to maintain a substantial portion of amounts outstanding under the UGI Corporation Senior Credit Facility beyond twelve months from the respective balance sheet dates. As such, borrowings outstanding are classified as “Long-term debt” on the Consolidated Balance Sheets. In October 2020, the Company repaid $30 of such borrowings and classified these repayments as “Current maturities of long-term debt” on the 2020 Consolidated Balance Sheet. The UGI Corporation Senior Credit Facility includes a $10 sublimit for letters of credit. Energy Services Receivables Facility. Energy Services has a Receivables Facility with an issuer of receivables-backed commercial paper currently scheduled to expire in October 2021. 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: 2020 2019 2018 Trade receivables transferred to ESFC during the year $ 1,046 $ 1,373 $ 1,280 ESFC trade receivables sold to the bank during the year $ 182 $ 179 $ 193 ESFC trade receivables - end of year (a) $ 50 $ 55 $ 65 (a) At September 30, 2020 and 2019, the amounts of ESFC trade receivables sold to the bank were $19 and $46, respectively, and are reflected as “Short-term borrowings” on the Consolidated Balance Sheets. Long-term Debt Long-term debt comprises the following at September 30: 2020 2019 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 (a) 5 14 Unamortized debt issuance costs (20) (24) Total AmeriGas Propane 2,560 2,565 UGI International: 3.25% Senior Notes due November 2025 410 382 UGI International, LLC variable-rate term loan due October 2023 (b) 352 327 Other 23 18 Unamortized debt issuance costs (7) (8) Total UGI International 778 719 Midstream & Marketing: Energy Services variable-rate term loan due through August 2026 (c) 691 698 Other (d) 41 1 Unamortized discount and debt issuance costs (12) (12) Total Energy Services 720 687 UGI Utilities: Senior Notes: 4.12%, due September 2046 200 200 4.98%, due March 2044 175 175 3.12% due April 2050 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 Medium-Term Notes: 6.13%, due October 2034 20 20 6.50%, due August 2033 20 20 Variable-rate term loan due through October 2022 (e) 108 114 Other 3 5 Unamortized debt issuance costs (5) (5) Total UGI Utilities 1,121 979 UGI Corporation: UGI Corporation revolving credit facility maturing August 2024 (f) 300 300 UGI Corporation variable-rate term loan due August 2022 (g) 300 300 UGI Corporation variable-rate term loan due through August 2024 (h) 250 250 Unamortized debt issuance costs (3) (4) Total UGI Corporation 847 846 Other 8 8 Total long-term debt 6,034 5,804 Less: current maturities (53) (24) Total long-term debt due after one year $ 5,981 $ 5,780 (a) At September 30, 2019, such amount includes Heritage Operating, L.P. Senior Secured Notes. The effective interest rate on the Heritage Operating, L.P. Senior Secured Notes was 6.75%. These notes were collateralized by AmeriGas OLP’s receivables, contracts, equipment, inventory, general intangibles and cash. (b) The effective interest rate on the term loan was 2.04% at both September 30, 2020 and 2019. We have entered into pay fixed, receive variable interest rate swaps to effectively fix the underlying variable rate on these borrowings. (c) At September 30, 2020 and 2019, the effective interest rates on the term loan were 5.30% and 5.79%, respectively. 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. 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. (d) Amounts include finance lease liabilities recognized as a result of the adoption of ASU No. 2016-02. For additional information, see Note 2 and Note 16 to the Consolidated Financial Statements. (e) At September 30, 2020 and 2019, the effective interest rates on this term loan were 4.00% and 3.05%, 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. (f) At September 30, 2020 and 2019, the effective interest rates on credit facility borrowings were 2.41% and 4.55%, 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. (g) At September 30, 2020 and 2019, the effective interest rate on this term loan 3.51% and 4.30%, respectively. We have entered into pay-fixed, receive variable interest rate swaps to effectively fix the underlying variable rate on these borrowings. (h) At September 30, 2020 and 2019, the effective interest rates on this term loan were 3.50% and 4.55%, 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. Scheduled principal repayments of long-term debt for each of the next five fiscal years ending September 30 are as follows: 2021 2022 2023 2024 2025 AmeriGas Propane $ 3 $ 2 $ — $ 675 $ 700 UGI International 1 22 — 352 — Midstream & Marketing 10 7 7 7 7 UGI Utilities 8 7 96 — — UGI Corporation (a) 30 300 38 482 — Other 1 1 6 — — Total $ 53 $ 339 $ 147 $ 1,516 $ 707 (a) In October 2020, the Company repaid $30 of such borrowings and has classified these repayments as “Current maturities of long-term debt” on the 2020 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. AmeriGas Propane . The AmeriGas Propane OLP Credit Agreement requires that AmeriGas OLP and AmeriGas Partners maintain ratios of total indebtedness to EBITDA, as defined, below certain thresholds. In addition, the Partnership must maintain a minimum ratio of EBITDA to interest expense, as defined and as calculated on a rolling four-quarter basis. Generally, as long as no default exists or would result therefrom, AmeriGas OLP is permitted to make cash distributions not more frequently than quarterly in an amount not to exceed available cash, as defined, for the immediately preceding calendar quarter. Under the AmeriGas Partners Senior Notes Indentures, AmeriGas Partners is generally permitted to make cash distributions equal to available cash, as defined, as of the end of the immediately preceding quarter, if certain conditions are met. At September 30, 2020, these restrictions did not limit the amount of Available Cash. See Note 15 for the definition of Available Cash included in the Partnership Agreement. UGI International. The UGI International Credit Facilities Agreement requires UGI International not to exceed a ratio of consolidated total net indebtedness to consolidated EBITDA, as defined, of 3.85 to 1.00. Energy Services . The Energy Services Term Loan requires that Energy Services and subsidiaries maintain a minimum ratio of consolidated EBITDA to debt service, as defined, of 1.10 to 1.00. The Energy Services 2020 Credit Agreement requires Energy Services and subsidiaries not to exceed a ratio of total indebtedness to EBITDA, as defined, of 4.00 to 1.00 and maintain a minimum ratio of Consolidated EBITDA to Consolidated Interest Expense, as defined and as calculated on a quarterly basis, of 3.50 to 1.00. UGI Utilities. The UGI Utilities Credit Agreement, certain of UGI Utilities’ Senior Notes and the Utilities Term Loan require UGI Utilities not to exceed a ratio of consolidated debt to consolidated total capital, as defined, of 0.65 to 1.00. UGI Corporation. The UGI Corporation Senior Credit Facility requires that UGI maintain a ratio of consolidated EBITDA to consolidated interest expense, as defined and as calculated on a rolling four-quarter basis, above 3.50 to 1.00. In addition, UGI may not exceed a ratio of consolidated net indebtedness to consolidated EBITDA, as defined and as calculated on a rolling four-quarter basis, of 4.50 to 1.00 (declining over time to 4.00 to 1.00). Restricted Net Assets At September 30, 2020, 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 $2,200.

Income Taxes

Income Taxes	12 Months Ended
	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Note 7 — Income Taxes Income before income taxes comprises the following: 2020 2019 2018 Domestic $ 424 $ 330 $ 576 Foreign 243 71 279 Total income before income taxes $ 667 $ 401 $ 855 The provisions for income taxes consist of the following: 2020 2019 2018 Current expense (benefit): Federal $ (85) $ 52 $ (2) State 4 14 26 Foreign 70 70 78 Total current (benefit) expense (11) 136 102 Deferred expense (benefit): Federal 135 3 (78) State 19 4 7 Foreign (8) (50) 2 Total deferred expense (benefit) 146 (43) (69) Total income tax expense $ 135 $ 93 $ 33 Federal income taxes for Fiscal 2019 and Fiscal 2018 are net of foreign tax credits of $10 and $13, respectively. There were no foreign tax credits utilized in Fiscal 2020. A reconciliation from the U.S. federal statutory tax rate to our effective tax rate is as follows: 2020 2019 2018 U.S. federal statutory tax rate 21.0 % 21.0 % 24.5 % Difference in tax rate due to: Effect of U.S. tax legislation (4.7) 0.2 (20.9) Effect of tax rate changes - International 0.3 (0.5) (2.1) Noncontrolling interests not subject to tax — (2.7) (3.0) State income taxes, net of federal benefit 2.8 3.6 2.9 Valuation allowance adjustments — — 1.1 Effects of foreign operations 1.3 1.8 3.1 Excess tax benefits on share-based payments (0.2) (1.0) (1.1) Other, net (0.3) 0.7 (0.7) Effective tax rate 20.2 % 23.1 % 3.8 % 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 loss generated in Fiscal 2020 to be carried back to Fiscal 2015. The carryback of our Fiscal 2020 U.S. federal tax loss in a 21% rate environment to offset taxable income in Fiscal 2015 in a 35% rate environment generated an incremental $32 benefit in the current year. The expected $80 refund is included in “Income taxes receivable” on the 2020 Consolidated Balance Sheet. 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 items of 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 2020. On December 22, 2017, the TCJA was enacted into law. Among the significant changes resulting from the law, the TCJA reduced the U.S. federal income tax rate from 35% to 21%, effective January 1, 2018, created a territorial tax system with a one-time mandatory “toll tax” on previously un-repatriated foreign earnings, and allowed for immediate capital expensing of certain qualified property. It also applied restrictions on the deductibility of interest expense, eliminated bonus depreciation for regulated utilities and certain FERC-regulated property beginning in Fiscal 2019 and applied a broader application of compensation limitations. As a result of the TCJA, we reduced our net deferred income tax liabilities in Fiscal 2018 by $384 due to the remeasuring of our existing federal deferred income tax assets and liabilities as of the date of the enactment of the TCJA on December 22, 2017. Because most of the reduction to UGI Utilities’ net deferred income taxes related to regulated utility plant assets, most of UGI Utilities’ reduction in deferred income taxes was not recognized immediately in income tax expense. In accordance with GAAP as determined by ASC 740, we are required to record the effects of tax law changes in the period enacted. Our results for Fiscal 2018 contained provisional estimates of the impact of the TCJA as such amounts used estimates for tax returns that had not yet been filed and because estimated amounts could have been impacted by future regulatory and accounting guidance if and when issued. As permitted by SEC Staff Bulletin No. 118, adjustments to provisional amounts recorded in prior periods were made during Fiscal 2019 and were not material. In Fiscal 2018, we were subject to a blended federal tax rate of 24.5% because our fiscal year contained the effective date of the rate change from 35% to 21%. The effects of the tax law changes on Fiscal 2018 results (excluding the remeasurement impact described above) decreased income tax by $52. In Fiscal 2018, earnings of the Company’s foreign subsidiaries were generally subject to U.S. taxation upon repatriation to the U.S. and the Company’s tax provisions reflected the related incremental U.S. tax except for certain foreign subsidiaries whose unremitted earnings were considered to be indefinitely reinvested. No deferred tax liability had been recognized with regard to remittance of those earnings because of the availability of U.S. foreign tax credits made it likely that no U.S. tax would be due if such earnings were repatriated. Upon enactment of the TCJA, substantially all prior unrepatriated earnings were subjected to U.S. tax under the transition tax rules. The transition tax was immaterial to the Company and we generally expect to have the ability to repatriate prior unrepatriated earnings without material U.S. federal tax cost. Our Fiscal 2020 and Fiscal 2019 effective tax rate was 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. Fiscal 2020 and Fiscal 2019 tax expense includes $2 and $4, respectively, of GILTI and Branch taxes that are treated as current period costs and carry no related deferred taxes. Pennsylvania utility ratemaking practice permits the flow through to ratepayers of state tax benefits resulting from accelerated tax depreciation. For Fiscal 2020, Fiscal 2019 and Fiscal 2018, the beneficial effects of state tax flow through of accelerated depreciation reduced income tax expense by $11, $7 and $4, respectively. Deferred tax liabilities (assets) comprise the following at September 30: 2020 2019 Excess book basis over tax basis of property, plant and equipment $ 830 $ 805 Utility regulatory assets 112 108 Intangible assets and goodwill 107 71 Other 32 7 Gross deferred tax liabilities 1,081 991 Investment in AmeriGas Partners (216) (304) Pension plan liabilities (48) (50) Employee-related benefits (46) (44) Operating loss carryforwards (34) (21) Foreign tax credit carryforwards (81) (81) Utility regulatory liabilities (94) (94) Derivative instruments (26) (15) Utility environmental liabilities (16) (15) Other (54) (34) Gross deferred tax assets (615) (658) Deferred tax assets valuation allowance 105 91 Net deferred tax liabilities $ 571 $ 424 As a result of the AmeriGas Merger in Fiscal 2019, we acquired all of the equity interests of AmeriGas Partners. In exchange for the interest acquired from the public, we issued stock and paid cash having a total implied fair value of $2,228. The transaction represents a taxable exchange for which we received a step-up in the tax basis in the underlying assets acquired. A gross deferred tax asset of $2,030 related to the book tax basis difference in this investment was recorded in Fiscal 2019 through equity in accordance with ASC 810. We evaluated the realizability of the resulting net deferred tax asset position of $512 assessing the available positive and negative evidence. As the taxable temporary differences of the Partnership’s tax depreciation in excess of book depreciation reverses, the associated deferred taxes are expected to be fully realized. In December 2017, the French Parliament approved the December 2017 French Finance Bills. One impact of the December 2017 French Finance Bills was an increase in the Fiscal 2018 corporate income tax rate in France from 34.4% to 39.4%. The December 2017 French Finance Bills also included measures to gradually reduce the corporate income tax rate to 25.8%, effective for fiscal years starting after January 1, 2022 (Fiscal 2023). In July 2019, the French Parliament enacted legislation retroactively increasing the corporate income tax rate for tax years beginning in 2019 that had previously been reduced by the December 2017 French Finance Bills. As a result, the Fiscal 2020 tax rate remained at 34.43% for Fiscal 2019. The impact on deferred income tax liabilities increased income tax expense by $2 during Fiscal 2019. In December 2019, the French Parliament enacted additional legislation revising the rates enacted for Fiscal 2021 and Fiscal 2022, but retained the corporate income tax rate of 25.8%, effective for fiscal years starting after January 1, 2022 (Fiscal 2023). The impact on deferred income tax liabilities was not material during Fiscal 2020 . As a result of the December 2017 French Finance Bills, during Fiscal 2018, the Company reduced its net French deferred income tax liabilities and recognized an estimated deferred tax benefit of $12 to reflect the estimated impact of the corporate income tax rate reductions that will be implemented through Fiscal 2023. The Company’s Fiscal 2018 effective income tax rate reflects the impact of the higher Fiscal 2018 income tax rate in France as a result of the December 2017 French Finance Bills, which increased income tax expense for the year by approximately $1. At September 30, 2020, foreign net operating loss carryforwards principally relating to Flaga and certain subsidiaries of UGI France totaled $11 and $14, respectively, with no expiration dates. We have state net operating loss carryforwards primarily relating to certain subsidiaries that approximate $393 and expire through 2040. We also have federal operating loss carryforwards of $12 for certain operations of AmeriGas Propane that expire through 2036. At September 30, 2020, deferred tax assets relating to operating loss carryforwards include $2 for Flaga, $5 for certain subsidiaries of UGI France, $2 for AmeriGas Propane and $25 for certain other subsidiaries. Valuation allowances against deferred tax assets exist for foreign tax credit carryforwards, net operating loss carryforwards of foreign subsidiaries and a notional interest deduction. The valuation allowance for all deferred tax assets increased by $14 in Fiscal 2020 largely related to a $16 increase in a notional interest deduction carryover. The valuation allowance for deferred tax assets decreased by $26 in Fiscal 2019 consisting primarily of the release of $25 of valuation allowances on foreign tax credits that expired in Fiscal 2019. 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 2016 tax year, our Austrian tax returns are settled through 2016 and our other European tax returns are effectively settled for various years from 2012 to 2016. 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. As of September 30, 2020, we have unrecognized income tax benefits totaling $4 including related accrued interest. If these unrecognized tax benefits were subsequently recognized, $4 would be recorded as a benefit to income taxes on the Consolidated Statement of Income and, therefore, would impact the reported effective tax rate. Generally, a net reduction in unrecognized tax benefits could occur because of the expiration of the statute of limitations in certain jurisdictions or as a result of settlements with tax authorities. The expected change in unrecognized tax benefits and related interest in the next twelve months as the result of the expiration of certain statutes of limitation is not material. A reconciliation of the beginning and ending amounts of unrecognized tax benefits is as follows: 2020 2019 2018 Unrecognized tax benefits — beginning of year $ 11 $ 12 $ 12 Additions for tax positions of the current year 2 1 2 Additions for tax positions taken in prior years — — 1 Settlements with tax authorities/statute lapses (9) (2) (3) Unrecognized tax benefits — end of year $ 4 $ 11 $ 12

Employee Retirement Plans

Employee Retirement Plans	12 Months Ended
	Sep. 30, 2020
Retirement Benefits [Abstract]
Employee Retirement Plans	Note 8 — Employee Retirement Plans Defined Benefit Pension and Other Postretirement Plans The U.S. Pension Plan is a defined benefit pension plan for employees hired prior to January 1, 2009, of UGI, UGI Utilities, and certain of UGI’s other domestic wholly owned subsidiaries. U.S. Pension Plan benefits are based on years of service, age and employee compensation. We also provide postretirement health care benefits to certain retirees and postretirement life insurance benefits to certain U.S. active and retired employees. 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. The following table provides a reconciliation of the PBOs of our pension plans (the U.S. Pension Plan and the UGI International pension plans), the ABOs of our other postretirement benefit plans, plan assets, and the funded status of pension and other postretirement plans as of September 30, 2020 and 2019. 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 Other Postretirement 2020 2019 2020 2019 Change in benefit obligations: Benefit obligations — beginning of year $ 750 $ 669 $ 23 $ 19 Service cost 11 10 — — Interest cost 23 27 1 1 Actuarial loss 27 89 1 4 Curtailments (2) (1) — — Settlements — (13) — — Foreign currency 3 (3) — — Benefits paid (30) (28) (1) (1) Benefit obligations — end of year $ 782 $ 750 $ 24 $ 23 Change in plan assets: Fair value of plan assets — beginning of year $ 547 $ 563 $ 16 $ 15 Actual gain on plan assets 53 13 2 1 Foreign currency 1 (1) — — Employer contributions 13 12 — — Settlements — (13) — — Benefits paid (29) (27) (1) — Fair value of plan assets — end of year $ 585 $ 547 $ 17 $ 16 Funded status of the plans — end of year $ (197) $ (203) $ (7) $ (7) Assets (liabilities) recorded in the balance sheet: Assets in excess of liabilities — included in other noncurrent assets $ — $ — $ 3 $ 3 Unfunded liabilities — included in other noncurrent liabilities (197) (203) (10) (10) Net amount recognized $ (197) $ (203) $ (7) $ (7) Amounts recorded in UGI Corporation stockholders’ equity (pre-tax): Prior service cost (benefit) $ 1 $ 1 $ (1) $ (1) Net actuarial loss 24 26 — — Total $ 25 $ 27 $ (1) $ (1) Amounts recorded in regulatory assets and liabilities (pre-tax): Prior service cost $ — $ 1 $ — $ — Net actuarial loss 174 177 1 1 Total $ 174 $ 178 $ 1 $ 1 In Fiscal 2020 and Fiscal 2019, the change in the pension plans’ PBO due to actuarial gains and losses is principally the result of changes in discount rates. The change in the pension plans’ PBO in Fiscal 2019 also reflects a settlement resulting from the conversion of a defined benefit pension plan to a defined contribution plan in the Netherlands. In Fiscal 2021, the estimated amount that will be amortized from UGI Stockholders’ equity and regulatory assets into net periodic benefit cost is approximately $15, the majority of which represents net actuarial losses, primarily associated with the U.S. Pension Plan. Actuarial assumptions for our U.S. 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 Plan Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 Weighted-average assumptions: Discount rate – benefit obligations 2.90 % 3.30 % 4.40 % 3.00 % 3.30 % 4.40 % Discount rate – benefit cost 3.30 % 4.40 % 4.00 % 3.30 % 4.40 % 4.00 % Expected return on plan assets 7.20 % 7.30 % 7.40 % 5.00 % 5.00 % 5.00 % Rate of increase in salary levels 3.25 % 3.25 % 3.25 % 3.25 % 3.25 % 3.25 % The ABO for the U.S. Pension Plan was $687 and $659 as of September 30, 2020 and 2019, respectively. 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 (expense) income, net” on the Consolidated Statements of Income. Other postretirement benefit cost was not material for all periods presented. Net periodic pension cost include the following components: Pension Benefits 2020 2019 2018 Service cost $ 11 $ 10 $ 11 Interest cost 23 27 26 Expected return on assets (38) (36) (35) Curtailment gain (1) — — Amortization of: Prior service cost 1 — 1 Actuarial loss 15 8 13 Net cost $ 11 $ 9 $ 16 It is our general policy to fund amounts for U.S. Pension Plan 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 2020, Fiscal 2019 and Fiscal 2018, we made cash contributions to the U.S. Pension Plan of $13, $12 and $15, respectively. The minimum required contributions in Fiscal 2021 are not expected to be material. UGI Utilities has established a VEBA trust to pay retiree health care and life insurance benefits by depositing into the VEBA the annual amount of postretirement benefits costs, if any. We do not expect to be required to make any contributions to the VEBA during Fiscal 2021. Expected payments for postretirement benefits over the next 10 years are not material. Expected payments for pension benefits are as follows: Pension Fiscal 2021 $ 33 Fiscal 2022 $ 32 Fiscal 2023 $ 34 Fiscal 2024 $ 36 Fiscal 2025 $ 38 Fiscal 2026 - 2030 $ 203 We also sponsor unfunded and non-qualified supplemental executive defined benefit retirement plans. At September 30, 2020 and 2019, the PBOs of these plans, including obligations for amounts held in grantor trusts, totaled $59 and $53, respectively. Costs associated with these plans were not material for all periods presents and are excluded from the tables above. Amounts recorded in UGI’s stockholders’ equity for these plans include pre-tax losses of $12 and $9 at September 30, 2020 and 2019, respectively, principally representing unrecognized actuarial losses. In Fiscal 2021, the estimated amount that will be amortized from such pre-tax actuarial losses into retiree benefit cost is not material. During Fiscal 2020, Fiscal 2019 and Fiscal 2018, 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 $35 and $34 at September 30, 2020 and 2019, respectively. U.S. Pension Plan Assets The assets of the U.S. Pension Plan are held in trust. The investment policies and asset allocation strategies for the assets in these trusts are determined by an investment committee comprising officers of UGI and UGI Utilities. In Fiscal 2020, the Company transitioned its investment strategy to minimize projected funded status volatility by more closely aligning the duration of the U.S. Pension Plan’s 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. To achieve the stated objective, beginning in October 2019, investments are made principally in common collective trust funds that consists of equity index investments, bond index investments and a short-term investments, and, to a much less extent, UGI Common Stock. Previously, investments were made principally in publicly traded, diversified equity and fixed income index mutual funds. Assets associated with the VEBA and the UGI International plans are excluded from the tables below as such assets are not material. The targets, target ranges and actual allocations for the U.S. Pension Plan trust assets at September 30 are as follows: Actual Target Asset Allocation Permitted Range 2020 2019 2020 2019 September 30, 2020 Equity investments: U.S. equities 26.5 % 54.8 % 29.0 % 52.5 % 24.0% - 34.0% Non-U.S. equities 25.0 % 11.8 % 24.5 % 12.5 % 19.5% - 29.5% Global equities (a) 12.3 % — % 11.5 % — % 6.5% - 16.5% Total 63.8 % 66.6 % 65.0 % 65.0 % 60.0% - 70.0% Fixed income funds & cash equivalents 36.2 % 33.4 % 35.0 % 35.0 % 30.0% - 40.0% 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. Common collective trust funds in the U.S. Pension Plan 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 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 Plan trust assets by asset class and level within the fair value hierarchy, as described in Note 2, as of September 30, 2020 and 2019 are as follows: U.S. Pension Plan Level 1 Level 2 Level 3 Other (a) Total September 30, 2020: Domestic equity investments: UGI Corporation Common Stock $ 27 $ — $ — $ — $ 27 Total domestic equity investments 27 — — — 27 Common collective trust funds: U.S. equity index investments — — — 123 123 Non-U.S. equity index investments — — — 141 141 Global equity index investments — — — 70 70 Bond index investments — — — 200 200 Cash equivalents — — — 5 5 Total common collective trust funds — — — 539 539 Total $ 27 $ — $ — $ 539 $ 566 September 30, 2019: Domestic equity investments: S&P 500 Index equity mutual funds $ 176 $ — $ — $ — $ 176 Small and midcap equity mutual funds 73 — — — 73 UGI Corporation Common Stock 41 — — — 41 Total domestic equity investments 290 — — — 290 International index equity mutual funds 62 — — — 62 Fixed income investments: Bond index mutual funds 171 — — — 171 Cash equivalents — — — 6 6 Total fixed income investments 171 — — 6 177 Total $ 523 $ — $ — $ 6 $ 529 (a) Assets measured at NAV and therefore excluded from the fair value hierarchy. The expected long-term rates of return on U.S. Pension Plan 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 2020, $19 in Fiscal 2019 and $17 in Fiscal 2018. 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 2020, Fiscal 2019 and Fiscal 2018 were not material. At September 30, 2020 and 2019, the total fair values of these grantor trust investment assets, which amounts are included in “Other assets” on the Consolidated Balance Sheets, were $7 and $6, respectively.

Utility Regulatory Assets and L

Utility Regulatory Assets and Liabilities and Regulatory Matters	12 Months Ended
	Sep. 30, 2020
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 UGI Utilities are included in our Consolidated Balance Sheets at September 30: 2020 2019 Regulatory assets (a): Income taxes recoverable $ 124 $ 115 Underfunded pension and postretirement plans 175 179 Environmental costs 61 60 Removal costs, net 26 28 Other 11 14 Total regulatory assets $ 397 $ 396 Regulatory liabilities (a): Postretirement benefit overcollections $ 13 $ 15 Deferred fuel and power refunds 29 6 State income tax benefits — distribution system repairs 28 25 PAPUC Temporary Rates Order 7 31 Excess federal deferred income taxes 274 280 Other 2 2 Total regulatory liabilities $ 353 $ 359 (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 three remediation COAs with the PADEP, which were consolidated into one COA effective October 1, 2020. Pursuant to base rate orders, Gas Utility receives ratemaking recognition of its estimated environmental investigation and remediation costs associated with their 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. At September 30, 2020, 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 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. Gas Utility’s and Electric Utility’s tariffs contain clauses that permit recovery of all prudently incurred purchased gas and power costs through the application of PGC rates in the case of Gas Utility and DS tariffs in the case of Electric Utility. These clauses provide for periodic adjustments to PGC 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 and (losses) on such contracts at September 30, 2020 and 2019 were $8 and $(2), 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 Gas Utility or Electric Utility assets that are capitalized for regulatory and GAAP reporting. The tax benefits associated with these repair and maintenance deductions will be reflected as a reduction to income tax expense over the remaining tax lives of the related book assets. PAPUC Temporary Rates Order. On May 17, 2018, the PAPUC ordered each regulated utility currently not in a general base rate case proceeding, including UGI Gas, PNG and CPG, 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 will be 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 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 January 28, 2020, Gas Utility filed a request with the PAPUC to increase its annual base distribution operating revenues by $75 annually. On October 8, 2020, the PAPUC issued a final Order approving a previously filed Joint Petition for Approval of Settlement of all issues (the “Joint Petition”). Under the terms of the Joint Petition, Gas Utility will be permitted to increase its annual base distribution rates by $20, through a phased approach, with $10 beginning January 1, 2021 and an additional $10 beginning July 1, 2021. Additionally, Gas Utility will be authorized to implement a DSIC once Gas Utility total property, plant and equipment less accumulated depreciation reaches $2,875, with this threshold being unchanged from Gas Utility’s 2019 base rate case. The Joint Petition also includes enhanced COVID-19 customer assistance measures, including the establishment of an Emergency Relief Program for a defined set of payment troubled customers (“ERP”). Additionally, the Joint Petition will permit the Gas Utility to establish a regulatory asset for certain incremental expenses attributable to the ongoing COVID-19 pandemic, most notably expenses related to the ERP and uncollectible accounts expense, through the effective date of rates in the next Gas Utility base rate case, to be recovered and amortized over a 10-year period. In accordance with the terms of the Joint Petition, Gas Utility will not be permitted to file a rate case prior to January 1, 2022. On January 28, 2019, Gas Utility filed a rate request with the PAPUC to increase the base operating revenues for residential, commercial, and industrial customers throughout its Pennsylvania service territory by an aggregate $71. On October 4, 2019, the PAPUC issued a final Order approving a settlement that permitted Gas Utility, effective October 11, 2019, to increase its base distribution revenues by $30 under a single consolidated tariff, approved a plan for uniform class rates, and permitted Gas Utility to extend its Energy Efficiency and Conservation and Growth Extension Tariff programs by an additional term of five years. The PAPUC’s final Order approved a negative surcharge, to return to customers $24 of tax benefits experienced by Gas Utility over the period January 1, 2018 to June 30, 2018, plus applicable interest, in accordance with the May 17, 2018 PAPUC Order, which became effective for a twelve-month period beginning on October 11, 2019, the effective date of Gas Utility’s new base rates, subject to final reconciliation of any over- or under-crediting of the tax savings. On October 25, 2018, the PAPUC approved a final order providing for a $3 annual base distribution rate increase for Electric Utility, effective October 27, 2018. As part of the final PAPUC Order, Electric Utility provided customers with a one-time billing credit associated with 2018 TCJA tax benefits. On November 26, 2018, the Pennsylvania Office of Consumer Advocate filed an appeal to the Pennsylvania Commonwealth Court challenging the PAPUC’s acceptance of UGI Utilities’ use of a fully projected future test year and handling of consolidated federal income tax benefits. On January 15, 2020, the Pennsylvania Commonwealth Court issued a decision affirming the PAPUC Order adopting UGI Utilities’ position on both issues. No party exercised their right to seek an appeal of the Commonwealth Court decision.

Inventories

Inventories	12 Months Ended
	Sep. 30, 2020
Inventory Disclosure [Abstract]
Inventories	Note 10 — Inventories Inventories comprise the following at September 30: 2020 2019 Non-utility LPG and natural gas $ 164 $ 150 Gas Utility natural gas 20 27 Materials, supplies and other 57 53 Total inventories $ 241 $ 230 At September 30, 2020, UGI Utilities was a party to three SCAAs with terms up to three years. Pursuant to the SCAAs, UGI Utilities has, among other things, released certain natural gas storage and transportation contracts for the terms of the SCAAs. UGI Utilities also transferred certain associated natural gas storage inventories upon commencement of the SCAAs, will receive a transfer of storage inventories at the end of the SCAAs, and makes payments associated with refilling storage inventories during the terms of the SCAAs. The historical cost of natural gas storage inventories released under the SCAAs, which represents a portion of Gas Utility’s total natural gas storage inventories, and any exchange receivable (representing amounts of

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Sep. 30, 2020
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: 2020 2019 Utility: Distribution $ 3,630 $ 3,366 Transmission 111 106 General and other 425 389 Work in process 99 77 Total Utility 4,265 3,938 Non-utility: Land 191 184 Buildings and improvements 431 404 Transportation equipment 248 258 Equipment, primarily cylinders and tanks 3,712 3,455 Electric generation 211 327 Pipeline and related assets 1,098 1,150 Other 306 255 Work in process 196 102 Total non-utility 6,393 6,135 Total property, plant and equipment $ 10,658 $ 10,073

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Sep. 30, 2020
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, 2018 $ 2,004 $ 964 $ 10 $ 182 $ 3,160 Acquisitions — 26 330 — 356 Foreign currency translation — (60) — — (60) 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 Intangible assets comprise the following at September 30: 2020 2019 Customer relationships $ 1,083 $ 1,038 Trademarks and tradenames 12 16 Noncompete agreements and other 76 48 Accumulated amortization (543) (442) Intangible assets, net (definite-lived) 628 660 Trademarks and tradenames (indefinite-lived) 49 49 Total intangible assets, net $ 677 $ 709 Changes in amounts above include the effects of currency translation. Amortization expense of intangible assets was $83, $59 and $58 for Fiscal 2020, Fiscal 2019 and Fiscal 2018, respectively. Estimated amortization expense of intangible assets during the next five fiscal years is as follows: Fiscal 2021 — $76; Fiscal 2022 — $65; Fiscal 2023 — $61; Fiscal 2024 — $59; Fiscal 2025 — $57.

Series Preferred Stock

Series Preferred Stock	12 Months Ended
	Sep. 30, 2020
Equity [Abstract]
Series Preferred Stock	Note 13 — Series Preferred Stock UGI has 10,000,000 shares of UGI Series Preferred Stock authorized for issuance, including both series subject to and series not subject to mandatory redemption. UGI had no shares of UGI Series Preferred Stock outstanding at September 30, 2020 or 2019. UGI Utilities has 2,000,000 shares of UGI Utilities Series Preferred Stock authorized for issuance, including both series subject to and series not subject to mandatory redemption. At September 30, 2020 and 2019, there were no shares of UGI Utilities Series Preferred Stock outstanding.

Common Stock and Equity-Based C

Common Stock and Equity-Based Compensation	12 Months Ended
	Sep. 30, 2020
Share-based Payment Arrangement [Abstract]
Common Stock and Equity-Based Compensation	Note 14 — Common Stock and Equity-Based Compensation Common Stock 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, Fiscal 2019 and Fiscal 2018, the Company purchased and placed in treasury stock 950,000, 300,000 and 1,200,000 shares at a total cost of $38, $17 and $60, respectively. UGI Common Stock share activity for Fiscal 2020, Fiscal 2019 and Fiscal 2018 is as follows: Issued Treasury Outstanding Balance at September 30, 2017 173,987,691 (843,954) 173,143,737 Issued: Employee and director plans 155,306 1,804,712 1,960,018 Repurchases of common stock — (1,200,000) (1,200,000) Reacquired common stock – employee and director plans — (154,780) (154,780) 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 September 30, 2020 209,514,044 (1,159,606) 208,354,438 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 as further described below. We recognized total pre-tax equity-based compensation expense of $15 ($11 after-tax), $18 ($13 after-tax) and $23 ($16 after-tax) in Fiscal 2020, Fiscal 2019 and Fiscal 2018, respectively. UGI Equity-Based Compensation Plans and Awards. Under the UGI Corporation 2013 OICP, 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 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 2013 OICP 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. In addition, the 2013 OICP provides that awards of UGI Units may also provide for the crediting of dividend equivalents to participants’ accounts. Except in the event of retirement, death or disability, each unvested grant 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. Under the 2013 OICP, awards representing up to 21,750,000 shares of UGI Common Stock may be granted. Dividend equivalents on UGI Unit Awards to employees will be paid in cash. Dividend equivalents on non-employee director awards are accumulated in additional Stock Units. UGI Unit Awards granted to employees and non-employee directors are settled in shares of UGI Common Stock and cash. Substantially all UGI Unit Awards granted to UGI France employees are settled in shares of UGI Common Stock and do not accrue dividend equivalents. With respect to UGI Performance Unit awards, the actual number of shares (or their cash equivalent) ultimately issued, and the actual amount of dividend equivalents paid, is generally dependent upon the achievement of market performance goals and service conditions. Beginning in Fiscal 2019, we began issuing shares of UGI Common Stock to satisfy substantially all option exercises and UGI Unit Awards. Prior to Fiscal 2019, we issued treasury shares to satisfy substantially all option exercises and UGI Unit Awards. Stock options may be net exercised whereby shares equal to the option price and the grantee’s applicable payroll tax withholding are withheld from the number of shares payable (“net exercise”). We record shares withheld pursuant to a net exercise as shares reacquired. Pursuant to the AmeriGas Merger Agreement, all holders of AmeriGas Partners equity-based compensation awards received replacement awards comprising UGI cash-settled restricted stock units. See discussion below under “AmeriGas Partners Equity-Based Compensation Plans and Awards” for additional information. UGI Stock Option Awards . Stock option transactions under equity-based compensation plans during Fiscal 2020, Fiscal 2019 and Fiscal 2018 are as follows: Shares Weighted - Total Weighted - Shares under option — September 30, 2017 8,781,748 $ 30.20 $ 147 6.3 Granted 1,401,400 $ 47.85 Canceled (152,017) $ 42.14 Expired (1,666) $ 35.80 Exercised (1,832,396) $ 26.00 $ 45 Shares under option — September 30, 2018 8,197,069 $ 33.93 $ 177 6.2 Granted 1,197,100 $ 53.27 Canceled (123,012) $ 48.69 Expired (13,699) $ 47.49 Exercised (779,353) $ 25.75 $ 23 Shares under option — September 30, 2019 8,478,105 $ 37.18 $ 115 5.9 Granted 1,893,700 $ 43.20 Canceled (57,668) $ 49.69 Expired (93,728) $ 37.81 Exercised (230,875) $ 22.65 $ 3 Shares under option — September 30, 2020 9,989,534 $ 38.58 $ 26 5.8 Options exercisable — September 30, 2018 5,498,330 $ 28.63 Options exercisable — September 30, 2019 5,963,530 $ 32.02 Options exercisable — September 30, 2020 6,898,251 $ 35.06 $ 26 4.5 Options not exercisable — September 30, 2020 3,091,283 $ 46.45 $ — 8.6 Cash received from stock option exercises and associated tax benefits were $2 and $1, $20 and $5, and $43 and $13 in Fiscal 2020, Fiscal 2019 and Fiscal 2018, respectively. As of September 30, 2020, there was $8 of unrecognized compensation cost associated with unvested stock options that is expected to be recognized over a weighted-average period of 1.9 years. The following table presents additional information relating to stock options outstanding and exercisable at September 30, 2020: Range of exercise prices Under $30.00 $30.00 – $35.00 $35.01 – $40.00 $40.01 – $45.00 Over $45.01 Options outstanding at September 30, 2020: Number of options 2,672,041 1,297,358 858,565 177,947 4,983,623 Weighted average remaining contractual life (in years) 2.2 5.9 4.2 7.9 7.8 Weighted average exercise price $ 23.46 $ 33.30 $ 37.82 $ 44.07 $ 48.00 Options exercisable at September 30, 2020: Number of options 2,669,481 1,041,488 858,565 172,497 2,156,220 Weighted average exercise price $ 23.45 $ 33.65 $ 37.82 $ 44.12 $ 48.28 UGI Stock Option Fair Value Information. The per share weighted-average fair value of stock options granted under our option plans was $5.58 in Fiscal 2020, $8.70 in Fiscal 2019 and $7.51 in Fiscal 2018. These amounts were determined using a Black-Scholes option pricing model that values options based on the stock price at the grant date, the expected life of the option, the estimated volatility of the stock, expected dividend payments and the risk-free interest rate over the expected life of the option. The expected life of option awards represents the period of time during which option grants are expected to be outstanding and is derived from historical exercise patterns. Expected volatility is based on historical volatility of the price of UGI’s Common Stock. Expected dividend yield is based on historical UGI dividend rates. The risk free interest rate is based on U.S. Treasury bonds with terms comparable to the options in effect on the date of grant. The assumptions we used for valuing option grants during Fiscal 2020, Fiscal 2019 and Fiscal 2018 are as follows: 2020 2019 2018 Expected life of option 6 years 6 years 6 years Weighted-average volatility 19.6% 17.2% 17.5% Weighted-average dividend yield 3.0% 1.8% 2.1% Expected volatility 19.6% 17.2% 17.5% Expected dividend yield 3.0% 1.8% 2.1% Risk free rate 0.3% - 1.7% 1.5% - 2.6% 2.2% - 2.9% 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. For such grants, if UGI’s TSR ranks below the 25th percentile compared to the UGI comparator group, the employee will not be paid. At the 25th percentile, the employee will be paid an award equal to 25% of the target award; at the 40th percentile, 70%; at the 50th percentile, 100%; and at the 90th percentile and above, 200%. The actual amount of the award is interpolated between these percentile rankings. Dividend equivalents are paid in cash only on UGI Performance Units that eventually vest. 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. Under GAAP, UGI Performance Units are equity awards with a market-based condition which, if settled in shares, result in the recognition of compensation cost over the requisite employee service period regardless of whether the market-based condition is satisfied. The fair values of UGI Performance Units are 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 expected term of the UGI Performance Unit awards is three years based on the performance period. Expected volatility is based on the historical volatility of UGI Common Stock over a three-year period. The risk-free interest rate is based on the yields on U.S. Treasury bonds at the time of grant. Volatility for all companies in the UGI comparator groups is based on historical volatility. The following table summarizes the weighted-average assumptions used to determine the fair value of UGI Performance Unit awards and related compensation costs: Grants Awarded in Fiscal Year 2020 2019 2018 Risk free rate 1.6% 2.5% 2.0% Expected life 3 years 3 years 3 years Expected volatility 18.6% 17.7% 18.9% Dividend yield 2.9% 1.9% 2.1% The weighted-average grant date fair value of UGI Performance Unit awards was estimated to be $41.85 for Units granted in Fiscal 2020, $55.40 for Units granted in Fiscal 2019 and $55.26 for Units granted in Fiscal 2018. The following table summarizes UGI Unit award activity for Fiscal 2020: Weighted-Average Total UGI Units at September 30, 2019 (a) 893,820 $ 36.39 UGI Performance Units: Granted 222,410 $ 41.85 Forfeited (13,734) $ 40.01 Performance criteria not met (121,948) $ 46.76 UGI Stock Units: Granted (b) 77,951 $ 40.38 Unit awards paid (227,225) $ 24.31 Total UGI Units at September 30, 2020 (a) 831,274 $ 39.95 (a) Total UGI Units includes UGI Stock Units issued to non-employee directors, which vest on the grant date, and UGI Performance Units and UGI Stock Units issued to retirement-eligible employees that vest on an accelerated basis. Total vested restricted units at September 30, 2020 and 2019 were 441,498 and 616,319, respectively. (b) Generally, shares granted under UGI Stock Unit awards are paid approximately 70% in shares. UGI Stock Unit awards granted in Fiscal 2019 and Fiscal 2018 were 29,784 and 52,314, respectively. During Fiscal 2020, Fiscal 2019 and Fiscal 2018, the Company paid UGI Performance Unit and UGI Stock Unit awards in shares and cash as follows: 2020 2019 2018 UGI Performance Unit awards: Number of original awards granted, net of forfeitures 121,948 144,521 136,621 Performance period beginning January 1: 2017 2016 2015 Payment of awards: Shares of UGI Common Stock issued, net of shares withheld for taxes — 116,950 69,680 Cash paid $ — $ 10 $ 2 UGI Stock Unit awards: Number of original awards granted, net of forfeitures 227,721 50,985 39,680 Payment of awards: Shares of UGI Common Stock issued, net of shares withheld for taxes 148,477 43,479 29,095 Cash paid $ 3 $ 1 $ 1 During Fiscal 2020, Fiscal 2019 and Fiscal 2018, we granted UGI Unit awards representing 300,361, 158,694 and 196,114 shares, respectively, having weighted-average grant date fair values per Unit of $41.50, $55.40 and $53.36, respectively. As of September 30, 2020, there was a total of $8 unrecognized compensation cost associated with 831,274 UGI Unit awards outstanding that is expected to be recognized over a weighted-average period of 2.0 years. The total grant-date fair values of outstanding UGI Units that vested during Fiscal 2020, Fiscal 2019 and Fiscal 2018 were $5, $5 and $7, respectively. As of September 30, 2020 and 2019, total liabilities of $5 and $10, respectively, associated with UGI Unit awards are reflected in “Employee compensation and benefits accrued” and “Other noncurrent liabilities” on the Consolidated Balance Sheets. At September 30, 2020, 6,105,754 shares of Common Stock were available for future grants under the 2013 OICP, which includes the number of AmeriGas Common Units available for grant under the 2010 Propane Plan that were converted to UGI Units as further described below. AmeriGas Partners Equity-Based Compensation Plans and Awards. Prior to the AmeriGas Merger, under the 2010 Propane Plan on behalf of AmeriGas Partners, L.P., the General Partner could award to employees and non-employee directors of the General Partner grants of AmeriGas Partners Units (comprising “AmeriGas Stock Units” and “AmeriGas Performance Units”), options, phantom units, unit appreciation rights and other Common Unit-based awards that, depending on the award, vested immediately or ratable over a period of time subject to other conditions under the plan related to termination, retirement, death or disability (all as defined). Participants were eligible to receive Common Unit distribution equivalents under the terms of certain awards (ultimately paid in cash only on awards that vested). Effective with the AmeriGas Merger, all outstanding AmeriGas Stock Units and AmeriGas Performance Units were canceled and converted to cash-settled restricted stock units relating to UGI Common Stock (see “Impact of AmeriGas Merger on AmeriGas Unit Awards” below). AmeriGas Stock Unit and AmeriGas Performance Unit awards entitled the grantee to AmeriGas Partners Common Units or cash once the service condition was met and, with respect to AmeriGas Performance Units, subject to market performance conditions or actual net customer acquisition and retention performance (as defined in the applicable awards). Recipients were awarded a target number of AmeriGas Performance Units, and the number of AmeriGas Performance Units ultimately paid at the end of the performance period (generally three years) ranging from 0% to 200% of the target number, subject to the performance conditions as defined for the applicable award. Pursuant to the terms of the AmeriGas Merger Agreement, the performance periods for AmeriGas TUR Performance Units outstanding immediately prior to the AmeriGas Merger ended on August 20, 2019, the last trading day of the Common Units prior to the completion of the AmeriGas Merger. Under GAAP, AmeriGas TUR Performance Units awards were recorded as equity awards to the extent they were to be settled in Common Units. This resulted in the recognition of compensation cost equal to the fair value of such award estimated using a Monte Carlo valuation model, over the requisite employee service period regardless of whether the market-based conditions were satisfied. The fair value associated with the target awards, which were to be paid in Common Units, was accounted for as equity and the fair value of the award over the target, as well as all Common Unit distribution equivalents, which were to be paid in cash, was accounted for as a liability. Impact of AmeriGas Merger on AmeriGas Unit Awards. Effective with the AmeriGas Merger on August 21, 2019, each outstanding award of AmeriGas Stock Units and AmeriGas Performance Units, including awards subject to market performance conditions, was canceled and converted into a number of cash-settled restricted stock units relating to UGI Common Stock determined by multiplying the number of such AmeriGas Unit awards by 0.6378. With respect to outstanding AmeriGas TUR Performance Units and AmeriGas Performance Units, the number of such awards canceled and converted to UGI restricted stock units was determined by multiplying the target number of such awards, including dividend equivalents, times the performance multiplier as determined based upon a shortened performance period ending August 20, 2019, the last full trading day of the Common Units prior to the AmeriGas Merger, subject to other performance conditions as defined in the award agreement and the AmeriGas Merger Agreement. The resulting number of cash-settled restricted stock units relating to UGI Common Stock could be more, but not less, than the associated target number of AmeriGas TUR Performance Unit awards. These restricted stock units vest on the originally scheduled AmeriGas TUR Performance Unit award vesting dates with the only condition being employment with the Company at the time of vesting. The converted awards remain subject to the same terms, conditions and restrictions as applied to the corresponding AmeriGas Unit awards immediately prior to the conversion including vesting terms, forfeitures, and distribution equivalent rights except that distribution equivalent rights will be based upon UGI dividends subsequent to the conversion. Pursuant to the terms of the AmeriGas Unit conversions described above, effective on August 21, 2019, 137,472 AmeriGas Performance Units and 126,089 AmeriGas Stock Units were converted into 215,957 of cash-settled restricted stock units relating to UGI Common Stock. The unrecognized compensation cost and total liabilities associated with UGI cash-settled restricted stock units that remain outstanding, including costs resulting from modifications and settlements resulting from the conversion of certain awards in connection with the AmeriGas Merger, was not material for Fiscal 2020 and Fiscal 2019. UGI assumed the obligations of the General Partner and the Partnership under the 2010 Propane Plan, and the 2010 Propane Plan was deemed amended to conform to all of the terms and form of the 2013 OICP and combined with the 2013 OICP. At the time of the merger, the number of Common Units that remained available for grant under the 2010 Propane Plan were converted to 1,420,949 UGI awards available for future grant and delivery based upon a conversion ratio of 0.6378:1. These available converted awards may be granted only to those individuals who were eligible to receive awards under the 2010

Partnership Distributions

Partnership Distributions	12 Months Ended
	Sep. 30, 2020
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. Available Cash is generally defined as: 1. all cash on hand at the end of such quarter, plus 2. all additional cash on hand as of the date of determination resulting from borrowings after the end of such quarter, less 3. the amount of cash reserves established by the General Partner in its reasonable discretion. 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) until Available Cash exceeded the Minimum Quarterly Distribution of $0.55 and the First Target Distribution of $0.055 per Common Unit (or a total of $0.605 per Common Unit). When Available Cash exceeded $0.605 per Common Unit 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 per Common Unit to limited partners exceeded $0.605. During Fiscal 2019 (prior to the AmeriGas Merger) and Fiscal 2018, the Partnership made quarterly distributions to Common Unitholders in excess of $0.605 per limited partner unit. 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 and Fiscal 2018, distributions received by the General Partner with respect to its aggregate 2% general partner ownership interests totaled $55 in each period, which included incentive distributions of $45 in each period.

Leases

Leases	12 Months Ended
	Sep. 30, 2020
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 Sheet as of September 30 are as follows: 2020 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 415 Other assets Finance lease ROU assets 52 Property, plant and equipment Total ROU assets $ 467 Lease liabilities: Operating lease liabilities — current $ 87 Other current liabilities Operating lease liabilities — noncurrent 334 Other noncurrent liabilities Finance lease liabilities — current 5 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 Long-term debt Total lease liabilities $ 467 The components of lease cost for Fiscal 2020 are as follows: 2020 Operating lease cost $ 102 Finance lease cost: Amortization of ROU assets 5 Interest on lease liabilities 3 Variable lease cost 5 Short-term lease cost 3 Total lease cost $ 118 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statement of Cash Flows during Fiscal 2020: 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 103 Operating cash flows — finance leases $ 3 Financing cash flows — finance leases $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (including the impact upon adoption) $ 506 ROU assets obtained in exchange for finance lease liabilities $ 22 The following table presents the weighted-average remaining lease term and weighted-average discount rate as of September 30, 2020: Weighted-average remaining lease term In years Operating leases 6.2 Finance leases 2.4 Weighted-average discount rate % Operating leases 3.8% Finance leases 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, 2020, were as follows: 2021 2022 2023 2024 2025 After 2025 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 102 $ 86 $ 73 $ 63 $ 48 $ 109 $ 481 $ (60) $ 421 Finance leases $ 5 $ 4 $ 4 $ 3 $ 3 $ 83 $ 102 $ (56) $ 46 Approximately 85% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2020, operating and finance leases that had not yet commenced were not material. Disclosures Related to Periods Prior to Adoption of ASC 842 As discussed above, the Company adopted ASC 842 effective October 1, 2019, using a modified retrospective approach. As required, the following disclosure is provided for periods prior to adoption. The Company’s future minimum payments under non-cancelable operating leases at September 30, 2019, which were accounted for under ASC 840, were as follows: 2020 2021 2022 2023 2024 After Minimum operating lease payments $ 100 $ 86 $ 71 $ 62 $ 54 $ 139 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 Sheet as of September 30 are as follows: 2020 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 415 Other assets Finance lease ROU assets 52 Property, plant and equipment Total ROU assets $ 467 Lease liabilities: Operating lease liabilities — current $ 87 Other current liabilities Operating lease liabilities — noncurrent 334 Other noncurrent liabilities Finance lease liabilities — current 5 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 Long-term debt Total lease liabilities $ 467 The components of lease cost for Fiscal 2020 are as follows: 2020 Operating lease cost $ 102 Finance lease cost: Amortization of ROU assets 5 Interest on lease liabilities 3 Variable lease cost 5 Short-term lease cost 3 Total lease cost $ 118 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statement of Cash Flows during Fiscal 2020: 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 103 Operating cash flows — finance leases $ 3 Financing cash flows — finance leases $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (including the impact upon adoption) $ 506 ROU assets obtained in exchange for finance lease liabilities $ 22 The following table presents the weighted-average remaining lease term and weighted-average discount rate as of September 30, 2020: Weighted-average remaining lease term In years Operating leases 6.2 Finance leases 2.4 Weighted-average discount rate % Operating leases 3.8% Finance leases 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, 2020, were as follows: 2021 2022 2023 2024 2025 After 2025 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 102 $ 86 $ 73 $ 63 $ 48 $ 109 $ 481 $ (60) $ 421 Finance leases $ 5 $ 4 $ 4 $ 3 $ 3 $ 83 $ 102 $ (56) $ 46 Approximately 85% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2020, operating and finance leases that had not yet commenced were not material. Disclosures Related to Periods Prior to Adoption of ASC 842 As discussed above, the Company adopted ASC 842 effective October 1, 2019, using a modified retrospective approach. As required, the following disclosure is provided for periods prior to adoption. The Company’s future minimum payments under non-cancelable operating leases at September 30, 2019, which were accounted for under ASC 840, were as follows: 2020 2021 2022 2023 2024 After Minimum operating lease payments $ 100 $ 86 $ 71 $ 62 $ 54 $ 139 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 Sheet as of September 30 are as follows: 2020 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 415 Other assets Finance lease ROU assets 52 Property, plant and equipment Total ROU assets $ 467 Lease liabilities: Operating lease liabilities — current $ 87 Other current liabilities Operating lease liabilities — noncurrent 334 Other noncurrent liabilities Finance lease liabilities — current 5 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 Long-term debt Total lease liabilities $ 467 The components of lease cost for Fiscal 2020 are as follows: 2020 Operating lease cost $ 102 Finance lease cost: Amortization of ROU assets 5 Interest on lease liabilities 3 Variable lease cost 5 Short-term lease cost 3 Total lease cost $ 118 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statement of Cash Flows during Fiscal 2020: 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 103 Operating cash flows — finance leases $ 3 Financing cash flows — finance leases $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (including the impact upon adoption) $ 506 ROU assets obtained in exchange for finance lease liabilities $ 22 The following table presents the weighted-average remaining lease term and weighted-average discount rate as of September 30, 2020: Weighted-average remaining lease term In years Operating leases 6.2 Finance leases 2.4 Weighted-average discount rate % Operating leases 3.8% Finance leases 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, 2020, were as follows: 2021 2022 2023 2024 2025 After 2025 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 102 $ 86 $ 73 $ 63 $ 48 $ 109 $ 481 $ (60) $ 421 Finance leases $ 5 $ 4 $ 4 $ 3 $ 3 $ 83 $ 102 $ (56) $ 46 Approximately 85% of the operating lease liabilities presented above relate to AmeriGas Propane. At September 30, 2020, operating and finance leases that had not yet commenced were not material. Disclosures Related to Periods Prior to Adoption of ASC 842 As discussed above, the Company adopted ASC 842 effective October 1, 2019, using a modified retrospective approach. As required, the following disclosure is provided for periods prior to adoption. The Company’s future minimum payments under non-cancelable operating leases at September 30, 2019, which were accounted for under ASC 840, were as follows: 2020 2021 2022 2023 2024 After Minimum operating lease payments $ 100 $ 86 $ 71 $ 62 $ 54 $ 139 Lessor

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Sep. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 17 — Commitments and Contingencies Environmental Matters UGI Utilities From the late 1800s through the mid-1900s, UGI Utilities and its former subsidiaries owned and operated a number of MGPs prior to the general availability of natural gas. Some constituents of coal tars and other residues of the manufactured gas process are today considered hazardous substances under the Superfund Law and may be present on the sites of former MGPs. Between 1882 and 1953, UGI Utilities owned the stock of subsidiary gas companies in Pennsylvania and elsewhere and also operated the businesses of some gas companies under agreement. By the early 1950s, UGI Utilities divested all of its utility operations other than certain gas and electric operations. Beginning in 2006 and 2008, UGI Utilities also owned and operated two acquired subsidiaries (CPG and PNG), with similar histories of owning, and in some cases operating, MGPs in Pennsylvania. CPG and PNG merged into UGI Utilities effective October 1, 2018. Prior to the Utility Merger, each of UGI Utilities and its subsidiaries, CPG and PNG, were subject to COAs with the PADEP to address the remediation of specified former MGP sites in Pennsylvania. In accordance with the COAs, as amended to recognize the Utility Merger, UGI Utilities, as the successor to CPG and PNG, was 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 and in the case of one COA, an additional obligation to plug specific natural gas wells, or make expenditures for such activities in an amount equal to an annual environmental cost cap (i.e. minimum expenditure threshold). The annual cost cap of the three COAs, in the aggregate, was $5. Effective October 1, 2020, the three COAs were consolidated into one agreement that superseded the existing agreements without modifications to the aggregate annual cost cap, and is scheduled to expire at the end of 2031. At September 30, 2020 and 2019, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the COAs totaled $53 and $50, respectively. We do not expect the costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to UGI Utilities’ results of operations because UGI Utilities receives ratemaking recovery of actual environmental investigation and remediation costs associated with the sites covered by the COAs. This ratemaking recognition reconciles the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. As such, UGI Utilities has recorded an associated regulatory asset for these costs because recovery of these costs from customers is probable (see Note 9). From time to time, UGI Utilities is notified of sites outside Pennsylvania on which private parties allege MGPs were formerly owned or operated by UGI Utilities or owned or operated by a former subsidiary. Such parties generally investigate the extent of environmental contamination or perform environmental remediation. Management believes that under applicable law UGI Utilities should not be liable in those instances in which a former subsidiary owned or operated an MGP. There could be, however, significant future costs of an uncertain amount associated with environmental damage caused by MGPs outside Pennsylvania that UGI Utilities directly operated, or that were owned or operated by a former subsidiary of UGI Utilities if a court were to conclude that (1) the subsidiary’s separate corporate form should be disregarded, or (2) UGI Utilities should be considered to have been an operator because of its conduct with respect to its subsidiary’s MGP. At September 30, 2020 and 2019, neither the undiscounted nor the accrued liability for environmental investigation and cleanup costs for UGI Utilities’ MGP sites outside Pennsylvania was material. 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, 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, subject to court approval. 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, 2020
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, 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 September 30, 2019 Derivative instruments: Assets: Commodity contracts $ 32 $ 10 $ — $ 42 Foreign currency contracts $ — $ 59 $ — $ 59 Liabilities: Commodity contracts $ (62) $ (113) $ — $ (175) Foreign currency contracts $ — $ (4) $ — $ (4) Interest rate contracts $ — $ (12) $ — $ (12) Non-qualified supplemental postretirement grantor trust investments (a) $ 40 $ — $ — $ 40 (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: 2020 2019 Carrying amount $ 6,081 $ 5,857 Estimated fair value $ 6,504 $ 6,189

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Sep. 30, 2020
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 derivatives 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, 2020, 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 local currency earnings before income taxes. Because these contracts are not designated as hedging instruments, realized and unrealized gains and losses on these contracts are recorded in “Other non-operating (expense) income, net” on the Consolidated Statements of Income. 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. During Fiscal 2020, we changed the method used for measuring ineffectiveness of our net investment hedges from the forward rate method to the spot rate method and the income statement impact of the change was not material. 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 (losses) gains associated with these net investment hedges in the cumulative translation adjustment component in AOCI of $(53) and $31 during Fiscal 2020 and 2019, respectively. Cross Currency Contracts Prior to the repayment of its U.S. dollar denominated variable-rate term loan during Fiscal 2019, Flaga used cross-currency contracts to hedge its exposure to the variability in expected future cash flows associated with the foreign currency and interest rate risk associated with this debt. These cross-currency contracts included initial and final exchanges of principal from a fixed euro denomination to a fixed U.S. dollar-denominated amount, to be exchanged at a specified rate, which was determined by the market spot rate on the date of issuance. These cross-currency contracts also included interest rate swaps of a floating U.S. dollar-denominated interest rate to a fixed euro-denominated interest rate. We designated these cross-currency contracts as cash flow hedges. These cross-currency contracts were settled concurrent with the repayment of this debt during Fiscal 2019. 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, 2020 and 2019 and the final settlement dates of the Company's open derivative contracts as of September 30, 2020, excluding those derivatives that qualified for the NPNS exception: Notional Amounts September 30, Type Units Settlements Extending Through 2020 2019 Commodity Price Risk: Regulated Utility Operations Gas Utility NYMEX natural gas futures and option contracts Dekatherms October 2021 22 23 Non-utility Operations LPG swaps Gallons February 2023 846 800 Natural gas futures, forward, basis swap, options and pipeline contracts Dekatherms December 2024 339 329 Electricity long forward and futures contracts Kilowatt hours January 2024 4,517 3,098 Electricity short forward and futures contracts Kilowatt hours April 2024 188 367 Interest Rate Risk: Interest rate swaps Euro October 2022 € 300 € 300 Interest rate swaps USD July 2024 $ 1,344 $ 1,357 Foreign Currency Exchange Rate Risk: Forward foreign exchange contracts USD September 2023 $ 511 $ 516 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. Certain of these agreements call for the posting of collateral by the counterparty or by the Company in the forms of letters of credit, parental guarantees or cash. Additionally, our commodity exchange-traded futures contracts generally require cash deposits in margin accounts. Restricted cash in brokerage accounts is reported in “Restricted cash” on the Consolidated Balance Sheets. Although we have concentrations of credit risk associated with derivative instruments, the maximum amount of loss we would incur if these counterparties failed to perform according to the terms of their contracts, based upon the gross fair values of the derivative instruments, was not material at September 30, 2020. 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, 2020, 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, most 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: 2020 2019 Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 17 $ 17 Derivatives subject to PGC and DS mechanisms: Commodity contracts 7 1 Derivatives not designated as hedging instruments: Commodity contracts 100 41 Foreign currency contracts 15 42 115 83 Total derivative assets – gross 139 101 Gross amounts offset in the balance sheet (57) (29) Total derivative assets – net $ 82 $ 72 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts $ (55) $ (12) Derivatives subject to PGC and DS mechanisms: Commodity contracts — (4) Derivatives not designated as hedging instruments: Commodity contracts (118) (171) Foreign currency contracts (14) (4) (132) (175) Total derivative liabilities – gross (187) (191) Gross amounts offset in the balance sheet 57 29 Cash collateral pledged 7 29 Total derivative liabilities – net $ (123) $ (133) 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 2020, Fiscal 2019 and Fiscal 2018: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from 2020 2019 2018 2020 2019 2018 Cash Flow Hedges: Foreign currency contracts $ — $ 1 $ — $ — $ 2 $ (3) Cost of sales Cross-currency contracts — — 2 — — 1 Interest expense /other operating income, net Interest rate contracts (53) (11) — (13) (6) (5) Interest expense Total $ (53) $ (10) $ 2 $ (13) $ (4) $ (7) Net Investment Hedges: Foreign currency contracts $ (1) $ 17 $ — Gain (Loss) Location of 2020 2019 2018 Derivatives Not Designated as Hedging Instruments: Commodity contracts $ (32) $ (344) $ 155 Cost of sales Commodity contracts 10 7 (5) Revenues Foreign currency contracts (20) 38 16 Other non-operating (expense) income, net Total $ (42) $ (299) $ 166 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, 2020
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. Changes in AOCI during Fiscal 2020, Fiscal 2019 and Fiscal 2018 are as follows: Postretirement Derivative Foreign Total AOCI - September 30, 2017 $ (19) $ (21) $ (53) $ (93) Other comprehensive income (loss) before reclassification adjustments (after-tax) 10 1 (30) (19) Amounts reclassified from AOCI: Reclassification adjustments (pre-tax) (3) 7 — 4 Reclassification adjustments tax expense (benefit) 1 (3) — (2) Reclassification adjustments (after-tax) (2) 4 — 2 Other comprehensive income (loss) attributable to UGI 8 5 (30) (17) AOCI - September 30, 2018 $ (11) $ (16) $ (83) $ (110) Other comprehensive loss before reclassification adjustments (after-tax) (13) (7) (83) (103) Amounts reclassified from AOCI: Reclassification adjustments (pre-tax) 2 4 — 6 Reclassification adjustments tax benefit (1) (2) — (3) Reclassification adjustments (after-tax) 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: Reclassification adjustments (pre-tax) 4 13 — 17 Reclassification adjustments tax benefit (1) (4) — (5) Reclassification adjustments (after-tax) 3 9 — 12 Other comprehensive (loss) income attributable to UGI — (29) 99 70 AOCI - September 30, 2020 $ (26) $ (54) $ (67) $ (147)

Other Operating Income, Net and

Other Operating Income, Net and Other Non-Operating (Expense) Income, Net	12 Months Ended
	Sep. 30, 2020
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 (Expense) Income, Net Other Operating Income, Net Other operating income, net, for Fiscal 2020, Fiscal 2019 and Fiscal 2018 comprises the following: 2020 2019 2018 Finance charges $ 9 $ 17 $ 16 Interest and interest-related income 2 6 3 Utility non-tariff service income — 1 3 Gains on sales of fixed assets, net 5 3 5 Other, net 5 4 5 Total other operating income, net $ 21 $ 31 $ 32 Other Non-Operating (Expense) Income, Net Other non-operating (expense) income, net for Fiscal 2020, Fiscal 2019 and Fiscal 2018 comprises the following: 2020 2019 2018 (Losses) gains on foreign currency contracts, net $ (20) $ 38 $ 16 Pension and other postretirement plans non-service income, net — 1 — Total other non-operating (expense) income, net $ (20) $ 39 $ 16

Quarterly Data (unaudited)

Quarterly Data (unaudited)	12 Months Ended
	Sep. 30, 2020
Quarterly Financial Data [Abstract]
Quarterly Data (unaudited)	Note 22 — Quarterly Data (unaudited) The following unaudited quarterly data includes adjustments (consisting only of normal recurring adjustments with the exception of those indicated below) that we consider necessary for a fair presentation unless otherwise indicated. Our quarterly results fluctuate primarily because of the seasonal nature of our businesses and the effects of unrealized gains and losses on commodity and certain foreign currency derivative instruments (see Note 19) and other significant discrete items that can affect the comparison of period-over-period results. December 31, March 31, June 30, September 30, 2019 2018 2020 2019 2020 2019 2020 2019 Revenues $ 2,007 $ 2,200 $ 2,229 $ 2,606 $ 1,199 $ 1,364 $ 1,124 $ 1,150 Operating income (loss) $ 377 $ 168 $ 362 $ 539 $ 174 $ 9 $ 69 $ (99) Net income (loss) including noncontrolling interests $ 212 $ 89 $ 226 $ 396 $ 84 $ (46) $ 10 $ (131) Net income (loss) attributable to UGI Corporation $ 212 $ 64 $ 226 $ 246 $ 85 $ (2) $ 9 $ (52) Earnings (loss) per common share attributable to UGI Corporation stockholders: Basic $ 1.01 $ 0.37 $ 1.08 $ 1.41 $ 0.41 $ (0.01) $ 0.05 $ (0.27) Diluted $ 1.00 $ 0.36 $ 1.07 $ 1.38 $ 0.41 $ (0.01) $ 0.05 $ (0.27) Weighted-average common shares outstanding (thousands): Basic 209,439 174,413 208,941 174,501 208,598 174,759 208,655 189,905 Diluted 211,258 177,566 209,808 177,318 208,975 174,759 209,357 189,905 (a) Includes loss on extinguishments of debt at UGI International which reduced net income attributable to UGI by $4. (b) Includes impairment of Conemaugh assets held-for-sale at Midstream & Marketing which reduced net income attributable to UGI by $37 (see Note 5). (c) Weighted-average common shares outstanding includes the impact from the August 2019 issuance of 34,613 thousand shares of UGI Common Stock in connection with the AmeriGas Merger (see Note 5).

Segment Information

Segment Information	12 Months Ended
	Sep. 30, 2020
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 and natural gas 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). UGI Utilities 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. 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 & 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 (c) $ 140 $ 229 $ (1) Income from equity investees 27 — — — 27 (d) — — Other non-operating (expense) income, net (20) — — 18 1 — (39) Earnings (losses) before interest expense and income taxes 989 — 373 259 168 229 (40) Interest expense (322) — (164) (31) (42) (54) (31) Income tax (expense) benefit (135) — (53) (55) (34) (39) 46 Net income (loss) attributable to UGI $ 532 $ — $ 156 $ 173 $ 92 $ 136 $ (25) Depreciation and amortization $ 484 $ — $ 178 $ 125 $ 75 $ 105 $ 1 Total assets $ 13,985 $ (282) $ 4,327 $ 3,123 $ 2,775 $ 3,809 $ 233 Short-term borrowings $ 347 $ — $ 186 $ 1 $ 19 $ 141 $ — Capital expenditures (including the effects of accruals) $ 665 $ — $ 135 $ 89 $ 93 $ 348 $ — Investments in equity investees $ 200 $ — $ — $ 10 $ 190 $ — $ — 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 (d) — — Loss on extinguishments of debt (6) — — — — — (6) Other non-operating income (expense), net 39 (1) — 5 — 2 33 Earnings (losses) 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) Total Elim- AmeriGas UGI International Midstream UGI Utilities Corporate & 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 $ — $ — 2018 Revenues from external customers $ 7,651 $ — $ 2,823 $ 2,684 $ 1,149 $ 998 $ (3) Intersegment revenues $ — $ (371) (b) $ — $ — $ 273 $ 94 $ 4 Cost of sales $ 4,075 $ (367) (b) $ 1,315 $ 1,620 $ 1,091 $ 523 $ (107) Operating income (loss) $ 1,065 $ 1 $ 422 $ 248 $ 175 $ 240 $ (21) Income (loss) from equity investees 4 — — (1) 5 (d) — — Other non-operating income (expense), net 16 (1) — (7) (1) (2) 27 Earnings before interest expense and income taxes 1,085 — 422 240 179 238 6 Interest expense (230) — (163) (21) (2) (43) (1) Income tax (expense) benefit (e) (33) (1) (31) (69) (50) (54) 172 Noncontrolling interests’ net (income) loss (103) — (152) 3 — — 46 Net income (loss) attributable to UGI $ 719 $ (1) $ 76 $ 153 $ 127 $ 141 $ 223 Depreciation and amortization $ 455 $ — $ 186 $ 141 $ 43 $ 85 $ — Total assets $ 11,981 $ (125) $ 3,934 $ 3,279 $ 1,329 $ 3,266 $ 298 Short-term borrowings $ 425 $ — $ 232 $ 1 $ 2 $ 190 $ — Capital expenditures (including the effects of accruals) $ 597 $ — $ 101 $ 111 $ 43 $ 339 $ 3 Investments in equity investees $ 88 $ — $ — $ 13 $ 75 $ — $ — (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 2020, Fiscal 2019 and Fiscal 2018: Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing 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) LPG 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) LPG business transformation expenses Operating and administrative expenses $ (15) $ (9) $ — 2018 Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (4) Net gains (losses) on commodity derivative instruments not associated with current-period transactions Cost of Sales $ 13 $ 93 $ 2 Unrealized gains on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 29 $ — Integration expenses associated with Finagaz Operating and administrative expenses $ — $ (31) $ — Impairment of Partnership tradenames and trademarks Impairment of Partnership tradenames and trademarks $ (75) $ — $ — (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. (d) Fiscal 2020 and Fiscal 2019 also includes income from Pennant subsequent to the CMG Acquisition (see Note 5). Includes AFUDC associated with PennEast (see Note 2).

Global LPG Business Transformat

Global LPG Business Transformation Initiatives	12 Months Ended
	Sep. 30, 2020
Restructuring and Related Activities [Abstract]
Global LPG Business Transformation Initiatives	Note 24 — Global LPG Business Transformation Initiatives 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. In connection with these initiatives, during Fiscal 2020 and 2019 we incurred $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, 2020
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 its 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 have been significantly impacted by COVID-19 in Fiscal 2020, the Company cannot predict the duration or magnitude of the outbreak 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, 2020
Condensed Financial Information Disclosure [Abstract]
SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)	BALANCE SHEETS (Millions of dollars) September 30, 2020 2019 ASSETS Current assets: Cash and cash equivalents $ 67 $ 54 Accounts receivable – related parties 11 5 Prepaid expenses and other current assets 15 23 Total current assets 93 82 Property, plant and equipment, net 2 3 Investments in subsidiaries 4,898 4,585 Other assets 87 77 Total assets $ 5,080 $ 4,747 LIABILITIES AND COMMON STOCKHOLDERS’ EQUITY Current liabilities: Current maturities of long-term debt $ 30 $ — Accounts and notes payable 15 15 Accrued liabilities 29 9 Total current liabilities 74 24 Long-term debt 817 846 Other noncurrent liabilities 61 60 Total liabilities 952 930 Commitments and contingencies (Note 1) Common stockholders’ equity: Common Stock, without par value (authorized – 450,000,000 shares; issued – 209,514,044 and 209,304,129 shares, respectively) 1,416 1,397 Retained earnings 2,908 2,653 Accumulated other comprehensive loss (147) (217) Treasury stock, at cost (49) (16) Total common stockholders’ equity 4,128 3,817 Total liabilities and common stockholders’ equity $ 5,080 $ 4,747 Note 1 — Commitments and Contingencies: At September 30, 2020, UGI Corporation had agreed to indemnify the issuers of $80 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 $396 of such obligations were outstanding as of September 30, 2020. Scheduled principal repayments of long-term debt during the next five fiscal years include $30 in Fiscal 2021, $300 in Fiscal 2022, $38 in Fiscal 2023 and $482 in Fiscal 2024. STATEMENTS OF INCOME (Millions of dollars, except per share amounts) Year Ended September 30, 2020 2019 2018 Revenues $ — $ — $ — Costs and expenses: Operating and administrative expenses 56 50 63 Other operating income, net (a) (54) (50) (52) 2 — 11 Operating loss (2) — (11) Pension and other postretirement plans non-service expense — (1) (1) Interest expense (32) (6) — Loss before income taxes (34) (7) (12) Income tax expense (benefit) 17 (3) 6 Loss before equity in income of unconsolidated subsidiaries (51) (4) (18) Equity in income of unconsolidated subsidiaries 583 260 737 Net income attributable to UGI Corporation $ 532 $ 256 $ 719 Other comprehensive (loss) income (12) (3) 3 Equity in other comprehensive income (loss) of unconsolidated subsidiaries 82 (97) (20) Comprehensive income attributable to UGI Corporation $ 602 $ 156 $ 702 Earnings per common share attributable to UGI Corporation stockholders: Basic $ 2.55 $ 1.44 $ 4.13 Diluted $ 2.54 $ 1.41 $ 4.06 Weighted - average common shares outstanding (thousands): Basic 208,928 178,417 173,908 Diluted 209,869 181,111 176,905 (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, 2020 2019 2018 NET CASH PROVIDED BY OPERATING ACTIVITIES (a) $ 322 $ 170 $ 208 CASH FLOWS FROM INVESTING ACTIVITIES: Expenditures for property, plant and equipment — — (2) Net investments in unconsolidated subsidiaries — (768) (7) Net cash used by investing activities — (768) (9) CASH FLOWS FROM FINANCING ACTIVITIES: Payment of dividends on Common Stock (273) (200) (177) Issuances of debt, net of issuance costs 60 846 — Repayments of long-term debt (60) — — Issuances of Common Stock 2 17 35 Repurchases of UGI Common Stock (38) (17) (60) Other — (7) — Net cash (used) provided by financing activities (309) 639 (202) Cash and cash equivalents increase (decrease) $ 13 $ 41 $ (3) Cash and cash equivalents: End of year $ 67 $ 54 $ 13 Beginning of year 54 13 16 Cash and cash equivalents increase (decrease) $ 13 $ 41 $ (3) (a) Includes dividends received from unconsolidated subsidiaries of $352, $163 and $191 for the years ended September 30, 2020, 2019 and 2018, respectively.

SCHEDULE II _ VALUATION AND QUA

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS	12 Months Ended
	Sep. 30, 2020
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, 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 Year Ended September 30, 2018 Reserves deducted from assets in the consolidated balance sheet: Allowance for doubtful accounts $ 27 $ 36 $ (28) (1) $ 35 Other reserves: Deferred tax assets valuation allowance $ 107 $ 10 $ — $ 117 (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, 2020
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	Certain 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. 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 RegulationUGI Utilities accounts for the financial effects of regulation in accordance with the FASB’s guidance in ASC 980. In accordance with this guidance, incurred costs and estimated future expenditures that would otherwise be charged to expense are capitalized and recorded as regulatory assets when it is probable that the incurred costs or estimated future expenditures 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 regulator.
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 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 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 and the assessment of the collectability of specific amounts. 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. For additional information regarding the tax effects of the AmeriGas Merger, see Note 7. 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	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 and common stock awards.
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 Gas Utility and Electric Utility inventories; specific identification for appliances; and the FIFO method for all other inventories.
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 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.
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 AssetsImpairment 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.
Debt Issuance Costs	Debt Issuance Costs We defer and amortize debt issuance costs and debt premiums and discounts over the expected lives of the respective debt issues considering maturity dates. Deferred debt issuance costs associated with long-term debt are reflected as a direct deduction from the carrying amount of such debt. Deferred debt issuance costs associated with revolving credit facilities reflected as short-term borrowings are classified as “ Other assets ” on our Consolidated Balance Sheets. Amortization of debt issuance costs is reported as interest expense. Unamortized costs associated with redemptions of debt prior to their stated maturity are generally recognized and recorded in “Loss on extinguishments of debt” on the Consolidated Statements of Income. As permitted by regulatory authorities, gains or losses resulting from refinancings of UGI Utilities’ debt are deferred and amortized over the lives of the new issuances.
Leases	Leases Effective October 1, 2019, the Company adopted ASU No. 2016-02 We adopted this new guidance using the modified retrospective transition method. Amounts and disclosures related to periods prior to October 1, 2019 have not been restated and continue to be reported in accordance with ASC 840. We elected to apply the following practical expedients in accordance with the guidance upon adoption: • Short-term leases: We did not recognize short-term leases (term of 12 months or less) on the balance sheet; • Easements: We did not re-evaluate existing land easements that were not previously accounted for as leases; and • Other: We did not reassess the classification of expired or existing contracts or determine whether they are or contain a lease. We also did not reassess whether initial direct costs qualify for capitalization under ASC 842. Upon adoption, we recorded ROU assets and lease liabilities of $452 related to our operating leases. Our accounting for finance leases remained substantially unchanged. There were no cumulative-effect adjustments made to retained earnings as of October 1, 2019. The adoption did not have a significant impact on our consolidated statements of income or cash flows. See Note 16 for additional disclosures regarding our leases.
Refundable Tank and Cylinder Deposits	Refundable Tank and Cylinder DepositsIncluded in “Other noncurrent liabilities” on our Consolidated Balance Sheets are customer paid deposits on tanks and cylinders primarily owned by subsidiaries of UGI FranceDeposits are refundable to customers when the tanks or cylinders are returned in accordance with contract terms.
Environmental Matters	Environmental Matters We are subject to environmental laws and regulations intended to mitigate or remove the effects of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current or former operating sites. Environmental 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
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 PlansWe use a market-related value of plan assets and an expected long-term rate of return to determine the expected return on assets of our U.S. pension and other postretirement plans. The market-related value of plan assets, other than equity investments, is based upon fair values. The market-related value of equity investments is calculated by rolling forward the prior-year’s market-related value with contributions, disbursements and the expected return on plan assets. One third of the difference between the expected and the actual value is then added to or subtracted from the expected value to determine the new market-related value
Equity-Based Compensation	Equity-Based Compensation All of our equity-based compensation, principally comprising UGI stock options, grants of UGI stock-based equity instruments and, prior to the AmeriGas Merger, grants of AmeriGas Partners equity instruments (together with UGI stock-based equity instruments, “Units” or “Unit Awards”), are measured at fair value on the grant date, date of modification or end of the period, as applicable. Compensation expense is recognized on a straight-line basis over the requisite service period. Depending upon the settlement terms of the awards, all or a portion of the fair value of equity-based awards may be presented as a liability or as equity on our Consolidated Balance Sheets. Equity-based compensation costs associated with the portion of Unit Awards classified as equity are measured based upon their estimated fair value on the date of grant or modification. Equity-based compensation costs associated with all or a portion of Unit Awards classified as liabilities are measured based upon their estimated fair value at the grant date and remeasured as of the end of each period. We record deferred tax assets for awards that we expect will result in deductions on our income tax returns based on the amount of compensation cost recognized and the statutory tax rate in the jurisdiction in which we will receive a deduction. Differences between the deferred tax assets recognized for financial reporting purposes and the actual tax benefit received on the income tax return are recorded on the Consolidated Statements of Income. Excess tax benefits and tax deficiencies associated with employee share-based awards that vest or are exercised are recognized as income tax benefit or expense in the reporting period in which they occur, and assumed proceeds under the treasury stock method used for computing diluted shares outstanding do not include windfall tax benefits in the diluted shares calculation. We account for forfeitures of share-based payments when they occur.
New Accounting Standards Adopted in Fiscal 2020 and Not Yet Adopted	New Accounting Standards Adopted in Fiscal 2020 Derivatives and Hedging. Effective October 1, 2019, the Company adopted ASU No. 2017-12, “Targeted Improvements to Accounting for Hedging Activities.” This ASU amends and simplifies existing guidance to allow companies to more accurately present the economic effects of risk management activities in the financial statements. For cash flow and net investment hedges as of the adoption date, the guidance required a modified retrospective approach. The amended presentation and disclosure guidance was required prospectively. The adoption of the new guidance did not have a material impact on our consolidated financial statements. Leases. Effective October 1, 2019, the Company adopted new accounting guidance for leases in accordance with ASC 842. See Notes 2 and 16 for a detailed description of the impact of the new guidance and related disclosures. Reference Rate Reform. In March 2020, the FASB issued ASU 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting.” This ASU provides entities with temporary optional guidance to ease potential accounting burdens to transition away from LIBOR or other reference rates that are expected to be discontinued and replaced with alternative reference rates. This ASU applies to all entities that have contracts, hedging relationships and other transactions affected by reference rate reform. The provisions in this ASU, among other things, simplify contract modification accounting and allow hedging relationships affected by reference rate reform to continue. ASU 2020-04 is effective upon issuance and entities are able to apply the amendments prospectively through December 31, 2022. During the third quarter of Fiscal 2020, the Company elected certain optional expedients related to all outstanding cash flow hedging relationships and such elections did not have a material impact on our consolidated financial statements. New Accounting Standard Adopted Effective October 1, 2020 Credit Losses. In June 2016, the FASB issued ASU 2016-13, “Measurement of Credit Losses on Financial Instruments. ” 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. Further, the new current expected credit loss model affects how entities estimate their allowance for losses related to receivables that are current with respect to their payment terms. Effective October 1, 2020, the Company adopted this ASU, as updated, using a modified retrospective transition approach. The adoption of the new guidance did not have a material impact on our consolidated financial statements. Accounting Standard Not Yet Adopted 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. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2021 (Fiscal 2022). Early adoption is permitted. The Company is in the process of assessing the impact on our consolidated financial statements from the adoption of the new guidance and determining 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, 2020
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) 2020 2019 2018 Weighted-average common shares outstanding for basic computation (a) 208,928 178,417 173,908 Incremental shares issuable for stock options and common stock awards (b) 941 2,694 2,997 Weighted-average common shares outstanding for diluted computation 209,869 181,111 176,905 (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) For Fiscal 2020 and Fiscal 2019, there were 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.
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. 2020 2019 2018 2017 Cash and cash equivalents $ 336 $ 447 $ 452 $ 558 Restricted cash 21 64 10 11 Cash, cash equivalents and restricted cash $ 357 $ 511 $ 462 $ 569
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. 2020 2019 2018 2017 Cash and cash equivalents $ 336 $ 447 $ 452 $ 558 Restricted cash 21 64 10 11 Cash, cash equivalents and restricted cash $ 357 $ 511 $ 462 $ 569
Estimated Useful Lives by Type	At September 30, 2020, estimated useful lives by asset type were as follows: Asset Type Minimum Estimated Useful Life Maximum Estimated Useful Life Buildings and improvements 10 40 Equipment, primarily cylinders and tanks 5 30 Electricity generation facilities 25 40 Pipeline and related assets 25 40 Transportation equipment and office furniture and fixtures 3 10 Computer software 1 10 Property, plant and equipment comprise the following at September 30: 2020 2019 Utility: Distribution $ 3,630 $ 3,366 Transmission 111 106 General and other 425 389 Work in process 99 77 Total Utility 4,265 3,938 Non-utility: Land 191 184 Buildings and improvements 431 404 Transportation equipment 248 258 Equipment, primarily cylinders and tanks 3,712 3,455 Electric generation 211 327 Pipeline and related assets 1,098 1,150 Other 306 255 Work in process 196 102 Total non-utility 6,393 6,135 Total property, plant and equipment $ 10,658 $ 10,073
Average Composite Depreciation Rates	The average composite depreciation rates at our Gas Utility and Electric Utility were as follows: 2020 2019 2018 Gas Utility 2.5 % 2.2 % 2.3 % Electric Utility 2.2 % 2.1 % 2.2 %

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Sep. 30, 2020
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 2020 and Fiscal 2019: 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, 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, 2020
Business Combinations [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	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: 2020 2019 2018 Midstream & Marketing UGI International Midstream & Marketing AmeriGas Propane UGI International Total cash paid $ 16 $ 49 $ 15 $ 10 $ 122 Liabilities incurred 7 — — 3 — Total purchase price $ 23 $ 49 $ 15 $ 13 $ 122

Debt (Tables)

Debt (Tables)	12 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Schedule of Short-term Debt	Information about the Company’s principal credit agreements (excluding the Energy Services Receivables Facility, which is discussed below) as of September 30, 2020 and 2019, 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 UGI Corporation Senior Credit Facility) are classified as “Short-term borrowings” on the Consolidated Balance Sheets. Expiration Date Total Capacity Borrowings Outstanding Letters of Credit and Guarantees Outstanding Available Borrowing Capacity Weighted Average Interest Rate - End of Year September 30, 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 (d) June 2024 $ 350 $ 141 $ — $ 209 1.12 % UGI Corporation (e) August 2024 $ 300 $ 300 $ — $ — 2.41 % September 30, 2019 AmeriGas OLP (a) December 2022 $ 600 $ 328 $ 63 $ 209 4.50 % UGI International, LLC (b) October 2023 € 300 € 193 € — € 107 3.64 % Energy Services (c) March 2021 $ 200 $ 45 $ — $ 155 6.25 % UGI Utilities (d) June 2024 $ 350 $ 166 $ — $ 184 3.00 % UGI Corporation (e) August 2024 $ 300 $ 300 $ — $ — 4.55 % (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. At September 30, 2019, the amount outstanding consisted of USD-denominated borrowings of $210. (c) The Energy Services 2020 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 Credit Agreement includes a $100 sublimit for letters of credit. (e) At September 30, 2020 and 2019, management intended to maintain a substantial portion of amounts outstanding under the UGI Corporation Senior Credit Facility beyond twelve months from the respective balance sheet dates. As such, borrowings outstanding are classified as “Long-term debt” on the Consolidated Balance Sheets. In October 2020, the Company repaid $30 of such borrowings and classified these repayments as “Current maturities of long-term debt” on the 2020 Consolidated Balance Sheet. The UGI Corporation Senior Credit Facility includes a $10 sublimit for letters of credit.
Schedule of Receivables Facility	Information regarding the amounts of trade receivables transferred to ESFC and the amounts sold to the bank are as follows: 2020 2019 2018 Trade receivables transferred to ESFC during the year $ 1,046 $ 1,373 $ 1,280 ESFC trade receivables sold to the bank during the year $ 182 $ 179 $ 193 ESFC trade receivables - end of year (a) $ 50 $ 55 $ 65 (a) At September 30, 2020 and 2019, the amounts of ESFC trade receivables sold to the bank were $19 and $46, respectively, and are 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: 2020 2019 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 (a) 5 14 Unamortized debt issuance costs (20) (24) Total AmeriGas Propane 2,560 2,565 UGI International: 3.25% Senior Notes due November 2025 410 382 UGI International, LLC variable-rate term loan due October 2023 (b) 352 327 Other 23 18 Unamortized debt issuance costs (7) (8) Total UGI International 778 719 Midstream & Marketing: Energy Services variable-rate term loan due through August 2026 (c) 691 698 Other (d) 41 1 Unamortized discount and debt issuance costs (12) (12) Total Energy Services 720 687 UGI Utilities: Senior Notes: 4.12%, due September 2046 200 200 4.98%, due March 2044 175 175 3.12% due April 2050 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 Medium-Term Notes: 6.13%, due October 2034 20 20 6.50%, due August 2033 20 20 Variable-rate term loan due through October 2022 (e) 108 114 Other 3 5 Unamortized debt issuance costs (5) (5) Total UGI Utilities 1,121 979 UGI Corporation: UGI Corporation revolving credit facility maturing August 2024 (f) 300 300 UGI Corporation variable-rate term loan due August 2022 (g) 300 300 UGI Corporation variable-rate term loan due through August 2024 (h) 250 250 Unamortized debt issuance costs (3) (4) Total UGI Corporation 847 846 Other 8 8 Total long-term debt 6,034 5,804 Less: current maturities (53) (24) Total long-term debt due after one year $ 5,981 $ 5,780 (a) At September 30, 2019, such amount includes Heritage Operating, L.P. Senior Secured Notes. The effective interest rate on the Heritage Operating, L.P. Senior Secured Notes was 6.75%. These notes were collateralized by AmeriGas OLP’s receivables, contracts, equipment, inventory, general intangibles and cash. (b) The effective interest rate on the term loan was 2.04% at both September 30, 2020 and 2019. We have entered into pay fixed, receive variable interest rate swaps to effectively fix the underlying variable rate on these borrowings. (c) At September 30, 2020 and 2019, the effective interest rates on the term loan were 5.30% and 5.79%, respectively. 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. 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. (d) Amounts include finance lease liabilities recognized as a result of the adoption of ASU No. 2016-02. For additional information, see Note 2 and Note 16 to the Consolidated Financial Statements. (e) At September 30, 2020 and 2019, the effective interest rates on this term loan were 4.00% and 3.05%, 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. (f) At September 30, 2020 and 2019, the effective interest rates on credit facility borrowings were 2.41% and 4.55%, 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. (g) At September 30, 2020 and 2019, the effective interest rate on this term loan 3.51% and 4.30%, respectively. We have entered into pay-fixed, receive variable interest rate swaps to effectively fix the underlying variable rate on these borrowings. (h) At September 30, 2020 and 2019, the effective interest rates on this term loan were 3.50% and 4.55%, 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 Maturities 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: 2021 2022 2023 2024 2025 AmeriGas Propane $ 3 $ 2 $ — $ 675 $ 700 UGI International 1 22 — 352 — Midstream & Marketing 10 7 7 7 7 UGI Utilities 8 7 96 — — UGI Corporation (a) 30 300 38 482 — Other 1 1 6 — — Total $ 53 $ 339 $ 147 $ 1,516 $ 707

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Income Before Income Taxes	Income before income taxes comprises the following: 2020 2019 2018 Domestic $ 424 $ 330 $ 576 Foreign 243 71 279 Total income before income taxes $ 667 $ 401 $ 855
Provisions for Income Taxes	The provisions for income taxes consist of the following: 2020 2019 2018 Current expense (benefit): Federal $ (85) $ 52 $ (2) State 4 14 26 Foreign 70 70 78 Total current (benefit) expense (11) 136 102 Deferred expense (benefit): Federal 135 3 (78) State 19 4 7 Foreign (8) (50) 2 Total deferred expense (benefit) 146 (43) (69) Total income tax expense $ 135 $ 93 $ 33
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: 2020 2019 2018 U.S. federal statutory tax rate 21.0 % 21.0 % 24.5 % Difference in tax rate due to: Effect of U.S. tax legislation (4.7) 0.2 (20.9) Effect of tax rate changes - International 0.3 (0.5) (2.1) Noncontrolling interests not subject to tax — (2.7) (3.0) State income taxes, net of federal benefit 2.8 3.6 2.9 Valuation allowance adjustments — — 1.1 Effects of foreign operations 1.3 1.8 3.1 Excess tax benefits on share-based payments (0.2) (1.0) (1.1) Other, net (0.3) 0.7 (0.7) Effective tax rate 20.2 % 23.1 % 3.8 %
Deferred Tax Liabilities (Assets)	Deferred tax liabilities (assets) comprise the following at September 30: 2020 2019 Excess book basis over tax basis of property, plant and equipment $ 830 $ 805 Utility regulatory assets 112 108 Intangible assets and goodwill 107 71 Other 32 7 Gross deferred tax liabilities 1,081 991 Investment in AmeriGas Partners (216) (304) Pension plan liabilities (48) (50) Employee-related benefits (46) (44) Operating loss carryforwards (34) (21) Foreign tax credit carryforwards (81) (81) Utility regulatory liabilities (94) (94) Derivative instruments (26) (15) Utility environmental liabilities (16) (15) Other (54) (34) Gross deferred tax assets (615) (658) Deferred tax assets valuation allowance 105 91 Net deferred tax liabilities $ 571 $ 424
Reconciliation of Unrecognized Tax Benefits	A reconciliation of the beginning and ending amounts of unrecognized tax benefits is as follows: 2020 2019 2018 Unrecognized tax benefits — beginning of year $ 11 $ 12 $ 12 Additions for tax positions of the current year 2 1 2 Additions for tax positions taken in prior years — — 1 Settlements with tax authorities/statute lapses (9) (2) (3) Unrecognized tax benefits — end of year $ 4 $ 11 $ 12

Employee Retirement Plans (Tabl

Employee Retirement Plans (Tables)	12 Months Ended
	Sep. 30, 2020
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 Plan and the UGI International pension plans), the ABOs of our other postretirement benefit plans, plan assets, and the funded status of pension and other postretirement plans as of September 30, 2020 and 2019. 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 Other Postretirement 2020 2019 2020 2019 Change in benefit obligations: Benefit obligations — beginning of year $ 750 $ 669 $ 23 $ 19 Service cost 11 10 — — Interest cost 23 27 1 1 Actuarial loss 27 89 1 4 Curtailments (2) (1) — — Settlements — (13) — — Foreign currency 3 (3) — — Benefits paid (30) (28) (1) (1) Benefit obligations — end of year $ 782 $ 750 $ 24 $ 23 Change in plan assets: Fair value of plan assets — beginning of year $ 547 $ 563 $ 16 $ 15 Actual gain on plan assets 53 13 2 1 Foreign currency 1 (1) — — Employer contributions 13 12 — — Settlements — (13) — — Benefits paid (29) (27) (1) — Fair value of plan assets — end of year $ 585 $ 547 $ 17 $ 16 Funded status of the plans — end of year $ (197) $ (203) $ (7) $ (7) Assets (liabilities) recorded in the balance sheet: Assets in excess of liabilities — included in other noncurrent assets $ — $ — $ 3 $ 3 Unfunded liabilities — included in other noncurrent liabilities (197) (203) (10) (10) Net amount recognized $ (197) $ (203) $ (7) $ (7) Amounts recorded in UGI Corporation stockholders’ equity (pre-tax): Prior service cost (benefit) $ 1 $ 1 $ (1) $ (1) Net actuarial loss 24 26 — — Total $ 25 $ 27 $ (1) $ (1) Amounts recorded in regulatory assets and liabilities (pre-tax): Prior service cost $ — $ 1 $ — $ — Net actuarial loss 174 177 1 1 Total $ 174 $ 178 $ 1 $ 1
Actuarial Assumptions for Domestic 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 Plan Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 Weighted-average assumptions: Discount rate – benefit obligations 2.90 % 3.30 % 4.40 % 3.00 % 3.30 % 4.40 % Discount rate – benefit cost 3.30 % 4.40 % 4.00 % 3.30 % 4.40 % 4.00 % Expected return on plan assets 7.20 % 7.30 % 7.40 % 5.00 % 5.00 % 5.00 % Rate of increase in salary levels 3.25 % 3.25 % 3.25 % 3.25 % 3.25 % 3.25 %
Net Periodic Pension Expense and Other Postretirement Benefit Costs	Net periodic pension cost include the following components: Pension Benefits 2020 2019 2018 Service cost $ 11 $ 10 $ 11 Interest cost 23 27 26 Expected return on assets (38) (36) (35) Curtailment gain (1) — — Amortization of: Prior service cost 1 — 1 Actuarial loss 15 8 13 Net cost $ 11 $ 9 $ 16
Expected Payments for Pension Benefits and Other Postretirement Welfare Benefits	Expected payments for pension benefits are as follows: Pension Fiscal 2021 $ 33 Fiscal 2022 $ 32 Fiscal 2023 $ 34 Fiscal 2024 $ 36 Fiscal 2025 $ 38 Fiscal 2026 - 2030 $ 203
Pension Plans	The targets, target ranges and actual allocations for the U.S. Pension Plan trust assets at September 30 are as follows: Actual Target Asset Allocation Permitted Range 2020 2019 2020 2019 September 30, 2020 Equity investments: U.S. equities 26.5 % 54.8 % 29.0 % 52.5 % 24.0% - 34.0% Non-U.S. equities 25.0 % 11.8 % 24.5 % 12.5 % 19.5% - 29.5% Global equities (a) 12.3 % — % 11.5 % — % 6.5% - 16.5% Total 63.8 % 66.6 % 65.0 % 65.0 % 60.0% - 70.0% Fixed income funds & cash equivalents 36.2 % 33.4 % 35.0 % 35.0 % 30.0% - 40.0% 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.
Fair Value of U.S. Pension Plan and VEBA Trust Assets	The fair values of the U.S. Pension Plan trust assets by asset class and level within the fair value hierarchy, as described in Note 2, as of September 30, 2020 and 2019 are as follows: U.S. Pension Plan Level 1 Level 2 Level 3 Other (a) Total September 30, 2020: Domestic equity investments: UGI Corporation Common Stock $ 27 $ — $ — $ — $ 27 Total domestic equity investments 27 — — — 27 Common collective trust funds: U.S. equity index investments — — — 123 123 Non-U.S. equity index investments — — — 141 141 Global equity index investments — — — 70 70 Bond index investments — — — 200 200 Cash equivalents — — — 5 5 Total common collective trust funds — — — 539 539 Total $ 27 $ — $ — $ 539 $ 566 September 30, 2019: Domestic equity investments: S&P 500 Index equity mutual funds $ 176 $ — $ — $ — $ 176 Small and midcap equity mutual funds 73 — — — 73 UGI Corporation Common Stock 41 — — — 41 Total domestic equity investments 290 — — — 290 International index equity mutual funds 62 — — — 62 Fixed income investments: Bond index mutual funds 171 — — — 171 Cash equivalents — — — 6 6 Total fixed income investments 171 — — 6 177 Total $ 523 $ — $ — $ 6 $ 529 (a) 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, 2020
Regulated Operations [Abstract]
Schedule of Regulatory Assets	The following regulatory assets and liabilities associated with UGI Utilities are included in our Consolidated Balance Sheets at September 30: 2020 2019 Regulatory assets (a): Income taxes recoverable $ 124 $ 115 Underfunded pension and postretirement plans 175 179 Environmental costs 61 60 Removal costs, net 26 28 Other 11 14 Total regulatory assets $ 397 $ 396 Regulatory liabilities (a): Postretirement benefit overcollections $ 13 $ 15 Deferred fuel and power refunds 29 6 State income tax benefits — distribution system repairs 28 25 PAPUC Temporary Rates Order 7 31 Excess federal deferred income taxes 274 280 Other 2 2 Total regulatory liabilities $ 353 $ 359 (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 UGI Utilities are included in our Consolidated Balance Sheets at September 30: 2020 2019 Regulatory assets (a): Income taxes recoverable $ 124 $ 115 Underfunded pension and postretirement plans 175 179 Environmental costs 61 60 Removal costs, net 26 28 Other 11 14 Total regulatory assets $ 397 $ 396 Regulatory liabilities (a): Postretirement benefit overcollections $ 13 $ 15 Deferred fuel and power refunds 29 6 State income tax benefits — distribution system repairs 28 25 PAPUC Temporary Rates Order 7 31 Excess federal deferred income taxes 274 280 Other 2 2 Total regulatory liabilities $ 353 $ 359 (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, 2020
Inventory Disclosure [Abstract]
Components of Inventories	Inventories comprise the following at September 30: 2020 2019 Non-utility LPG and natural gas $ 164 $ 150 Gas Utility natural gas 20 27 Materials, supplies and other 57 53 Total inventories $ 241 $ 230

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Sep. 30, 2020
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	At September 30, 2020, estimated useful lives by asset type were as follows: Asset Type Minimum Estimated Useful Life Maximum Estimated Useful Life Buildings and improvements 10 40 Equipment, primarily cylinders and tanks 5 30 Electricity generation facilities 25 40 Pipeline and related assets 25 40 Transportation equipment and office furniture and fixtures 3 10 Computer software 1 10 Property, plant and equipment comprise the following at September 30: 2020 2019 Utility: Distribution $ 3,630 $ 3,366 Transmission 111 106 General and other 425 389 Work in process 99 77 Total Utility 4,265 3,938 Non-utility: Land 191 184 Buildings and improvements 431 404 Transportation equipment 248 258 Equipment, primarily cylinders and tanks 3,712 3,455 Electric generation 211 327 Pipeline and related assets 1,098 1,150 Other 306 255 Work in process 196 102 Total non-utility 6,393 6,135 Total property, plant and equipment $ 10,658 $ 10,073

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Sep. 30, 2020
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, 2018 $ 2,004 $ 964 $ 10 $ 182 $ 3,160 Acquisitions — 26 330 — 356 Foreign currency translation — (60) — — (60) 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
Schedule of Finite-Lived Intangible Assets	Intangible assets comprise the following at September 30: 2020 2019 Customer relationships $ 1,083 $ 1,038 Trademarks and tradenames 12 16 Noncompete agreements and other 76 48 Accumulated amortization (543) (442) Intangible assets, net (definite-lived) 628 660 Trademarks and tradenames (indefinite-lived) 49 49 Total intangible assets, net $ 677 $ 709
Schedule of Indefinite-Lived Intangible Assets	Intangible assets comprise the following at September 30: 2020 2019 Customer relationships $ 1,083 $ 1,038 Trademarks and tradenames 12 16 Noncompete agreements and other 76 48 Accumulated amortization (543) (442) Intangible assets, net (definite-lived) 628 660 Trademarks and tradenames (indefinite-lived) 49 49 Total intangible assets, net $ 677 $ 709

Common Stock and Equity-Based_2

Common Stock and Equity-Based Compensation (Tables)	12 Months Ended
	Sep. 30, 2020
Share-based Payment Arrangement [Abstract]
Common Stock Share Activity	UGI Common Stock share activity for Fiscal 2020, Fiscal 2019 and Fiscal 2018 is as follows: Issued Treasury Outstanding Balance at September 30, 2017 173,987,691 (843,954) 173,143,737 Issued: Employee and director plans 155,306 1,804,712 1,960,018 Repurchases of common stock — (1,200,000) (1,200,000) Reacquired common stock – employee and director plans — (154,780) (154,780) 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 September 30, 2020 209,514,044 (1,159,606) 208,354,438
Stock Option Awards	Stock option transactions under equity-based compensation plans during Fiscal 2020, Fiscal 2019 and Fiscal 2018 are as follows: Shares Weighted - Total Weighted - Shares under option — September 30, 2017 8,781,748 $ 30.20 $ 147 6.3 Granted 1,401,400 $ 47.85 Canceled (152,017) $ 42.14 Expired (1,666) $ 35.80 Exercised (1,832,396) $ 26.00 $ 45 Shares under option — September 30, 2018 8,197,069 $ 33.93 $ 177 6.2 Granted 1,197,100 $ 53.27 Canceled (123,012) $ 48.69 Expired (13,699) $ 47.49 Exercised (779,353) $ 25.75 $ 23 Shares under option — September 30, 2019 8,478,105 $ 37.18 $ 115 5.9 Granted 1,893,700 $ 43.20 Canceled (57,668) $ 49.69 Expired (93,728) $ 37.81 Exercised (230,875) $ 22.65 $ 3 Shares under option — September 30, 2020 9,989,534 $ 38.58 $ 26 5.8 Options exercisable — September 30, 2018 5,498,330 $ 28.63 Options exercisable — September 30, 2019 5,963,530 $ 32.02 Options exercisable — September 30, 2020 6,898,251 $ 35.06 $ 26 4.5 Options not exercisable — September 30, 2020 3,091,283 $ 46.45 $ — 8.6
Additional Information Relating to Stock Options Outstanding and Exercisable	The following table presents additional information relating to stock options outstanding and exercisable at September 30, 2020: Range of exercise prices Under $30.00 $30.00 – $35.00 $35.01 – $40.00 $40.01 – $45.00 Over $45.01 Options outstanding at September 30, 2020: Number of options 2,672,041 1,297,358 858,565 177,947 4,983,623 Weighted average remaining contractual life (in years) 2.2 5.9 4.2 7.9 7.8 Weighted average exercise price $ 23.46 $ 33.30 $ 37.82 $ 44.07 $ 48.00 Options exercisable at September 30, 2020: Number of options 2,669,481 1,041,488 858,565 172,497 2,156,220 Weighted average exercise price $ 23.45 $ 33.65 $ 37.82 $ 44.12 $ 48.28
Assumptions Used for Valuing Option Grants	The assumptions we used for valuing option grants during Fiscal 2020, Fiscal 2019 and Fiscal 2018 are as follows: 2020 2019 2018 Expected life of option 6 years 6 years 6 years Weighted-average volatility 19.6% 17.2% 17.5% Weighted-average dividend yield 3.0% 1.8% 2.1% Expected volatility 19.6% 17.2% 17.5% Expected dividend yield 3.0% 1.8% 2.1% Risk free rate 0.3% - 1.7% 1.5% - 2.6% 2.2% - 2.9%
Weighted Average Assumptions Used to Determine the Fair Value of UGI Performance Unit Awards and Related Compensation Costs	The following table summarizes the weighted-average assumptions used to determine the fair value of UGI Performance Unit awards and related compensation costs: Grants Awarded in Fiscal Year 2020 2019 2018 Risk free rate 1.6% 2.5% 2.0% Expected life 3 years 3 years 3 years Expected volatility 18.6% 17.7% 18.9% Dividend yield 2.9% 1.9% 2.1%
UGI Performance Unit Award Activity	The following table summarizes UGI Unit award activity for Fiscal 2020: Weighted-Average Total UGI Units at September 30, 2019 (a) 893,820 $ 36.39 UGI Performance Units: Granted 222,410 $ 41.85 Forfeited (13,734) $ 40.01 Performance criteria not met (121,948) $ 46.76 UGI Stock Units: Granted (b) 77,951 $ 40.38 Unit awards paid (227,225) $ 24.31 Total UGI Units at September 30, 2020 (a) 831,274 $ 39.95 (a) Total UGI Units includes UGI Stock Units issued to non-employee directors, which vest on the grant date, and UGI Performance Units and UGI Stock Units issued to retirement-eligible employees that vest on an accelerated basis. Total vested restricted units at September 30, 2020 and 2019 were 441,498 and 616,319, respectively. (b) Generally, shares granted under UGI Stock Unit awards are paid approximately 70% in shares. UGI Stock Unit awards granted in Fiscal 2019 and Fiscal 2018 were 29,784 and 52,314, respectively.
Schedule of Payment for UGI Performance Unit and UGI Stock Unit Awards in Shares and Cash	During Fiscal 2020, Fiscal 2019 and Fiscal 2018, the Company paid UGI Performance Unit and UGI Stock Unit awards in shares and cash as follows: 2020 2019 2018 UGI Performance Unit awards: Number of original awards granted, net of forfeitures 121,948 144,521 136,621 Performance period beginning January 1: 2017 2016 2015 Payment of awards: Shares of UGI Common Stock issued, net of shares withheld for taxes — 116,950 69,680 Cash paid $ — $ 10 $ 2 UGI Stock Unit awards: Number of original awards granted, net of forfeitures 227,721 50,985 39,680 Payment of awards: Shares of UGI Common Stock issued, net of shares withheld for taxes 148,477 43,479 29,095 Cash paid $ 3 $ 1 $ 1

Leases (Tables)

Leases (Tables)	12 Months Ended
	Sep. 30, 2020
Leases [Abstract]
Assets And Liabilities Lessee	ROU assets and lease liabilities recorded in the Consolidated Balance Sheet as of September 30 are as follows: 2020 Location on the Balance Sheet ROU assets: Operating lease ROU assets $ 415 Other assets Finance lease ROU assets 52 Property, plant and equipment Total ROU assets $ 467 Lease liabilities: Operating lease liabilities — current $ 87 Other current liabilities Operating lease liabilities — noncurrent 334 Other noncurrent liabilities Finance lease liabilities — current 5 Current maturities of long-term debt Finance lease liabilities — noncurrent 41 Long-term debt Total lease liabilities $ 467
Components of Lease Expense, Lease Terms and Discount Rate, and Supplemental Cash Flow Information	The components of lease cost for Fiscal 2020 are as follows: 2020 Operating lease cost $ 102 Finance lease cost: Amortization of ROU assets 5 Interest on lease liabilities 3 Variable lease cost 5 Short-term lease cost 3 Total lease cost $ 118 The following table presents the cash and non-cash activity related to lease liabilities included in the Consolidated Statement of Cash Flows during Fiscal 2020: 2020 Cash paid related to lease liabilities: Operating cash flows — operating leases $ 103 Operating cash flows — finance leases $ 3 Financing cash flows — finance leases $ 4 Non-cash lease liability activities: ROU assets obtained in exchange for operating lease liabilities (including the impact upon adoption) $ 506 ROU assets obtained in exchange for finance lease liabilities $ 22 The following table presents the weighted-average remaining lease term and weighted-average discount rate as of September 30, 2020: Weighted-average remaining lease term In years Operating leases 6.2 Finance leases 2.4 Weighted-average discount rate % Operating leases 3.8% Finance leases 1.9%
Lessee, Operating Lease, Liability, Maturity	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, 2020, were as follows: 2021 2022 2023 2024 2025 After 2025 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 102 $ 86 $ 73 $ 63 $ 48 $ 109 $ 481 $ (60) $ 421 Finance leases $ 5 $ 4 $ 4 $ 3 $ 3 $ 83 $ 102 $ (56) $ 46
Finance Lease, Liability, Fiscal Year Maturity	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, 2020, were as follows: 2021 2022 2023 2024 2025 After 2025 Total Lease Payments Imputed Interest Lease Liabilities Operating leases $ 102 $ 86 $ 73 $ 63 $ 48 $ 109 $ 481 $ (60) $ 421 Finance leases $ 5 $ 4 $ 4 $ 3 $ 3 $ 83 $ 102 $ (56) $ 46
Schedule of Future Minimum Rental Payments for Operating Leases	, which were accounted for under ASC 840, were as follows: 2020 2021 2022 2023 2024 After Minimum operating lease payments $ 100 $ 86 $ 71 $ 62 $ 54 $ 139

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Sep. 30, 2020
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, 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 September 30, 2019 Derivative instruments: Assets: Commodity contracts $ 32 $ 10 $ — $ 42 Foreign currency contracts $ — $ 59 $ — $ 59 Liabilities: Commodity contracts $ (62) $ (113) $ — $ (175) Foreign currency contracts $ — $ (4) $ — $ (4) Interest rate contracts $ — $ (12) $ — $ (12) Non-qualified supplemental postretirement grantor trust investments (a) $ 40 $ — $ — $ 40 (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: 2020 2019 Carrying amount $ 6,081 $ 5,857 Estimated fair value $ 6,504 $ 6,189

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Sep. 30, 2020
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, 2020 and 2019 and the final settlement dates of the Company's open derivative contracts as of September 30, 2020, excluding those derivatives that qualified for the NPNS exception: Notional Amounts September 30, Type Units Settlements Extending Through 2020 2019 Commodity Price Risk: Regulated Utility Operations Gas Utility NYMEX natural gas futures and option contracts Dekatherms October 2021 22 23 Non-utility Operations LPG swaps Gallons February 2023 846 800 Natural gas futures, forward, basis swap, options and pipeline contracts Dekatherms December 2024 339 329 Electricity long forward and futures contracts Kilowatt hours January 2024 4,517 3,098 Electricity short forward and futures contracts Kilowatt hours April 2024 188 367 Interest Rate Risk: Interest rate swaps Euro October 2022 € 300 € 300 Interest rate swaps USD July 2024 $ 1,344 $ 1,357 Foreign Currency Exchange Rate Risk: Forward foreign exchange contracts USD September 2023 $ 511 $ 516 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: 2020 2019 Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 17 $ 17 Derivatives subject to PGC and DS mechanisms: Commodity contracts 7 1 Derivatives not designated as hedging instruments: Commodity contracts 100 41 Foreign currency contracts 15 42 115 83 Total derivative assets – gross 139 101 Gross amounts offset in the balance sheet (57) (29) Total derivative assets – net $ 82 $ 72 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts $ (55) $ (12) Derivatives subject to PGC and DS mechanisms: Commodity contracts — (4) Derivatives not designated as hedging instruments: Commodity contracts (118) (171) Foreign currency contracts (14) (4) (132) (175) Total derivative liabilities – gross (187) (191) Gross amounts offset in the balance sheet 57 29 Cash collateral pledged 7 29 Total derivative liabilities – net $ (123) $ (133)
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 2020, Fiscal 2019 and Fiscal 2018: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from 2020 2019 2018 2020 2019 2018 Cash Flow Hedges: Foreign currency contracts $ — $ 1 $ — $ — $ 2 $ (3) Cost of sales Cross-currency contracts — — 2 — — 1 Interest expense /other operating income, net Interest rate contracts (53) (11) — (13) (6) (5) Interest expense Total $ (53) $ (10) $ 2 $ (13) $ (4) $ (7) Net Investment Hedges: Foreign currency contracts $ (1) $ 17 $ — Gain (Loss) Location of 2020 2019 2018 Derivatives Not Designated as Hedging Instruments: Commodity contracts $ (32) $ (344) $ 155 Cost of sales Commodity contracts 10 7 (5) Revenues Foreign currency contracts (20) 38 16 Other non-operating (expense) income, net Total $ (42) $ (299) $ 166

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Sep. 30, 2020
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	Changes in AOCI during Fiscal 2020, Fiscal 2019 and Fiscal 2018 are as follows: Postretirement Derivative Foreign Total AOCI - September 30, 2017 $ (19) $ (21) $ (53) $ (93) Other comprehensive income (loss) before reclassification adjustments (after-tax) 10 1 (30) (19) Amounts reclassified from AOCI: Reclassification adjustments (pre-tax) (3) 7 — 4 Reclassification adjustments tax expense (benefit) 1 (3) — (2) Reclassification adjustments (after-tax) (2) 4 — 2 Other comprehensive income (loss) attributable to UGI 8 5 (30) (17) AOCI - September 30, 2018 $ (11) $ (16) $ (83) $ (110) Other comprehensive loss before reclassification adjustments (after-tax) (13) (7) (83) (103) Amounts reclassified from AOCI: Reclassification adjustments (pre-tax) 2 4 — 6 Reclassification adjustments tax benefit (1) (2) — (3) Reclassification adjustments (after-tax) 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: Reclassification adjustments (pre-tax) 4 13 — 17 Reclassification adjustments tax benefit (1) (4) — (5) Reclassification adjustments (after-tax) 3 9 — 12 Other comprehensive (loss) income attributable to UGI — (29) 99 70 AOCI - September 30, 2020 $ (26) $ (54) $ (67) $ (147)

Other Operating Income, Net a_2

Other Operating Income, Net and Other Non-Operating (Expense) Income, Net (Tables)	12 Months Ended
	Sep. 30, 2020
Component of Operating Income [Abstract]
Other Operating Income, Net	Other operating income, net, for Fiscal 2020, Fiscal 2019 and Fiscal 2018 comprises the following: 2020 2019 2018 Finance charges $ 9 $ 17 $ 16 Interest and interest-related income 2 6 3 Utility non-tariff service income — 1 3 Gains on sales of fixed assets, net 5 3 5 Other, net 5 4 5 Total other operating income, net $ 21 $ 31 $ 32
Schedule of Other Non-Operating Income (Expense)	Other non-operating (expense) income, net for Fiscal 2020, Fiscal 2019 and Fiscal 2018 comprises the following: 2020 2019 2018 (Losses) gains on foreign currency contracts, net $ (20) $ 38 $ 16 Pension and other postretirement plans non-service income, net — 1 — Total other non-operating (expense) income, net $ (20) $ 39 $ 16

Quarterly Data (unaudited) (Tab

Quarterly Data (unaudited) (Tables)	12 Months Ended
	Sep. 30, 2020
Quarterly Financial Data [Abstract]
Quarterly Data (unaudited)	The following unaudited quarterly data includes adjustments (consisting only of normal recurring adjustments with the exception of those indicated below) that we consider necessary for a fair presentation unless otherwise indicated. Our quarterly results fluctuate primarily because of the seasonal nature of our businesses and the effects of unrealized gains and losses on commodity and certain foreign currency derivative instruments (see Note 19) and other significant discrete items that can affect the comparison of period-over-period results. December 31, March 31, June 30, September 30, 2019 2018 2020 2019 2020 2019 2020 2019 Revenues $ 2,007 $ 2,200 $ 2,229 $ 2,606 $ 1,199 $ 1,364 $ 1,124 $ 1,150 Operating income (loss) $ 377 $ 168 $ 362 $ 539 $ 174 $ 9 $ 69 $ (99) Net income (loss) including noncontrolling interests $ 212 $ 89 $ 226 $ 396 $ 84 $ (46) $ 10 $ (131) Net income (loss) attributable to UGI Corporation $ 212 $ 64 $ 226 $ 246 $ 85 $ (2) $ 9 $ (52) Earnings (loss) per common share attributable to UGI Corporation stockholders: Basic $ 1.01 $ 0.37 $ 1.08 $ 1.41 $ 0.41 $ (0.01) $ 0.05 $ (0.27) Diluted $ 1.00 $ 0.36 $ 1.07 $ 1.38 $ 0.41 $ (0.01) $ 0.05 $ (0.27) Weighted-average common shares outstanding (thousands): Basic 209,439 174,413 208,941 174,501 208,598 174,759 208,655 189,905 Diluted 211,258 177,566 209,808 177,318 208,975 174,759 209,357 189,905 (a) Includes loss on extinguishments of debt at UGI International which reduced net income attributable to UGI by $4. (b) Includes impairment of Conemaugh assets held-for-sale at Midstream & Marketing which reduced net income attributable to UGI by $37 (see Note 5). (c) Weighted-average common shares outstanding includes the impact from the August 2019 issuance of 34,613 thousand shares of UGI Common Stock in connection with the AmeriGas Merger (see Note 5).

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Sep. 30, 2020
Segment Reporting [Abstract]
Schedule of Segment Reporting Information	Total Elim- AmeriGas UGI International Midstream UGI Utilities Corporate & 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 (c) $ 140 $ 229 $ (1) Income from equity investees 27 — — — 27 (d) — — Other non-operating (expense) income, net (20) — — 18 1 — (39) Earnings (losses) before interest expense and income taxes 989 — 373 259 168 229 (40) Interest expense (322) — (164) (31) (42) (54) (31) Income tax (expense) benefit (135) — (53) (55) (34) (39) 46 Net income (loss) attributable to UGI $ 532 $ — $ 156 $ 173 $ 92 $ 136 $ (25) Depreciation and amortization $ 484 $ — $ 178 $ 125 $ 75 $ 105 $ 1 Total assets $ 13,985 $ (282) $ 4,327 $ 3,123 $ 2,775 $ 3,809 $ 233 Short-term borrowings $ 347 $ — $ 186 $ 1 $ 19 $ 141 $ — Capital expenditures (including the effects of accruals) $ 665 $ — $ 135 $ 89 $ 93 $ 348 $ — Investments in equity investees $ 200 $ — $ — $ 10 $ 190 $ — $ — 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 (d) — — Loss on extinguishments of debt (6) — — — — — (6) Other non-operating income (expense), net 39 (1) — 5 — 2 33 Earnings (losses) 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) Total Elim- AmeriGas UGI International Midstream UGI Utilities Corporate & 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 $ — $ — 2018 Revenues from external customers $ 7,651 $ — $ 2,823 $ 2,684 $ 1,149 $ 998 $ (3) Intersegment revenues $ — $ (371) (b) $ — $ — $ 273 $ 94 $ 4 Cost of sales $ 4,075 $ (367) (b) $ 1,315 $ 1,620 $ 1,091 $ 523 $ (107) Operating income (loss) $ 1,065 $ 1 $ 422 $ 248 $ 175 $ 240 $ (21) Income (loss) from equity investees 4 — — (1) 5 (d) — — Other non-operating income (expense), net 16 (1) — (7) (1) (2) 27 Earnings before interest expense and income taxes 1,085 — 422 240 179 238 6 Interest expense (230) — (163) (21) (2) (43) (1) Income tax (expense) benefit (e) (33) (1) (31) (69) (50) (54) 172 Noncontrolling interests’ net (income) loss (103) — (152) 3 — — 46 Net income (loss) attributable to UGI $ 719 $ (1) $ 76 $ 153 $ 127 $ 141 $ 223 Depreciation and amortization $ 455 $ — $ 186 $ 141 $ 43 $ 85 $ — Total assets $ 11,981 $ (125) $ 3,934 $ 3,279 $ 1,329 $ 3,266 $ 298 Short-term borrowings $ 425 $ — $ 232 $ 1 $ 2 $ 190 $ — Capital expenditures (including the effects of accruals) $ 597 $ — $ 101 $ 111 $ 43 $ 339 $ 3 Investments in equity investees $ 88 $ — $ — $ 13 $ 75 $ — $ — (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 2020, Fiscal 2019 and Fiscal 2018: Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing 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) LPG 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) LPG business transformation expenses Operating and administrative expenses $ (15) $ (9) $ — 2018 Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (4) Net gains (losses) on commodity derivative instruments not associated with current-period transactions Cost of Sales $ 13 $ 93 $ 2 Unrealized gains on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 29 $ — Integration expenses associated with Finagaz Operating and administrative expenses $ — $ (31) $ — Impairment of Partnership tradenames and trademarks Impairment of Partnership tradenames and trademarks $ (75) $ — $ — (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. (d) Fiscal 2020 and Fiscal 2019 also includes income from Pennant subsequent to the CMG Acquisition (see Note 5). Includes AFUDC associated with PennEast (see Note 2).

SCHEDULE I _ CONDENSED FINANC_2

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) (Tables)	12 Months Ended
	Sep. 30, 2020
Condensed Financial Information Disclosure [Abstract]
Condensed Balance Sheet	BALANCE SHEETS (Millions of dollars) September 30, 2020 2019 ASSETS Current assets: Cash and cash equivalents $ 67 $ 54 Accounts receivable – related parties 11 5 Prepaid expenses and other current assets 15 23 Total current assets 93 82 Property, plant and equipment, net 2 3 Investments in subsidiaries 4,898 4,585 Other assets 87 77 Total assets $ 5,080 $ 4,747 LIABILITIES AND COMMON STOCKHOLDERS’ EQUITY Current liabilities: Current maturities of long-term debt $ 30 $ — Accounts and notes payable 15 15 Accrued liabilities 29 9 Total current liabilities 74 24 Long-term debt 817 846 Other noncurrent liabilities 61 60 Total liabilities 952 930 Commitments and contingencies (Note 1) Common stockholders’ equity: Common Stock, without par value (authorized – 450,000,000 shares; issued – 209,514,044 and 209,304,129 shares, respectively) 1,416 1,397 Retained earnings 2,908 2,653 Accumulated other comprehensive loss (147) (217) Treasury stock, at cost (49) (16) Total common stockholders’ equity 4,128 3,817 Total liabilities and common stockholders’ equity $ 5,080 $ 4,747
Condensed Income Statement	STATEMENTS OF INCOME (Millions of dollars, except per share amounts) Year Ended September 30, 2020 2019 2018 Revenues $ — $ — $ — Costs and expenses: Operating and administrative expenses 56 50 63 Other operating income, net (a) (54) (50) (52) 2 — 11 Operating loss (2) — (11) Pension and other postretirement plans non-service expense — (1) (1) Interest expense (32) (6) — Loss before income taxes (34) (7) (12) Income tax expense (benefit) 17 (3) 6 Loss before equity in income of unconsolidated subsidiaries (51) (4) (18) Equity in income of unconsolidated subsidiaries 583 260 737 Net income attributable to UGI Corporation $ 532 $ 256 $ 719 Other comprehensive (loss) income (12) (3) 3 Equity in other comprehensive income (loss) of unconsolidated subsidiaries 82 (97) (20) Comprehensive income attributable to UGI Corporation $ 602 $ 156 $ 702 Earnings per common share attributable to UGI Corporation stockholders: Basic $ 2.55 $ 1.44 $ 4.13 Diluted $ 2.54 $ 1.41 $ 4.06 Weighted - average common shares outstanding (thousands): Basic 208,928 178,417 173,908 Diluted 209,869 181,111 176,905
Condensed Cash Flow Statement	STATEMENTS OF CASH FLOWS (Millions of dollars) Year Ended September 30, 2020 2019 2018 NET CASH PROVIDED BY OPERATING ACTIVITIES (a) $ 322 $ 170 $ 208 CASH FLOWS FROM INVESTING ACTIVITIES: Expenditures for property, plant and equipment — — (2) Net investments in unconsolidated subsidiaries — (768) (7) Net cash used by investing activities — (768) (9) CASH FLOWS FROM FINANCING ACTIVITIES: Payment of dividends on Common Stock (273) (200) (177) Issuances of debt, net of issuance costs 60 846 — Repayments of long-term debt (60) — — Issuances of Common Stock 2 17 35 Repurchases of UGI Common Stock (38) (17) (60) Other — (7) — Net cash (used) provided by financing activities (309) 639 (202) Cash and cash equivalents increase (decrease) $ 13 $ 41 $ (3) Cash and cash equivalents: End of year $ 67 $ 54 $ 13 Beginning of year 54 13 16 Cash and cash equivalents increase (decrease) $ 13 $ 41 $ (3) (a) Includes dividends received from unconsolidated subsidiaries of $352, $163 and $191 for the years ended September 30, 2020, 2019 and 2018, respectively.

Nature of Operations (Details)

Nature of Operations (Details) $ in Millions	Aug. 21, 2019USD ($)shares	Aug. 20, 2019	Aug. 01, 2019shares	Sep. 30, 2020county	Sep. 30, 2019shares
Investment [Line Items]
Number of counties of operation | county				1
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%
AmeriGas Propane | AmeriGas OLP
Investment [Line Items]
Effective ownership interest in AmeriGas OLP (as a percentage)		27.00%
Merger Sub
Investment [Line Items]
Total cash paid | $	$ 529
Merger Sub | Common Stock
Investment [Line Items]
Consideration paid (in shares) | shares	34,612,847		34,613,000		34,613,000

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Principles of Consolidation (Details)	12 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Ownership interests in certain subsidiaries under equity method investment, maximum	100.00%

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Equity Method Investments (Details) $ in Millions	12 Months Ended
	Sep. 30, 2020USD ($)mi	Sep. 30, 2019USD ($)	Aug. 01, 2019	Sep. 30, 2018USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Investments	$ 256	$ 242
Equity method investments	200	190		$ 88
Pennant
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Equity method investments	$ 94	91
Southern Company | PennEast
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Ownership percentage (as a percentage)	20.00%
Enbridge Inc | PennEast
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Ownership percentage (as a percentage)	20.00%
South Jersey Industries | PennEast
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Ownership percentage (as a percentage)	20.00%
UGI PennEast, LLC | PennEast
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Equity method investments	$ 96	$ 85
New Jersey Resources | PennEast
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Ownership percentage (as a percentage)	20.00%
PennEast
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Area of natural gas pipeline to be constructed (in miles) | mi	120
Pipeline contract term	15 years
Affiliated Entity | UGI PennEast, LLC | PennEast
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Ownership percentage (as a percentage)	20.00%
Pennant | Affiliated Entity | CMG
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Percentage of voting interests acquired		47.00%	47.00%

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Revenue Recognition (Details)	12 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Contract length (less than)	one year

Summary of Significant Accoun_7

Summary of Significant Accounting Policies - Income Taxes (Details)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Accounting Policies [Abstract]
Effective income tax rate reconciliation, at federal statutory income tax rate, percent (as a percentage)	21.00%	21.00%	24.50%

Summary of Significant Accoun_8

Summary of Significant Accounting Policies - Shares Used in Computing Basic and Diluted Earnings Per Share (Details) - shares	Aug. 21, 2019	Aug. 01, 2019	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Weighted-average common shares outstanding for basic computation (in shares)			208,655,000	208,598,000	208,941,000	209,439,000	189,905,000	174,759,000	174,501,000	174,413,000	208,928,000	178,417,000	173,908,000
Incremental shares issuable for stock options and common stock awards (in shares)											941,000	2,694,000	2,997,000
Weighted-average common shares outstanding for diluted computation (in shares)			209,357,000	208,975,000	209,808,000	211,258,000	189,905,000	174,759,000	177,318,000	177,566,000	209,869,000	181,111,000	176,905,000
Antidilutive securities excluded from computation of earnings per share (in shares)											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										34,613,000

Summary of Significant Accoun_9

Summary of Significant Accounting Policies - Reconciliation of the total cash, cash equivalents and restricted cash (Details) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2017
Accounting Policies [Abstract]
Cash and cash equivalents	$ 336	$ 447	$ 452	$ 558
Restricted cash	21	64	10	11
Cash, cash equivalents and restricted cash	$ 357	$ 511	$ 462	$ 569

Summary of Significant Accou_10

Summary of Significant Accounting Policies - Estimated Useful Lives by Type (Details)	12 Months Ended
	Sep. 30, 2020
Buildings and improvements | Minimum
Property, Plant and Equipment
Useful life (in years)	10 years
Buildings and improvements | Maximum
Property, Plant and Equipment
Useful life (in years)	40 years
Equipment, primarily cylinders and tanks | Minimum
Property, Plant and Equipment
Useful life (in years)	5 years
Equipment, primarily cylinders and tanks | Maximum
Property, Plant and Equipment
Useful life (in years)	30 years
Electricity generation facilities | Minimum
Property, Plant and Equipment
Useful life (in years)	25 years
Electricity generation facilities | Maximum
Property, Plant and Equipment
Useful life (in years)	40 years
Pipeline and related assets | Minimum
Property, Plant and Equipment
Useful life (in years)	25 years
Pipeline and related assets | Maximum
Property, Plant and Equipment
Useful life (in years)	40 years
Transportation equipment and office furniture and fixtures | Minimum
Property, Plant and Equipment
Useful life (in years)	3 years
Transportation equipment and office furniture and fixtures | Maximum
Property, Plant and Equipment
Useful life (in years)	10 years
Computer software | Minimum
Property, Plant and Equipment
Useful life (in years)	1 year
Computer software | Maximum
Property, Plant and Equipment
Useful life (in years)	10 years

Summary of Significant Accou_11

Summary of Significant Accounting Policies - Average Composite Depreciation Rates (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory assets	$ 0	$ 0
Depreciation	$ 416,000,000	$ 389,000,000	$ 397,000,000
Amortization period	5 years
Gas Utility
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates (as a percentage)	2.50%	2.20%	2.30%
Electric Utility
Public Utility, Property, Plant and Equipment [Line Items]
Average composite depreciation rates (as a percentage)	2.20%	2.10%	2.20%
UGI Utilities
Public Utility, Property, Plant and Equipment [Line Items]
Regulatory assets	$ 397,000,000	$ 396,000,000
Computer software | UGI Utilities
Public Utility, Property, Plant and Equipment [Line Items]
Useful life (in years)	15 years

Summary of Significant Accou_12

Summary of Significant Accounting Policies - Goodwill and Intangible Assets (Details) - USD ($)	1 Months Ended	12 Months Ended
	Apr. 30, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Finite-Lived Intangible Assets [Line Items]
Useful life				3 years
Impairment of intangible assets, finite-lived		$ 0	$ 0	$ 75,000,000
Finite-lived trademarks and tradenames, gross				8,000,000
Accumulated impairment losses		0	0
Provision for goodwill or other intangible asset impairments		$ 0	$ 0	$ 0
Trademarks and tradenames
Finite-Lived Intangible Assets [Line Items]
Useful life	3 years
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_13

Summary of Significant Accounting Policies - Impairment of Long-Lived Assets and Cost Basis Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Accounting Policies [Abstract]
Provisions for impairments	$ 0	$ 0

Summary of Significant Accou_14

Summary of Significant Accounting Policies - Leases (Details) - USD ($) $ in Millions	Oct. 01, 2019	Sep. 30, 2018	Sep. 30, 2020
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Accounting Standards Update [Extensible List]	us-gaap:AccountingStandardsUpdate201602Member	us-gaap:AccountingStandardsUpdate201409Member
Operating lease ROU assets			$ 415
Lease liabilities			$ 421
ASU 2016-02
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease ROU assets	$ 452
Lease liabilities	$ 452

Summary of Significant Accou_15

Summary of Significant Accounting Policies - Refundable Tank and Cylinder Deposits (Details) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019
Accounting Policies [Abstract]
Customer paid deposits primarily on owned tanks and cylinders	$ 300	$ 280

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Disaggregation of Revenue [Line Items]
Contract with customer, liability	$ 115	$ 114
Contract with customer, liability, revenue recognized	$ 89	$ 91
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	$ 1,900
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	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									$ 6,452	$ 7,211
Other revenues									107	109
Total revenues	$ 1,124	$ 1,199	$ 2,229	$ 2,007	$ 1,150	$ 1,364	$ 2,606	$ 2,200	6,559	7,320	$ 7,651
Negative surcharge										6
Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									563	553
Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									215	226
Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									142	138
Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									48	46
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									14	15
Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									982	978
Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									3,499	4,008
Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									211	233
Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,233	1,521
Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									168	95
Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									6	17
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									7	2
Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									34	43
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									312	314
Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									5,470	6,233
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									(229)	(302)
Other revenues									(3)	(4)
Total revenues									(232)	(306)	(371)
Eliminations | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Eliminations | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Eliminations | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Eliminations | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									(45)	(65)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									(2)	(3)
Eliminations | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									(47)	(68)
Eliminations | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Eliminations | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Eliminations | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									(79)	(134)
Eliminations | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Eliminations | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									(100)	(97)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Eliminations | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									(3)	(3)
Eliminations | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									(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									182	235	273
Eliminations | UGI Utilities
Disaggregation of Revenue [Line Items]
Total revenues									47	68	94
Operating Segments | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									2,315	2,618
Other revenues									66	64
Total revenues									2,381	2,682	2,823
Operating Segments | AmeriGas Propane | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | AmeriGas Propane | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | AmeriGas Propane | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									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
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | AmeriGas Propane | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | AmeriGas Propane | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									2,037	2,341
Operating Segments | AmeriGas Propane | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									63	64
Operating Segments | AmeriGas Propane | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | AmeriGas Propane | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | AmeriGas Propane | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | AmeriGas Propane | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									215	213
Operating Segments | AmeriGas Propane | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									2,315	2,618
Operating Segments | UGI International
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									2,104	2,339
Other revenues									23	33
Total revenues									2,127	2,372	$ 2,684
Operating Segments | UGI International | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI International | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI International | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									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
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI International | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI International | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,462	1,667
Operating Segments | UGI International | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									148	169
Operating Segments | UGI International | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									434	448
Operating Segments | UGI International | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI International | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI International | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									60	55
Operating Segments | UGI International | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									2,104	2,339
Operating Segments | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,233	1,510
Other revenues									14	6
Total revenues									1,247	1,516
Operating Segments | Midstream & Marketing | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | Midstream & Marketing | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | Midstream & Marketing | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									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
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | Midstream & Marketing | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | Midstream & Marketing | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | Midstream & Marketing | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | Midstream & Marketing | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									878	1,207
Operating Segments | Midstream & Marketing | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									168	95
Operating Segments | Midstream & Marketing | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									106	114
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									7	2
Operating Segments | Midstream & Marketing | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									34	43
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									40	49
Operating Segments | Midstream & Marketing | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,233	1,510
Operating Segments | UGI Utilities
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,029	1,046
Other revenues									1	3
Total revenues									1,030	1,049
Operating Segments | UGI Utilities | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									563	553
Operating Segments | UGI Utilities | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									215	226
Operating Segments | UGI Utilities | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									142	138
Operating Segments | UGI Utilities | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									93	111
Operating Segments | UGI Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									16	18
Operating Segments | UGI Utilities | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									1,029	1,046
Operating Segments | UGI Utilities | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI Utilities | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI Utilities | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI Utilities | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI Utilities | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI Utilities | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Operating Segments | UGI Utilities | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Other revenues									6	7
Total revenues									6	7
Corporate & Other | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									0	0
Corporate & Other | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers									$ 0	$ 0

AmeriGas Merger, Acquisitions_3

AmeriGas Merger, Acquisitions and Dispositions - Narrative (Details) $ / shares in Units, $ in Millions	Aug. 21, 2019USD ($)$ / sharesshares	Aug. 01, 2019USD ($)shares	Sep. 30, 2020USD ($)	Jun. 30, 2020USD ($)	Sep. 30, 2019USD ($)shares	Sep. 30, 2018USD ($)propane_distribution_business	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%
Merger Sub
Statement [Line Items]
Total cash paid	$ 529
Incentive distribution, distribution	2,228
After tax transaction costs	8
Operating expenses	6
Deferred tax asset, step up in tax basis of the underlying assets	$ 512				$ 512
Merger Sub | Common Stock
Statement [Line Items]
Consideration paid (in shares) | shares	34,612,847	34,613,000			34,613,000
CMG
Statement [Line Items]
After tax transaction costs					$ 15
Total cash paid		$ 1,284
Merger Agreement, Proposed Consideration One | Merger Sub | Common Stock
Statement [Line Items]
Business combination, consideration transferred, equity interests issuable per acquiree share (in shares) | shares	0.6378
Merger Agreement, Proposed Consideration Two | Merger Sub | Common Stock
Statement [Line Items]
Business combination, consideration transferred, equity interests issuable per acquiree share (in shares) | shares	0.500
Merger Agreement, Proposed Consideration Two | Merger Sub | Cash Without Interest
Statement [Line Items]
Business combination, consideration transferred, equity interests issuable per share (in dollars per share) | $ / shares	$ 7.63
Merger Agreement, Proposed Consideration Three | Merger Sub | Cash Without Interest
Statement [Line Items]
Business combination, consideration transferred, equity interests issuable per share (in dollars per share) | $ / shares	$ 35.325
AmeriGas Propane
Statement [Line Items]
Incentive distribution, distribution						$ 13
Total cash paid						$ 10
Number of retail propane distribution businesses acquired | propane_distribution_business						2
Affiliated Entity | CMG | Pennant
Statement [Line Items]
Percentage of voting interests acquired (as a percentage)		47.00%			47.00%

AmeriGas Merger, Acquisitions_4

AmeriGas Merger, Acquisitions and Dispositions - Components of Final Purchase Price Allocation (Details) - USD ($) $ in Millions	Aug. 01, 2019	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Liabilities assumed:
Goodwill		$ 3,518	$ 3,456	$ 3,160
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_5

AmeriGas Merger, Acquisitions and Dispositions - Total Cash Paid and Liabilities Incurred (Details) $ in Millions	12 Months Ended
	Sep. 30, 2020USD ($)mi	Sep. 30, 2019USD ($)miMW	Sep. 30, 2018USD ($)
Business Acquisition [Line Items]
Natural gas lines, acquired (in miles) | mi	21	60
Payments to acquire long-term investments	$ 20	$ 70
Natural gas-fired peaking turbine, acquired (mw) | MW		44
UGI International
Business Acquisition [Line Items]
Total cash paid		$ 49	$ 122
Liabilities incurred		0	0
Total purchase price		49	122
Midstream & Marketing
Business Acquisition [Line Items]
Total cash paid	16	15
Liabilities incurred	7	0
Total purchase price	$ 23	$ 15
AmeriGas Propane
Business Acquisition [Line Items]
Total cash paid			10
Liabilities incurred			3
Total purchase price			$ 13

Debt - Energy Services (Details

Debt - Energy Services (Details) - Energy Services - USD ($)	Mar. 06, 2020	Sep. 30, 2020	Sep. 30, 2019
Debt Instrument [Line Items]
Maximum borrowing capacity		$ 260,000,000	$ 200,000,000
Line of Credit | Energy Services Credit Agreement
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 260,000,000
Line of credit facility accordion feature increase limit	$ 325,000,000
Variable interest rate floor (as a percentage)	1.00%
Line of Credit | Energy Services Credit Agreement | Minimum
Debt Instrument [Line Items]
Variable interest rate floor (as a percentage)	0.75%
Line of Credit | Energy Services Credit Agreement | Maximum
Debt Instrument [Line Items]
Variable interest rate floor (as a percentage)	2.75%
Line of Credit | Energy Services Credit Agreement | Federal Funds Effective Swap Rate
Debt Instrument [Line Items]
Basis spread on variable rate (as a percentage)	0.50%
Line of Credit | Energy Services Credit Agreement | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Basis spread on variable rate (as a percentage)	1.00%
Line of Credit | Energy Services Credit Agreement | Alternate Rate And Adjusted L I B O R | Minimum
Debt Instrument [Line Items]
Variable interest rate floor (as a percentage)	1.50%
Line of Credit | Energy Services Credit Agreement | Alternate Rate And Adjusted L I B O R | Maximum
Debt Instrument [Line Items]
Variable interest rate floor (as a percentage)	2.50%
Letter of Credit | Line of Credit | Energy Services Credit Agreement
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 50,000,000

Debt - UGI Utilities (Details)

Debt - UGI Utilities (Details) - UGI Utilities - Senior Notes - 3.12% Senior Notes due April 2050	Apr. 16, 2020USD ($)
Debt Instrument [Line Items]
Debt instrument, face amount	$ 150,000,000
Stated interest rate (as a percentage)	3.12%

Debt - Schedule of Short-term D

Debt - Schedule of Short-term Debt (Details)	Sep. 30, 2020USD ($)	Sep. 30, 2020EUR (€)	Sep. 30, 2019USD ($)	Sep. 30, 2019EUR (€)
Short-term Debt [Line Items]
Weighted Average Interest Rate - End of Year			6.25%	6.25%
AmeriGas OLP
Short-term Debt [Line Items]
Total Capacity	$ 600,000,000		$ 600,000,000
Borrowings Outstanding	186,000,000		328,000,000
Letters of Credit and Guarantees Outstanding	$ 62,000,000		$ 63,000,000
Available Borrowing Capacity | €		€ 352,000,000		€ 209,000,000
Weighted Average Interest Rate - End of Year	2.61%	2.61%	4.50%	4.50%
UGI International LLC
Short-term Debt [Line Items]
Total Capacity | €		€ 300,000,000		€ 300,000,000
Borrowings Outstanding		0	$ 210,000,000	193,000,000
Letters of Credit and Guarantees Outstanding | €		0		0
Available Borrowing Capacity | €		300,000,000		€ 107,000,000
Weighted Average Interest Rate - End of Year			3.64%	3.64%
Energy Services
Short-term Debt [Line Items]
Total Capacity	$ 260,000,000		$ 200,000,000
Borrowings Outstanding	0		45,000,000
Letters of Credit and Guarantees Outstanding	0		0
Available Borrowing Capacity | €		260,000,000		€ 155,000,000
UGI Utilities
Short-term Debt [Line Items]
Total Capacity	350,000,000		350,000,000
Borrowings Outstanding	141,000,000		166,000,000
Letters of Credit and Guarantees Outstanding	$ 0		$ 0
Available Borrowing Capacity | €		€ 209,000,000		€ 184,000,000
Weighted Average Interest Rate - End of Year	1.12%	1.12%	3.00%	3.00%
UGI Corporation
Short-term Debt [Line Items]
Total Capacity	$ 300,000,000		$ 300,000,000
Borrowings Outstanding	300,000,000		300,000,000
Letters of Credit and Guarantees Outstanding	$ 0		$ 0
Available Borrowing Capacity | €		€ 0		€ 0
Weighted Average Interest Rate - End of Year	2.41%	2.41%	4.55%	4.55%

Debt - Schedule of Short-term_2

Debt - Schedule of Short-term Debt (Footnotes) (Details)	1 Months Ended	12 Months Ended
	Oct. 31, 2020USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)	Sep. 30, 2020EUR (€)	Sep. 30, 2019EUR (€)
Short-term Debt [Line Items]
Repayment of debt		$ 86,000,000	$ 738,000,000	$ 149,000,000
AmeriGas OLP
Short-term Debt [Line Items]
Maximum borrowing capacity		600,000,000	600,000,000
Borrowing		186,000,000	328,000,000
AmeriGas OLP | Letter of Credit | 2019 Credit Agreement | Line of Credit
Short-term Debt [Line Items]
Maximum borrowing capacity		150,000,000
UGI International LLC
Short-term Debt [Line Items]
Maximum borrowing capacity | €					€ 300,000,000	€ 300,000,000
Borrowing			210,000,000		€ 0	€ 193,000,000
Energy Services
Short-term Debt [Line Items]
Maximum borrowing capacity		260,000,000	200,000,000
Borrowing		0	45,000,000
Energy Services | Letter of Credit | 2019 Credit Agreement | Line of Credit
Short-term Debt [Line Items]
Maximum borrowing capacity		50,000,000
UGI Utilities
Short-term Debt [Line Items]
Maximum borrowing capacity		350,000,000	350,000,000
Borrowing		141,000,000	166,000,000
UGI Utilities | Letter of Credit | 2019 Credit Agreement | Line of Credit
Short-term Debt [Line Items]
Maximum borrowing capacity		100,000,000
UGI Corporation
Short-term Debt [Line Items]
Maximum borrowing capacity		300,000,000	300,000,000
Borrowing		300,000,000	$ 300,000,000
UGI Corporation | Subsequent Event
Short-term Debt [Line Items]
Repayment of debt	$ 30,000,000
UGI Corporation | Letter of Credit | 2019 Credit Agreement | The 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 ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Short-term Debt [Line Items]
Trade receivables transferred to ESFC during the year	$ 1,046	$ 1,373	$ 1,280
Trade receivables transferred to ESFC during the year	182	179	193
ESFC trade receivables - end of year	50	55	$ 65
Outstanding balance of trade receivables sold	$ 19	$ 46

Debt - Schedule of Long-term De

Debt - Schedule of Long-term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019
Debt Instrument [Line Items]
Total long-term debt	$ 6,034	$ 5,804
Less: current maturities	(53)	(24)
Total long-term debt due after one year	5,981	5,780
AmeriGas Propane
Debt Instrument [Line Items]
Unamortized debt issuance costs	(20)	(24)
Total long-term debt	2,560	2,565
AmeriGas Propane | Other
Debt Instrument [Line Items]
Long-term debt, gross	$ 5	14
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	(7)	(8)
Total long-term debt	$ 778	719
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	$ 410	382
UGI International | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	352	327
Other
Debt Instrument [Line Items]
Total long-term debt	8	8
Other | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	23	18
Midstream & Marketing:
Debt Instrument [Line Items]
Unamortized debt issuance costs	(12)	(12)
Total long-term debt	720	687
Midstream & Marketing: | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	41	1
Midstream & Marketing: | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	691	698
UGI Utilities
Debt Instrument [Line Items]
Unamortized debt issuance costs	(5)	(5)
Total long-term debt	$ 1,121	979
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	0
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 | Other | Other
Debt Instrument [Line Items]
Long-term debt, gross	3	5
UGI Utilities | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Long-term debt, gross	$ 108	114
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 Coporation
Debt Instrument [Line Items]
Unamortized debt issuance costs	(3)	(4)
Total long-term debt	847	846
UGI Coporation | Term Loan | 3-year Term loan
Debt Instrument [Line Items]
Long-term debt, gross	300	300
UGI Coporation | Term Loan | 5-year Term Loan
Debt Instrument [Line Items]
Long-term debt, gross	250	250
UGI Coporation | Line of Credit
Debt Instrument [Line Items]
Long-term debt, gross	$ 300	$ 300

Debt - Schedule of Long-term _2

Debt - Schedule of Long-term Debt (Footnotes) (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
AmeriGas Propane | Senior Secured Notes | HOLP Senior Secured Notes
Debt Instrument [Line Items]
Effective interest rate (as a percentage)		6.75%
UGI International | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	2.04%	2.04%
Midstream & Marketing | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	5.30%	5.79%
Quarterly Installments	$ 2,000,000
UGI Utilities | Term Loan | Variable-rate term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	4.00%	3.05%
Quarterly Installments	$ 2,000,000
UGI Coporation | Term Loan | 3-year Term loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	3.51%	4.30%
UGI Coporation | Term Loan | 5-year Term Loan
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	3.50%	4.55%
Quarterly Installments	$ 9,000,000
UGI Coporation | Line of Credit
Debt Instrument [Line Items]
Effective interest rate (as a percentage)	2.41%	4.55%

Debt - Schedule of Principal Re

Debt - Schedule of Principal Repayments of Long-term Debt (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Oct. 31, 2020	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Debt Instrument [Line Items]
2021		$ 53
2022		339
2023		147
2024		1,516
2025		707
Repayment of debt		86	$ 738	$ 149
AmeriGas Propane
Debt Instrument [Line Items]
2021		3
2022		2
2023		0
2024		675
2025		700
UGI International
Debt Instrument [Line Items]
2021		1
2022		22
2023		0
2024		352
2025		0
Midstream & Marketing
Debt Instrument [Line Items]
2021		10
2022		7
2023		7
2024		7
2025		7
UGI Utilities
Debt Instrument [Line Items]
2021		8
2022		7
2023		96
2024		0
2025		0
UGI Corporation
Debt Instrument [Line Items]
2021		30
2022		300
2023		38
2024		482
UGI Corporation | Subsequent Event
Debt Instrument [Line Items]
Repayment of debt	$ 30
Other
Debt Instrument [Line Items]
2021		1
2022		1
2023		6
2024		$ 0

Debt - Restrictive Covenants (D

Debt - Restrictive Covenants (Details)	Sep. 30, 2020
UGI Utilities | 2019 Credit Agreement
Debt Instrument [Line Items]
Ratio of consolidated debt to consolidated total capital, maximum	0.65
Revolving Credit Facility | UGI International LLC | Line of Credit | UGI International Credit Agreement
Debt Instrument [Line Items]
Maximum ratio of Total Indebtedness to EBITDA	3.85
Term Loan | Energy Services | Line of Credit | Energy Services Credit Agreement
Debt Instrument [Line Items]
Maximum ratio of Total Indebtedness to EBITDA	4
Consolidated EBITDA to debt service, minimum	1.10
EBITDA to consolidated interest expense ratio, maximum	3.50
Term Loan | UGI Corporation | Line of Credit | The UGI Corporation Senior Credit Facility
Debt Instrument [Line Items]
Maximum ratio of Total Indebtedness to EBITDA	4.50
EBITDA to consolidated interest expense ratio, maximum	3.50
Total indebtedness to EBITDA Ratio, final ratio, maximum	4

Debt - Restricted Net Assets (D

Debt - Restricted Net Assets (Details) $ in Millions	Sep. 30, 2020USD ($)
Senior Notes | 4.98% Senior Notes, due March 2044
Debt Instrument [Line Items]
Amount of net assets restricted from transfer to parent company under different agreements	$ 2,200

Income Taxes - Income Before In

Income Taxes - Income Before Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Domestic	$ 424	$ 330	$ 576
Foreign	243	71	279
Income before income taxes	$ 667	$ 401	$ 855

Income Taxes - Provisions for I

Income Taxes - Provisions for Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Current expense (benefit):
Federal	$ (85)	$ 52	$ (2)
State	4	14	26
Foreign	70	70	78
Total current (benefit) expense	(11)	136	102
Deferred expense (benefit):
Federal	135	3	(78)
State	19	4	7
Foreign	(8)	(50)	2
Total deferred expense (benefit)	146	(43)	(69)
Total income tax expense	$ 135	$ 93	$ 33

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($)	Aug. 21, 2019	Dec. 31, 2017	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Mar. 27, 2020	Sep. 30, 2017
Income Tax Examination [Line Items]
Foreign tax credits			$ 0	$ 10,000,000	$ 13,000,000
Net operating loss carryback						$ 32,000,000
Income taxes receivable			$ 80,000,000	$ 0
Tax Cuts And Jobs Act Of 2017, incomplete accounting, change in tax rate, deferred tax liability, provisional income tax benefit, including unrecognized deferred tax liability					$ 384,000,000
Effective income tax rate reconciliation, at federal statutory income tax rate, percent (as a percentage)			21.00%	21.00%	24.50%
Increase (decrease) in income tax liabilities					$ (52,000,000)
Tax Cuts And Jobs Act of 2017, transition tax for accumulated foreign earnings, provisional Income tax expense (benefit)			$ 2,000,000	$ 4,000,000
Income tax expense (benefit), continuing operations, adjustment of deferred tax (asset) liability		$ (12,000,000)		2,000,000
Deferred tax assets relating to operating loss carryforwards			34,000,000	21,000,000
Increase (decrease) in valuation allowance			14,000,000	(26,000,000)
Unrecognized income tax benefits			4,000,000	11,000,000	12,000,000		$ 12,000,000
Unrecognized tax benefits if recognized would impact the reported effective tax rate			4,000,000
Accrued Interest Included
Income Tax Examination [Line Items]
Unrecognized income tax benefits			4,000,000
Future Utilization of Foreign Tax Credits
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance				(25,000,000)
National Interest Deduction Carryover
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance			16,000,000
Flaga
Income Tax Examination [Line Items]
Deferred tax assets relating to operating loss carryforwards			2,000,000
UGI France
Income Tax Examination [Line Items]
Deferred tax assets relating to operating loss carryforwards			5,000,000
AmeriGas Propane
Income Tax Examination [Line Items]
Incentive distribution, distribution					13,000,000
Operating loss carryforwards			12,000,000
Deferred tax assets relating to operating loss carryforwards			2,000,000
Other Subsidiaries
Income Tax Examination [Line Items]
Deferred tax assets relating to operating loss carryforwards			25,000,000
Merger Sub
Income Tax Examination [Line Items]
Incentive distribution, distribution	$ 2,228,000,000
Cost for income tax purposes	2,030,000,000
Deferred tax asset, step up in tax basis of the underlying assets	$ 512,000,000			512,000,000
Foreign | Flaga
Income Tax Examination [Line Items]
Operating loss carryforwards			11,000,000
Foreign | UGI France
Income Tax Examination [Line Items]
Operating loss carryforwards			14,000,000
State
Income Tax Examination [Line Items]
Decrease in income tax expense due to state tax flow through of accelerated depreciation			11,000,000	$ 7,000,000	4,000,000
Operating loss carryforwards			$ 393,000,000
French Parliament
Income Tax Examination [Line Items]
Effective income tax rate reconciliation, at federal statutory income tax rate, percent (as a percentage)			34.43%
French Parliament | Foreign
Income Tax Examination [Line Items]
Increase (decrease) in income tax liabilities					$ 1,000,000

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of U.S. Federal Statutory Tax Rate to Effective Tax Rate (Details)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Operating Loss Carryforwards [Line Items]
U.S. federal statutory tax rate	21.00%	21.00%	24.50%
Difference in tax rate due to:
Noncontrolling interests not subject to tax	0.00%	(2.70%)	(3.00%)
State income taxes, net of federal benefit	2.80%	3.60%	2.90%
Valuation allowance adjustments	0.00%	0.00%	1.10%
Effects of foreign operations	1.30%	1.80%	3.10%
Excess tax benefits on share-based payments	(0.20%)	(1.00%)	(1.10%)
Other, net	(0.30%)	0.70%	(0.70%)
Effective tax rate	20.20%	23.10%	3.80%
Effect of U.S. tax legislation
Difference in tax rate due to:
Effect of tax rate change	(4.70%)	0.20%	(20.90%)
Effect of tax rate change	(4.70%)	0.20%	(20.90%)
Effect of tax rate changes - International
Difference in tax rate due to:
Effect of tax rate change	0.30%	(0.50%)	(2.10%)
Effect of tax rate change	0.30%	(0.50%)	(2.10%)

Income Taxes - Deferred Tax Lia

Income Taxes - Deferred Tax Liabilities (Assets) (Details) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019
Income Tax Disclosure [Abstract]
Excess book basis over tax basis of property, plant and equipment	$ 830	$ 805
Utility regulatory assets	112	108
Intangible assets and goodwill	107	71
Other	32	7
Gross deferred tax liabilities	1,081	991
Investment in AmeriGas Partners	(216)	(304)
Pension plan liabilities	(48)	(50)
Employee-related benefits	(46)	(44)
Operating loss carryforwards	(34)	(21)
Foreign tax credit carryforwards	(81)	(81)
Utility regulatory liabilities	(94)	(94)
Derivative instruments	(26)	(15)
Utility environmental liabilities	(16)	(15)
Other	(54)	(34)
Gross deferred tax assets	(615)	(658)
Deferred tax assets valuation allowance	105	91
Net deferred tax liabilities	$ 571	$ 424

Income Taxes - Reconciliation_2

Income Taxes - Reconciliation of Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Reconciliation of Unrecognized Tax Benefits
Unrecognized tax benefits — beginning of year	$ 11	$ 12	$ 12
Additions for tax positions of the current year	2	1	2
Additions for tax positions taken in prior years	0	0	1
Settlements with tax authorities/statute lapses	(9)	(2)	(3)
Unrecognized tax benefits — end of year	$ 4	$ 11	$ 12

Employee Retirement Plans - Cha

Employee Retirement Plans - Change in Pension Benefits and Other Postretirement Benefits Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Pension Benefits
Change in benefit obligations:
Benefit obligations — beginning of year	$ 750	$ 669
Service cost	11	10	$ 11
Interest cost	23	27	26
Actuarial loss	27	89
Curtailments	(2)	(1)
Settlements	0	(13)
Foreign currency	3	(3)
Benefits paid	(30)	(28)
Benefit obligations — end of year	782	750	669
Change in plan assets:
Fair value of plan assets — beginning of year	547	563
Actual gain on plan assets	53	13
Foreign currency	1	(1)
Employer contributions	13	12
Settlements	0	(13)
Benefits paid	(29)	(27)
Fair value of plan assets — end of year	585	547	563
Funded status of the plans — end of year	(197)	(203)
Assets (liabilities) recorded in the balance sheet:
Assets in excess of liabilities — included in other noncurrent assets	0	0
Unfunded liabilities — included in other noncurrent liabilities	(197)	(203)
Net amount recognized	(197)	(203)
Amounts recorded in UGI Corporation stockholders’ equity (pre-tax):
Prior service cost (benefit)	1	1
Net actuarial loss	24	26
Total	25	27
Amounts recorded in regulatory assets and liabilities (pre-tax):
Prior service cost		1
Net actuarial loss	174	177
Total	174	178
Other Postretirement Benefits
Change in benefit obligations:
Benefit obligations — beginning of year	23	19
Interest cost	1	1
Actuarial loss	1	4
Curtailments	0	0
Settlements	0	0
Foreign currency	0	0
Benefits paid	(1)	(1)
Benefit obligations — end of year	24	23	19
Change in plan assets:
Fair value of plan assets — beginning of year	16	15
Actual gain on plan assets	2	1
Foreign currency	0	0
Settlements	0	0
Benefits paid	(1)
Fair value of plan assets — end of year	17	16	$ 15
Funded status of the plans — end of year	(7)	(7)
Assets (liabilities) recorded in the balance sheet:
Assets in excess of liabilities — included in other noncurrent assets	3	3
Unfunded liabilities — included in other noncurrent liabilities	(10)	(10)
Net amount recognized	(7)	(7)
Amounts recorded in UGI Corporation stockholders’ equity (pre-tax):
Prior service cost (benefit)	(1)	(1)
Total	(1)	(1)
Amounts recorded in regulatory assets and liabilities (pre-tax):
Net actuarial loss	1	1
Total	$ 1	$ 1

Employee Retirement Plans - Nar

Employee Retirement Plans - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Expected amortization of net actuarial losses	$ 0
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected amortization of net actuarial losses	15
ABO for the pension plans	687	$ 659
Contribution made to Pension Plan	13	12
Projected benefit obligations of unfunded and non qualified supplemental executive retirement plans	782	750	$ 669
Net actuarial loss	24	26
Fair value of pension and other postretirement benefit contributions	0	0
Costs associated with the plans	11	9	16
Supplemental Employee Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligations of unfunded and non qualified supplemental executive retirement plans	59	53
Net actuarial loss	12	9
Fair value of pension and other postretirement benefit contributions	35	34
Costs associated with the plans	0	0
U.S. | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Contribution made to Pension Plan	$ 13	$ 12	$ 15

Employee Retirement Plans - Act

Employee Retirement Plans - Actuarial Assumptions for Domestic Plans (Details)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Pension Benefits
Weighted-average assumptions:
Discount rate – benefit obligations	2.90%	3.30%	4.40%
Discount rate – benefit cost	3.30%	4.40%	4.00%
Expected return on plan assets	7.20%	7.30%	7.40%
Rate of increase in salary levels	3.25%	3.25%	3.25%
Other Postretirement Benefits
Weighted-average assumptions:
Discount rate – benefit obligations	3.00%	3.30%	4.40%
Discount rate – benefit cost	3.30%	4.40%	4.00%
Expected return on plan assets	5.00%	5.00%	5.00%
Rate of increase in salary levels	3.25%	3.25%	3.25%

Employee Retirement Plans - Net

Employee Retirement Plans - Net Periodic Pension Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 11	$ 10	$ 11
Interest cost	23	27	26
Expected return on assets	(38)	(36)	(35)
Curtailment gain	(1)	0	0
Amortization of:
Prior service cost	1		1
Actuarial loss	15	8	13
Net cost	11	9	$ 16
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Interest cost	$ 1	$ 1

Employee Retirement Plans - Exp

Employee Retirement Plans - Expected Payments for Pension Benefits and Other Postretirement Welfare Benefits (Details) - Pension Benefits $ in Millions	Sep. 30, 2020USD ($)
Defined Benefit Plan Disclosure [Line Items]
Fiscal 2021	$ 33
Fiscal 2022	32
Fiscal 2023	34
Fiscal 2024	36
Fiscal 2025	38
Fiscal 2026 - 2030	$ 203

Employee Retirement Plans - Pen

Employee Retirement Plans - Pension Plans Assets (Details) - Pension Benefits - U.S.	Sep. 30, 2020	Sep. 30, 2019
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	100.00%	100.00%
Target Asset Allocation	100.00%	100.00%
Total domestic equity investments
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	26.50%	54.80%
Target Asset Allocation	29.00%	52.50%
Total domestic equity investments | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans
Target Asset Allocation	24.00%
Total domestic equity investments | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans
Target Asset Allocation	34.00%
International index equity mutual funds
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	25.00%	11.80%
Target Asset Allocation	24.50%	12.50%
International index equity mutual funds | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans
Target Asset Allocation	19.50%
International index equity mutual funds | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans
Target Asset Allocation	29.50%
Global equity index investments
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	12.30%	0.00%
Target Asset Allocation	11.50%	0.00%
Global equity index investments | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans
Target Asset Allocation	6.50%
Global equity index investments | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans
Target Asset Allocation	16.50%
Equity investments
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	63.80%	66.60%
Target Asset Allocation	65.00%	65.00%
Equity investments | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans
Target Asset Allocation	60.00%
Equity investments | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans
Target Asset Allocation	70.00%
Fixed income funds & cash equivalents
Defined Benefit Plans and Other Postretirement Benefit Plans
Actual	36.20%	33.40%
Target Asset Allocation	35.00%	35.00%
Fixed income funds & cash equivalents | Minimum
Defined Benefit Plans and Other Postretirement Benefit Plans
Target Asset Allocation	30.00%
Fixed income funds & cash equivalents | Maximum
Defined Benefit Plans and Other Postretirement Benefit Plans
Target Asset Allocation	40.00%

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, 2020	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 585	$ 547	$ 563
U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	566	529
U.S. | UGI Corporation Common Stock
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	27	41
U.S. | Total domestic equity investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	27	290
U.S. | U.S. equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	123
U.S. | U.S. equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	539
U.S. | International index equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		62
U.S. | Global equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	70
U.S. | Bond index mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	200	171
U.S. | S&P 500 Index equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		176
U.S. | Small and midcap equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		73
U.S. | Cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	6
U.S. | Fixed income funds & cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		177
U.S. | Defined Benefit Plan Non Us Equity Index Investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	141
U.S. | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	27	523
U.S. | Level 1 | UGI Corporation Common Stock
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	27	41
U.S. | Level 1 | Total domestic equity investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	27	290
U.S. | Level 1 | International index equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		62
U.S. | Level 1 | Bond index mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		171
U.S. | Level 1 | S&P 500 Index equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		176
U.S. | Level 1 | Small and midcap equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		73
U.S. | Level 1 | Fixed income funds & cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		171
U.S. | Level 2 | UGI Corporation Common Stock
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
U.S. | Level 2 | Total domestic equity investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
U.S. | Level 2 | International index equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
U.S. | Level 2 | Bond index mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
U.S. | Level 2 | S&P 500 Index equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
U.S. | Level 2 | Small and midcap equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
U.S. | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
U.S. | Level 3 | UGI Corporation Common Stock
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
U.S. | Level 3 | Total domestic equity investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
U.S. | Level 3 | International index equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
U.S. | Level 3 | Bond index mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
U.S. | Level 3 | S&P 500 Index equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
U.S. | Level 3 | Small and midcap equity mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
U.S. | Level 3 | Fixed income funds & cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
U.S. | Other
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	539	6
U.S. | Other | U.S. equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	123
U.S. | Other | U.S. equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	539
U.S. | Other | Global equity index investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	70
U.S. | Other | Bond index mutual funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	200
U.S. | Other | Cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	5	6
U.S. | Other | Fixed income funds & cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		$ 6
U.S. | Other | Defined Benefit Plan Non Us Equity Index Investments
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 141

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, 2020	Sep. 30, 2019	Sep. 30, 2018
Defined Contribution Plan Disclosure [Line Items]
Costs of benefits under savings plans	$ 21	$ 19	$ 17
Total fair values of grantor trust investment assets	$ 7	$ 6

Utility Regulatory Assets and_3

Utility Regulatory Assets and Liabilities and Regulatory Matters - Regulatory Assets and Liabilities Associated with Utilities (Details) - USD ($)	Sep. 30, 2020	Sep. 30, 2019
Regulatory Assets [Line Items]
Regulatory assets	$ 0	$ 0
UGI Utilities
Regulatory Assets [Line Items]
Regulatory assets	397,000,000	396,000,000
Regulatory Liabilities [Line Items]
Regulatory liabilities	353,000,000	359,000,000
UGI Utilities | Postretirement benefit overcollections
Regulatory Liabilities [Line Items]
Regulatory liabilities	13,000,000	15,000,000
UGI Utilities | Deferred fuel and power refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities	29,000,000	6,000,000
UGI Utilities | State income tax benefits — distribution system repairs
Regulatory Liabilities [Line Items]
Regulatory liabilities	28,000,000	25,000,000
UGI Utilities | PAPUC Temporary Rates Order
Regulatory Liabilities [Line Items]
Regulatory liabilities	7,000,000	31,000,000
UGI Utilities | Excess federal deferred income taxes
Regulatory Liabilities [Line Items]
Regulatory liabilities	274,000,000	280,000,000
UGI Utilities | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities	2,000,000	2,000,000
UGI Utilities | Income taxes recoverable
Regulatory Assets [Line Items]
Regulatory assets	124,000,000	115,000,000
UGI Utilities | Underfunded pension and postretirement plans
Regulatory Assets [Line Items]
Regulatory assets	175,000,000	179,000,000
UGI Utilities | Environmental costs
Regulatory Assets [Line Items]
Regulatory assets	61,000,000	60,000,000
UGI Utilities | Removal costs, net
Regulatory Assets [Line Items]
Regulatory assets	26,000,000	28,000,000
UGI Utilities | Other
Regulatory Assets [Line Items]
Regulatory assets	$ 11,000,000	$ 14,000,000

Utility Regulatory Assets and_4

Utility Regulatory Assets and Liabilities and Regulatory Matters - Narrative (Details) - USD ($)	Oct. 08, 2020	Jan. 28, 2020	Oct. 11, 2019	Jan. 28, 2019	Oct. 27, 2018	Oct. 25, 2018	Oct. 19, 2016	Sep. 30, 2020	Sep. 30, 2019
Regulatory Assets [Line Items]
Regulatory asset, amortization period					20 years
UGI Gas
Regulatory Assets [Line Items]
Public utilities, tax benefits, effective period				12 months
Pennsylvania Public Utility Commission | UGI Gas
Regulatory Assets [Line Items]
Public utilities, requested rate increase (decrease), amount		$ 75,000,000		$ 71,000,000
Approved rate increase (decrease), amount			$ 30,000,000
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]
Regulatory asset, amortization period	10 years
Approved rate increase (decrease), amount	$ 20,000,000
Property, plant and equipment, net threshold	2,875,000,000
Pennsylvania Public Utility Commission | UGI Gas | Beginning January 1, 2021 | Subsequent Event
Regulatory Assets [Line Items]
Approved rate increase (decrease), amount	10,000,000
Pennsylvania Public Utility Commission | UGI Gas | Beginning July 1, 2021 | Subsequent Event
Regulatory Assets [Line Items]
Approved rate increase (decrease), amount	$ 10,000,000
Pennsylvania Public Utility Commission | Electric Utility
Regulatory Assets [Line Items]
Approved rate increase (decrease), amount						$ 3,000,000
Postretirement benefit overcollections
Regulatory Assets [Line Items]
Regulatory liability, amortization period							10 years
Gas Utility
Regulatory Assets [Line Items]
Fair value of unrealized gains (losses)								$ 8,000,000	$ (2,000,000)
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 - Schedule of Inven

Inventories - Schedule of Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019
Public Utilities, Inventory
Total inventories	$ 241	$ 230
Non-utility LPG and natural gas
Public Utilities, Inventory
Total inventories	164	150
Gas Utility natural gas
Public Utilities, Inventory
Total inventories	20	27
Materials, supplies and other
Public Utilities, Inventory
Total inventories	$ 57	$ 53

Inventories - Narrative (Detail

Inventories - Narrative (Details) - UGI Utilities	12 Months Ended
	Sep. 30, 2020storage_agreement
Public Utilities, Inventory
Number of storage agreements	3
Storage agreement term (up to)	3 years

Property, Plant and Equipment -

Property, Plant and Equipment - (Details) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019
Property, Plant and Equipment
Utility	$ 4,265	$ 3,938
Non-utility	6,393	6,135
Total property, plant and equipment	10,658	10,073
Distribution
Property, Plant and Equipment
Utility	3,630	3,366
Transmission
Property, Plant and Equipment
Utility	111	106
General and other
Property, Plant and Equipment
Utility	425	389
Work in process
Property, Plant and Equipment
Utility	99	77
Non-utility	196	102
Land
Property, Plant and Equipment
Non-utility	191	184
Buildings and improvements
Property, Plant and Equipment
Non-utility	431	404
Transportation equipment
Property, Plant and Equipment
Non-utility	248	258
Equipment, primarily cylinders and tanks
Property, Plant and Equipment
Non-utility	3,712	3,455
Electric generation
Property, Plant and Equipment
Non-utility	211	327
Pipeline and related assets
Property, Plant and Equipment
Non-utility	1,098	1,150
Other
Property, Plant and Equipment
Non-utility	$ 306	$ 255

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, 2020	Sep. 30, 2019
Goodwill
Balance at beginning of period	$ 3,456	$ 3,160
Acquisitions		356
Dispositions	(5)
Purchase accounting adjustments	(2)
Foreign currency translation	69	(60)
Balance at end of period	3,518	3,456
AmeriGas Propane
Goodwill
Balance at beginning of period	2,004	2,004
Acquisitions		0
Dispositions	0
Purchase accounting adjustments	0
Foreign currency translation	0	0
Balance at end of period	2,004	2,004
UGI International
Goodwill
Balance at beginning of period	930	964
Acquisitions		26
Dispositions	0
Purchase accounting adjustments	(2)
Foreign currency translation	69	(60)
Balance at end of period	997	930
Midstream & Marketing
Goodwill
Balance at beginning of period	340	10
Acquisitions		330
Dispositions	(5)
Purchase accounting adjustments	0
Foreign currency translation	0	0
Balance at end of period	335	340
UGI Utilities
Goodwill
Balance at beginning of period	182	182
Acquisitions		0
Dispositions	0
Purchase accounting adjustments	0
Foreign currency translation	0	0
Balance at end of period	$ 182	$ 182

Goodwill and Intangible Asset_3

Goodwill and Intangible Assets - Components of Intangible Assets (Details) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019
Goodwill and Intangible Assets Disclosure [Abstract]
Customer relationships	$ 1,083	$ 1,038
Trademarks and tradenames	12	16
Noncompete agreements and other	76	48
Accumulated amortization	(543)	(442)
Intangible assets, net (definite-lived)	628	660
Trademarks and tradenames (indefinite-lived)	49	49
Total intangible assets, net	$ 677	$ 709

Goodwill and Intangible Asset_4

Goodwill and Intangible Assets - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Amortization expense of intangible assets	$ 83	$ 59	$ 58
Fiscal 2021	76
Fiscal 2022	65
Fiscal 2023	61
Fiscal 2024	59
Fiscal 2025	$ 57

Series Preferred Stock (Details

Series Preferred Stock (Details) - shares	Sep. 30, 2020	Sep. 30, 2019
Class of Stock [Line Items]
Preferred Stock, shares authorized (in shares)	10,000,000
Preferred Stock, shares outstanding (in shares)	0	0
UGI Utilities
Class of Stock [Line Items]
Preferred Stock, shares authorized (in shares)	2,000,000
Preferred Stock, shares outstanding (in shares)	0	0

Common Stock and Equity-Based_3

Common Stock and Equity-Based Compensation - Narrative (Details) $ / shares in Units, $ in Millions	Aug. 21, 2019shares	Jan. 25, 2018shares	Sep. 30, 2020USD ($)$ / sharesshares	Sep. 30, 2019USD ($)$ / sharesshares	Sep. 30, 2018USD ($)$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award
Treasury stock acquired | $			$ 49	$ 16
Pre-tax equity-based compensation expense | $			15	18	$ 23
After tax equity-based compensation expense | $			11	13	16
Cash received from stock option exercises | $			2	20	43
Associated tax benefits | $			1	$ 5	$ 13
Unrecognized compensation cost associated with unvested unit awards | $			$ 8
Weighted-average period of recognition for unvested unit awards			1 year 10 months 24 days
UGI Stock Option Awards
Share-based Compensation Arrangement by Share-based Payment Award
Weighted-average fair value of stock option granted under stock plans (in dollars per share) | $ / shares			$ 5.58	$ 8.70	$ 7.51
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) | $ / shares			$ 41.85	$ 55.40	$ 55.26
Award performance period			3 years
Expected term of Performance Unit awards			3 years
Expected volatility measurement period (in years)			3 years
UGI Units awarded (in shares)			222,410	29,784	52,314
Weighted average grant date fair value unit awards (in dollars per share) | $ / shares			$ 41.85
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 | $			$ 8
Weighted-average period of recognition for unvested unit awards			2 years
UGI Units awarded (in shares)			300,361	158,694	196,114
Weighted average grant date fair value unit awards (in dollars per share) | $ / shares			$ 41.50	$ 55.40	$ 53.36
UGI Unit awards outstanding (in shares)			831,274	893,820
Fair value of unit awards vested | $			$ 5	$ 5	$ 7
Liabilities associated with share based compensation | $			$ 5	10
Amerigas Performance Units and Stock Units
Share-based Compensation Arrangement by Share-based Payment Award
Conversion ratio	0.6378
AmeriGas Performance Units
Share-based Compensation Arrangement by Share-based Payment Award
Units converted to UGI cash-settled restricted units (in shares)	137,472
AmeriGas Stock Units
Share-based Compensation Arrangement by Share-based Payment Award
Units converted to UGI cash-settled restricted units (in shares)	126,089
Total Unitholder Return at 25th Percentile | UGI Performance Units
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted (as a percentage)			25.00%
Total Unitholder Return at 40th Percentile | UGI Performance Units
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted (as a percentage)			70.00%
Total Unitholder Return at 50th Percentile | UGI Performance Units
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted (as a percentage)			100.00%
Total Unitholder Return at 90th Percentile | UGI Performance Units
Share-based Compensation Arrangement by Share-based Payment Award
Percentage of target award to be granted (as a percentage)			200.00%
2010 Propane Plan | UGI Performance Units and Stock Units
Share-based Compensation Arrangement by Share-based Payment Award
UGI Unit awards outstanding (in shares)			1,420,949
2010 Propane Plan | Amerigas Performance Units and Stock Units
Share-based Compensation Arrangement by Share-based Payment Award
Award performance period			3 years
2010 Propane Plan | Amerigas Performance Units and Stock Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award
Total unitholder return ranking (as a percentage)			0.00%
2010 Propane Plan | Amerigas Performance Units and Stock Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award
Total unitholder return ranking (as a percentage)			200.00%
Common Stock
Share-based Compensation Arrangement by Share-based Payment Award
Maximum number of shares authorized for repurchase (up to)		8,000,000
Duration of stock repurchase program		4 years
Treasury stock acquired | $			$ 38	$ 17	$ 60
Common Stock | 2013 Omnibus Incentive Compensation Plan (OICP)
Share-based Compensation Arrangement by Share-based Payment Award
Expiration period			10 years
Common Stock awards granted (up to)			21,750,000
Number of common unit awards available for future grant (in shares)			6,105,754
Common Stock | Treasury Stock
Share-based Compensation Arrangement by Share-based Payment Award
Repurchases of common stock - Treasury (in shares)			(950,000)	(300,000)	(1,200,000)
AmeriGas Performance Units | Cash Settled Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award
Issuance in period due to conversion (in shares)	215,957

Common Stock and Equity-Based_4

Common Stock and Equity-Based Compensation - Common Stock Share Activity (Details) - Common Stock - shares	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2017
Common Stock Share Activity
Beginning balance - shares Issued/Treasury (in shares)	209,514,044	209,304,129	174,142,997	173,987,691
Beginning balance - shares Outstanding (in shares)	209,004,789	173,748,975	173,143,737
Issued:
Employee and director plans - shares Issued/Treasury (in shares)	209,915	548,285	155,306
Employee and director plans - shares Outstanding (in shares)	389,965	979,132	1,960,018
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)	(90,316)	(51,924)	(154,780)
Ending balance - shares Issued/Treasury (in shares)	209,514,044	209,304,129	174,142,997	173,987,691
Ending balance - shares Outstanding (in shares)	208,354,438	209,004,789	173,748,975
Treasury
Common Stock Share Activity
Beginning balance - shares Issued/Treasury (in shares)	1,159,606	299,340	394,022	843,954
Issued:
Employee and director plans - shares Issued/Treasury (in shares)	180,050	430,847	1,804,712
AmeriGas Merger -Issued (in shares)		0
Sale of reacquired common stock - Treasury (in shares)		15,759
Repurchases of common stock - Treasury (in shares)	(950,000)	(300,000)	(1,200,000)
Reacquired common stock, employee and director plans - Treasury (in shares)	(90,316)	(51,924)	(154,780)
Ending balance - shares Issued/Treasury (in shares)	1,159,606	299,340	394,022	843,954

Common Stock and Equity-Based_5

Common Stock and Equity-Based Compensation - Stock Option Awards (Details) - UGI Stock Option Awards - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2017
Shares
Shares under option - beginning balance (in shares)	8,478,105	8,197,069	8,781,748
Granted (in shares)	1,893,700	1,197,100	1,401,400
Canceled (in shares)	(57,668)	(123,012)	(152,017)
Expired (in shares)	(93,728)	(13,699)	(1,666)
Exercised (in shares)	(230,875)	(779,353)	(1,832,396)
Shares under option - ending balance (in shares)	9,989,534	8,478,105	8,197,069	8,781,748
Weighted - Average Option Price
Shares under option - beginning balance (in dollars per share)	$ 37.18	$ 33.93	$ 30.20
Granted (in dollars per share)	43.20	53.27	47.85
Canceled (in dollars per share)	49.69	48.69	42.14
Expired (in dollars per share)	37.81	47.49	35.80
Exercised (in dollars per share)	22.65	25.75	26
Shares under option - ending balance (in dollars per share)	$ 38.58	$ 37.18	$ 33.93	$ 30.20
Total Intrinsic Value
Shares under option - beginning balance	$ 115	$ 177	$ 147
Exercised	3	23	45
Shares under option - beginning balance	$ 26	$ 115	$ 177	$ 147
Weighted - Average Contract Term (Years)
Weighted - Average Contract Term (Years)	5 years 9 months 18 days	5 years 10 months 24 days	6 years 2 months 12 days	6 years 3 months 18 days
Options Exercisable
Options exercisable (in shares)	6,898,251	5,963,530	5,498,330
Weighted - Average Option Price (in dollars per share)	$ 35.06	$ 32.02	$ 28.63
Total Intrinsic Value	$ 26
Weighted - Average Contract Term (Years)	4 years 6 months
Options Not Exercisable
Options not exercisable (in shares)	3,091,283
Weighted - Average Option Price (in dollars per share)	$ 46.45
Total Intrinsic Value	$ 0
Weighted - Average Contract Term (Years)	8 years 7 months 6 days

Common Stock and Equity-Based_6

Common Stock and Equity-Based Compensation - Additional Information Relating to Stock Options Outstanding and Exercisable (Details) - UGI Stock Option Awards	12 Months Ended
	Sep. 30, 2020$ / sharesshares
Under $30.00
Share-based Compensation Arrangement by Share-based Payment Award
Range of exercise prices, upper limit (in dollars per share)	$ 30
Options outstanding at September 30, 2020
Number of options (in shares) | shares	2,672,041
Weighted average remaining contractual life (in years)	2 years 2 months 12 days
Weighted average exercise price (in dollars per share)	$ 23.46
Options exercisable at September 30, 2020
Number of options (in shares) | shares	2,669,481
Weighted average exercise price (in dollars per share)	$ 23.45
$30.00 – $35.00
Share-based Compensation Arrangement by Share-based Payment Award
Range of exercise prices, lower limit (in dollars per share)	30
Range of exercise prices, upper limit (in dollars per share)	$ 35
Options outstanding at September 30, 2020
Number of options (in shares) | shares	1,297,358
Weighted average remaining contractual life (in years)	5 years 10 months 24 days
Weighted average exercise price (in dollars per share)	$ 33.30
Options exercisable at September 30, 2020
Number of options (in shares) | shares	1,041,488
Weighted average exercise price (in dollars per share)	$ 33.65
$35.01 – $40.00
Share-based Compensation Arrangement by Share-based Payment Award
Range of exercise prices, lower limit (in dollars per share)	35.01
Range of exercise prices, upper limit (in dollars per share)	$ 40
Options outstanding at September 30, 2020
Number of options (in shares) | shares	858,565
Weighted average remaining contractual life (in years)	4 years 2 months 12 days
Weighted average exercise price (in dollars per share)	$ 37.82
Options exercisable at September 30, 2020
Number of options (in shares) | shares	858,565
Weighted average exercise price (in dollars per share)	$ 37.82
$40.01 – $45.00
Share-based Compensation Arrangement by Share-based Payment Award
Range of exercise prices, lower limit (in dollars per share)	40.01
Range of exercise prices, upper limit (in dollars per share)	$ 45
Options outstanding at September 30, 2020
Number of options (in shares) | shares	177,947
Weighted average remaining contractual life (in years)	7 years 10 months 24 days
Weighted average exercise price (in dollars per share)	$ 44.07
Options exercisable at September 30, 2020
Number of options (in shares) | shares	172,497
Weighted average exercise price (in dollars per share)	$ 44.12
Over $45.01
Share-based Compensation Arrangement by Share-based Payment Award
Range of exercise prices, lower limit (in dollars per share)	$ 45.01
Options outstanding at September 30, 2020
Number of options (in shares) | shares	4,983,623
Weighted average remaining contractual life (in years)	7 years 9 months 18 days
Weighted average exercise price (in dollars per share)	$ 48
Options exercisable at September 30, 2020
Number of options (in shares) | shares	2,156,220
Weighted average exercise price (in dollars per share)	$ 48.28

Common Stock and Equity-Based_7

Common Stock and Equity-Based Compensation - Assumptions Used for Valuing Option Grants (Details) - UGI Stock Option Awards	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award
Expected life of option	6 years	6 years	6 years
Weighted-average volatility	19.60%	17.20%	17.50%
Weighted-average dividend yield	3.00%	1.80%	2.10%
Expected volatility	19.60%	17.20%	17.50%
Expected dividend yield	3.00%	1.80%	2.10%
Minimum
Share-based Compensation Arrangement by Share-based Payment Award
Risk free rate	0.30%	1.50%	2.20%
Maximum
Share-based Compensation Arrangement by Share-based Payment Award
Risk free rate	1.70%	2.60%	2.90%

Common Stock and Equity-Based_8

Common Stock and Equity-Based Compensation - Weighted Average Assumptions Used to Determine the Fair Value of UGI Performance Unit Awards and Related Compensation Costs (Details) - UGI Performance Units	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award
Risk free rate	1.60%	2.50%	2.00%
Expected life	3 years	3 years	3 years
Expected volatility	18.60%	17.70%	18.90%
Dividend yield	2.90%	1.90%	2.10%

Common Stock and Equity-Based_9

Common Stock and Equity-Based Compensation - UGI Performance Unit Award Activity (Details) - $ / shares	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
UGI Performance Units and Stock Units
UGI Units
Number of units - beginning balance (in shares)			893,820
Granted (in shares)			300,361	158,694	196,114
Number of units - ending balance (in shares)	831,274	893,820	831,274	893,820
Weighted-Average Grant-Date Fair Value (per Unit)
Weighted average grant date fair value - beginning balance (in dollars per share)			$ 36.39
Granted (in dollars per share)			41.50	$ 55.40	$ 53.36
Weighted average grant date fair value - ending balance (in dollars per share)	$ 39.95	$ 36.39	$ 39.95	$ 36.39
UGI Performance Units
UGI Units
Granted (in shares)			222,410	29,784	52,314
Forfeited (in shares)			(13,734)
Performance criteria not met (in shares)			(121,948)
Weighted-Average Grant-Date Fair Value (per Unit)
Granted (in dollars per share)			$ 41.85
Forfeited (in dollars per share)			40.01
Performance criteria not met (in dollars per share)			$ 46.76
UGI Stock Units
UGI Units
Granted (in shares)			77,951
Units awards paid (in shares)			(227,225)
Weighted-Average Grant-Date Fair Value (per Unit)
Granted (in dollars per share)			$ 40.38
Units awards paid (in dollars per share)			$ 24.31
Shares granted under stock awards (as a percentage)			70.00%
UGI Restricted Stock Units
Weighted-Average Grant-Date Fair Value (per Unit)
Vested units (in shares)	441,498	616,319

Common Stock and Equity-Base_10

Common Stock and Equity-Based Compensation - Schedule of Payment for UGI Performance Unit and UGI Stock Unit Awards in Shares and Cash (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
UGI Performance Units
Share-based Compensation Arrangement by Share-based Payment Award
Number of original awards granted, net of forfeitures	121,948	144,521	136,621
Performance period beginning January 1:	2017	2016	2015
Payment of awards:
Shares of UGI Common Stock issued, net of shares withheld for taxes	0	116,950	69,680
Cash paid	$ 0	$ 10	$ 2
UGI Stock Units
Share-based Compensation Arrangement by Share-based Payment Award
Number of original awards granted, net of forfeitures	227,721	50,985	39,680
Payment of awards:
Shares of UGI Common Stock issued, net of shares withheld for taxes	148,477	43,479	29,095
Cash paid	$ 3	$ 1	$ 1

Partnership Distributions (Deta

Partnership Distributions (Details) - USD ($) $ / shares in Units, $ in Millions	11 Months Ended	12 Months Ended
	Aug. 21, 2019	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Distribution Made to Limited Partner
Partnership distributions to partners (days following quarter end)		45 days
Quarterly distribution (in dollars per share)	$ 0.55
First target distribution (in dollars per share)	0.055
Available cash for per common unit (more than) (in dollars per share)	0.605			$ 0.605
Threshold for increased distribution to General Partner (in dollars per share)	$ 0.605
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, 2020USD ($)
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) $ in Millions	Sep. 30, 2020USD ($)
ROU assets:
Operating lease ROU assets	$ 415
Finance lease ROU assets	52
Total ROU assets	$ 467
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	us-gaap:OtherAssetsNoncurrent
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	us-gaap:PropertyPlantAndEquipmentAndFinanceLeaseRightOfUseAssetAfterAccumulatedDepreciationAndAmortization
Lease liabilities:
Operating lease liabilities — current	$ 87
Operating lease liabilities — noncurrent	334
Finance lease liabilities — current	5
Finance lease liabilities — noncurrent	41
Total lease liabilities	$ 467
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	us-gaap:OtherLiabilitiesCurrent
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	us-gaap:OtherLiabilitiesNoncurrent
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	us-gaap:LongTermDebtAndCapitalLeaseObligationsCurrent
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	us-gaap:LongTermDebtAndCapitalLeaseObligations

Leases - Component of Lease Exp

Leases - Component of Lease Expense (Details) $ in Millions	12 Months Ended
	Sep. 30, 2020USD ($)
Leases [Abstract]
Operating lease cost	$ 102
Finance lease cost:
Amortization of ROU assets	5
Interest on lease liabilities	3
Variable lease cost	5
Short-term lease cost	3
Total lease cost	118
Cash paid related to lease liabilities:
Operating cash flows — operating leases	103
Operating cash flows — finance leases	3
Financing cash flows — finance leases	4
Non-cash lease liability activities:
ROU assets obtained in exchange for operating lease liabilities (including the impact upon adoption)	506
ROU assets obtained in exchange for finance lease liabilities	$ 22
Weighted-average remaining lease term
Operating leases	6 years 2 months 12 days
Finance leases	2 years 4 months 24 days
Weighted-average discount rate
Operating leases	3.80%
Finance leases	1.90%

Leases - Operating and Finance

Leases - Operating and Finance Leases, Liability, Maturity (Details) $ in Millions	Sep. 30, 2020USD ($)
Operating leases
2021	$ 102
2022	86
2023	73
2024	63
2025	48
After 2025	109
Total Lease Payments	481
Imputed Interest	(60)
Lease Liabilities	421
Finance leases
2021	5
2022	4
2023	4
2024	3
2025	3
After 2025	83
Total Lease Payments	102
Imputed Interest	(56)
Lease Liabilities	$ 46

Leases - Schedule of Future Min

Leases - Schedule of Future Minimum Rental Payments for Operating Leases (Details) $ in Millions	Sep. 30, 2019USD ($)
Minimum operating lease payments
2020	$ 100
2021	86
2022	71
2023	62
2024	54
After 2024	$ 139

Commitments and Contingencies -

Commitments and Contingencies - Contingencies (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017record_of_decision	Dec. 31, 2008lb	Dec. 31, 2007lb	Sep. 30, 2020USD ($)subsidiary	Sep. 30, 2019USD ($)	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 | 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
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, 2020	Sep. 30, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-qualified supplemental postretirement grantor trust investments	$ 42	$ 40
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Non-qualified supplemental postretirement grantor trust investments	42	40
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	107	42
Derivative instruments, Liabilities	(118)	(175)
Commodity contracts | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	68	32
Derivative instruments, Liabilities	(54)	(62)
Commodity contracts | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, Assets	39	10
Derivative instruments, Liabilities	(64)	(113)
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	32	59
Derivative instruments, Liabilities	(14)	(4)
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	32	59
Derivative instruments, Liabilities	(14)	(4)
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	(55)	(12)
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	(55)	(12)
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, 2020	Sep. 30, 2019
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,081	$ 5,857
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,504	$ 6,189

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Narrative (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Derivative [Line Items]
Pre-tax net losses associated with interest rate hedges	$ 4,000,000
Pre-tax (losses) gains associated with net investment hedges	(53,000,000)	$ 31,000,000
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, 2020USD ($)DTHkWhgal	Sep. 30, 2020EUR (€)DTHkWhgal	Sep. 30, 2019USD ($)DTHkWhgal	Sep. 30, 2019EUR (€)DTHkWhgal
Commodity contracts | Propane
Derivative [Line Items]
Notional amount (in units) | gal	846	846	800	800
Commodity contracts | Electricity | Long
Derivative [Line Items]
Notional amount (in units) | kWh	4,517	4,517	3,098	3,098
Commodity contracts | Electricity | Short
Derivative [Line Items]
Notional amount (in units) | kWh	188	188	367	367
Natural gas futures, forward, basis swap, options and pipeline contracts | Natural Gas
Derivative [Line Items]
Notional amount (in units) | DTH	339	339	329	329
Interest rate swaps
Derivative [Line Items]
Notional amount	$ 1,344	€ 300	$ 1,357	€ 300
Forward foreign exchange contracts
Derivative [Line Items]
Notional amount	$ 511	€ 173	$ 516	€ 173
Regulated Utility Operations | Commodity contracts | Natural Gas
Derivative [Line Items]
Notional amount (in units) | DTH	22	22	23	23

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, 2020	Sep. 30, 2019
Derivative assets:
Total derivative assets – gross	$ 139	$ 101
Gross amounts offset in the balance sheet	(57)	(29)
Total derivative assets – net	82	72
Derivative liabilities:
Total derivative liabilities – gross	(187)	(191)
Gross amounts offset in the balance sheet	57	29
Cash collateral pledged	7	29
Total derivative liabilities – net	(123)	(133)
Commodity contract - subject to PGC and DS mechanisms
Derivative assets:
Total derivative assets – gross	7	1
Derivative liabilities:
Total derivative liabilities – gross	0	(4)
Derivatives designated as hedging instruments | Foreign currency contracts
Derivative assets:
Total derivative assets – gross	17	17
Derivatives designated as hedging instruments | Interest rate contracts
Derivative liabilities:
Total derivative liabilities – gross	(55)	(12)
Derivatives not designated as hedging instruments
Derivative assets:
Total derivative assets – gross	115	83
Derivative liabilities:
Total derivative liabilities – gross	(132)	(175)
Derivatives not designated as hedging instruments | Foreign currency contracts
Derivative assets:
Total derivative assets – gross	15	42
Derivative liabilities:
Total derivative liabilities – gross	(14)	(4)
Derivatives not designated as hedging instruments | Commodity contracts
Derivative assets:
Total derivative assets – gross	100	41
Derivative liabilities:
Total derivative liabilities – gross	$ (118)	$ (171)

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, 2020	Sep. 30, 2019	Sep. 30, 2018
Derivatives Not Designated as Hedging Instruments:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ (42)	$ (299)	$ 166
Derivatives Not Designated as Hedging Instruments: | Foreign currency contracts | Other non-operating (expense) income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(20)	38	16
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(32)	(344)	155
Derivatives Not Designated as Hedging Instruments: | Commodity contracts | Revenues
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	10	7	(5)
Cash Flow Hedges:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	(53)
Gain (Loss) Recognized in AOCI		(10)	2
Gain (Loss) Reclassified from AOCI into Income	(13)
Gain (Loss) Reclassified from AOCI into Income		(4)	(7)
Cash Flow Hedges: | Foreign currency contracts
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	0
Gain (Loss) Recognized in AOCI		1	0
Cash Flow Hedges: | Foreign currency contracts | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Reclassified from AOCI into Income	0
Gain (Loss) Reclassified from AOCI into Income		2	(3)
Cash Flow Hedges: | Cross-currency swaps
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	0
Gain (Loss) Recognized in AOCI		0	2
Cash Flow Hedges: | Cross-currency swaps | Interest expense /other operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Reclassified from AOCI into Income	0
Gain (Loss) Reclassified from AOCI into Income		0	1
Cash Flow Hedges: | Interest rate contracts
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	(53)
Gain (Loss) Recognized in AOCI		(11)	0
Cash Flow Hedges: | Interest rate contracts | Interest expense
Derivative Instruments, Gain (Loss)
Gain (Loss) Reclassified from AOCI into Income	(13)
Gain (Loss) Reclassified from AOCI into Income		(6)	(5)
Net Investment Hedges: | Foreign currency contracts
Derivative Instruments, Gain (Loss)
Foreign currency contracts	$ (1)
Foreign currency contracts		$ 17	$ 0

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	$ 3,827	$ 4,101
Other comprehensive income (loss) before reclassification adjustments (after-tax)	58	(103)	$ (19)
Amounts reclassified from AOCI:
Reclassification adjustments (pre-tax)	17	6	4
Reclassification adjustments tax benefit	(5)	(3)	(2)
Reclassification adjustments (after-tax)	12	3	2
Other comprehensive income (loss) attributable to UGI	70	(100)	(17)
Reclassification of stranded income tax effects related to TCJA		(7)
Balance, end of year	4,137	3,827	4,101
Postretirement Benefit Plans
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(26)	(11)	(19)
Other comprehensive income (loss) before reclassification adjustments (after-tax)	(3)	(13)	10
Amounts reclassified from AOCI:
Reclassification adjustments (pre-tax)	4	2	(3)
Reclassification adjustments tax benefit	(1)	(1)	1
Reclassification adjustments (after-tax)	3	1	(2)
Other comprehensive income (loss) attributable to UGI	0	(12)	8
Reclassification of stranded income tax effects related to TCJA		(3)
Balance, end of year	(26)	(26)	(11)
Derivative Instruments
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(25)	(16)	(21)
Other comprehensive income (loss) before reclassification adjustments (after-tax)	(38)	(7)	1
Amounts reclassified from AOCI:
Reclassification adjustments (pre-tax)	13	4	7
Reclassification adjustments tax benefit	(4)	(2)	(3)
Reclassification adjustments (after-tax)	9	2	4
Other comprehensive income (loss) attributable to UGI	(29)	(5)	5
Reclassification of stranded income tax effects related to TCJA		(4)
Balance, end of year	(54)	(25)	(16)
Foreign Currency
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(166)	(83)	(53)
Other comprehensive income (loss) before reclassification adjustments (after-tax)	99	(83)	(30)
Amounts reclassified from AOCI:
Reclassification adjustments (pre-tax)	0	0	0
Reclassification adjustments tax benefit	0	0	0
Reclassification adjustments (after-tax)	0	0	0
Other comprehensive income (loss) attributable to UGI	99	(83)	(30)
Reclassification of stranded income tax effects related to TCJA		0
Balance, end of year	(67)	(166)	(83)
Accumulated other comprehensive income (loss)
AOCI Including Portion Attributable to NCI [Roll Forward]:
Balance, beginning of year	(217)	(110)	(93)
Amounts reclassified from AOCI:
Reclassification of stranded income tax effects related to TCJA		(7)
Balance, end of year	$ (147)	$ (217)	$ (110)

Other Operating Income, Net a_3

Other Operating Income, Net and Other Non-Operating (Expense) Income, Net - Other Operating Income, Net (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Component of Operating Income [Abstract]
Finance charges	$ 9	$ 17	$ 16
Interest and interest-related income	2	6	3
Utility non-tariff service income	0	1	3
Gains on sales of fixed assets, net	5	3	5
Other, net	5	4	5
Total other operating income, net	$ 21	$ 31	$ 32

Other Operating Income, Net a_4

Other Operating Income, Net and Other Non-Operating (Expense) Income, Net - Other Non-Operating Income (Expense), Net (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Other Income and Expenses [Abstract]
(Losses) gains on foreign currency contracts, net	$ (20)	$ 38	$ 16
Pension and other postretirement plans non-service expense	0	1	0
Total other non-operating (expense) income, net	$ (20)	$ 39	$ 16

Quarterly Data (unaudited) (Det

Quarterly Data (unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	Aug. 21, 2019	Aug. 01, 2019	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Quarterly Financial Data [Abstract]
Revenues			$ 1,124	$ 1,199	$ 2,229	$ 2,007	$ 1,150	$ 1,364	$ 2,606	$ 2,200	$ 6,559	$ 7,320	$ 7,651
Operating income (loss)			69	174	362	377	(99)	9	539	168	982	617	1,065
Net income (loss) including noncontrolling interests			10	84	226	212	(131)	(46)	396	89	532	308	822
Net income (loss) attributable to UGI Corporation			$ 9	$ 85	$ 226	$ 212	$ (52)	$ (2)	$ 246	$ 64	$ 532	$ 256	$ 719
Earnings (loss) per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)			$ 0.05	$ 0.41	$ 1.08	$ 1.01	$ (0.27)	$ (0.01)	$ 1.41	$ 0.37	$ 2.55	$ 1.44	$ 4.13
Diluted (in dollars per share)			$ 0.05	$ 0.41	$ 1.07	$ 1	$ (0.27)	$ (0.01)	$ 1.38	$ 0.36	$ 2.54	$ 1.41	$ 4.06
Weighted-average common shares outstanding (thousands):
Basic (in shares)			208,655,000	208,598,000	208,941,000	209,439,000	189,905,000	174,759,000	174,501,000	174,413,000	208,928,000	178,417,000	173,908,000
Diluted (in shares)			209,357,000	208,975,000	209,808,000	211,258,000	189,905,000	174,759,000	177,318,000	177,566,000	209,869,000	181,111,000	176,905,000
Effect of Fourth Quarter Events [Line Items]
Loss on extinguishments of debt						$ 4					$ 0	$ 6
Impairment of intangible assets, finite-lived											$ 0	$ 0	$ 75
Trademarks and tradenames
Effect of Fourth Quarter Events [Line Items]
Impairment of intangible assets, finite-lived				$ 37
Common Stock | Merger Sub
Effect of Fourth Quarter Events [Line Items]
Consideration paid (in shares)	34,612,847	34,613,000										34,613,000

Segment Information - Narrative

Segment Information - Narrative (Details)	12 Months Ended
	Sep. 30, 2020countysegmentstate
Segment Reporting [Abstract]
Number of reportable segments | segment	4
Number of states to which product sale with propane revenue | state	50
Segment Reporting Information [Line Items]
Number of counties	1
UGI Utilities
Segment Reporting Information [Line Items]
Number of counties	2
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	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting Information [Line Items]
Revenues	$ 1,124	$ 1,199	$ 2,229	$ 2,007	$ 1,150	$ 1,364	$ 2,606	$ 2,200	$ 6,559	$ 7,320	$ 7,651
Cost of sales									3,149	4,323	4,075
Operating income (loss)	69	174	362	377	(99)	9	539	168	982	617	1,065
Income (loss) from equity investees									27	9	4
Loss on extinguishments of debt				(4)					0	(6)
Other non-operating (expense) income, net									(20)	39	16
Earnings (losses) before interest expense and income taxes									989	659	1,085
Interest expense									(322)	(258)	(230)
Income tax (expense) benefit									(135)	(93)	(33)
Noncontrolling interests’ net (income) loss									0	(52)	(103)
Net income attributable to UGI Corporation	9	$ 85	$ 226	$ 212	(52)	$ (2)	$ 246	$ 64	532	256	719
Depreciation and amortization									484	448	455
Total assets	13,985				13,347				13,985	13,347	11,981
Short-term borrowings	347				796				347	796	425
Capital expenditures (including the effects of accruals)									665	707	597
Investments in equity investees	200				190				200	190	88
Eliminations
Segment Reporting Information [Line Items]
Revenues									(232)	(306)	(371)
Cost of sales									(229)	(301)	(367)
Operating income (loss)									0	0	1
Income (loss) from equity investees									0	0	0
Loss on extinguishments of debt										0
Other non-operating (expense) income, net									0	(1)	(1)
Earnings (losses) before interest expense and income taxes									0	(1)	0
Interest expense									0	0	0
Income tax (expense) benefit										0	(1)
Noncontrolling interests’ net (income) loss										0	0
Net income attributable to UGI Corporation									0	(1)	(1)
Depreciation and amortization									0	0	0
Total assets	(282)				(353)				(282)	(353)	(125)
Short-term borrowings	0				0				0	0	0
Capital expenditures (including the effects of accruals)									0	0	0
Investments in equity investees	0				0				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									182	235	273
Eliminations | UGI Utilities
Segment Reporting Information [Line Items]
Revenues									47	68	94
Operating Segments | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues									2,381	2,682	2,823
Cost of sales									960	1,191	1,315
Operating income (loss)									373	404	422
Income (loss) from equity investees									0	0	0
Loss on extinguishments of debt										0
Other non-operating (expense) income, net									0	0	0
Earnings (losses) before interest expense and income taxes									373	404	422
Interest expense									(164)	(167)	(163)
Income tax (expense) benefit									(53)	(26)	(31)
Noncontrolling interests’ net (income) loss										(143)	(152)
Net income attributable to UGI Corporation									156	68	76
Depreciation and amortization									178	179	186
Total assets	4,327				4,095				4,327	4,095	3,934
Short-term borrowings	186				328				186	328	232
Capital expenditures (including the effects of accruals)									135	107	101
Investments in equity investees	0				0				0	0	0
Operating Segments | UGI International
Segment Reporting Information [Line Items]
Revenues									2,127	2,372	2,684
Cost of sales									1,191	1,416	1,620
Operating income (loss)									241	229	248
Income (loss) from equity investees									0	0	(1)
Loss on extinguishments of debt										0
Other non-operating (expense) income, net									18	5	(7)
Earnings (losses) before interest expense and income taxes									259	234	240
Interest expense									(31)	(25)	(21)
Income tax (expense) benefit									(55)	(64)	(69)
Noncontrolling interests’ net (income) loss										0	3
Net income attributable to UGI Corporation									173	145	153
Depreciation and amortization									125	124	141
Total assets	3,123				2,975				3,123	2,975	3,279
Short-term borrowings	1				211				1	211	1
Capital expenditures (including the effects of accruals)									89	106	111
Investments in equity investees	10				12				10	12	13
Operating Segments | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues									1,247	1,516
Revenues from external customers									1,065	1,281	1,149
Cost of sales									892	1,241	1,091
Operating income (loss)									140	105	175
Income (loss) from equity investees									27	9	5
Loss on extinguishments of debt										0
Other non-operating (expense) income, net									1	0	(1)
Earnings (losses) before interest expense and income taxes									168	114	179
Interest expense									(42)	(9)	(2)
Income tax (expense) benefit									(34)	(27)	(50)
Noncontrolling interests’ net (income) loss										0	0
Net income attributable to UGI Corporation									92	78	127
Depreciation and amortization									75	51	43
Total assets	2,775				2,745				2,775	2,745	1,329
Short-term borrowings	19				91				19	91	2
Capital expenditures (including the effects of accruals)									93	138	43
Investments in equity investees	190				178				190	178	75
Operating Segments | UGI Utilities
Segment Reporting Information [Line Items]
Revenues									1,030	1,049
Revenues from external customers									983	981	998
Cost of sales									448	481	523
Operating income (loss)									229	224	240
Income (loss) from equity investees									0	0	0
Loss on extinguishments of debt										0
Other non-operating (expense) income, net									0	2	(2)
Earnings (losses) before interest expense and income taxes									229	226	238
Interest expense									(54)	(50)	(43)
Income tax (expense) benefit									(39)	(43)	(54)
Noncontrolling interests’ net (income) loss										0	0
Net income attributable to UGI Corporation									136	133	141
Depreciation and amortization									105	93	85
Total assets	3,809				3,560				3,809	3,560	3,266
Short-term borrowings	141				166				141	166	190
Capital expenditures (including the effects of accruals)									348	355	339
Investments in equity investees	0				0				0	0	0
Corporate & Other
Segment Reporting Information [Line Items]
Revenues									6	7
Revenues from external customers									3	4	(3)
Cost of sales									(113)	295	(107)
Operating income (loss)									(1)	(345)	(21)
Income (loss) from equity investees									0	0	0
Loss on extinguishments of debt										(6)
Other non-operating (expense) income, net									(39)	33	27
Earnings (losses) before interest expense and income taxes									(40)	(318)	6
Interest expense									(31)	(7)	(1)
Income tax (expense) benefit									46	67	172
Noncontrolling interests’ net (income) loss										91	46
Net income attributable to UGI Corporation									(25)	(167)	223
Depreciation and amortization									1	1	0
Total assets	233				325				233	325	298
Short-term borrowings	0				0				0	0	0
Capital expenditures (including the effects of accruals)									0	1	3
Investments in equity investees	$ 0				$ 0				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	$ 4

Segment Information - Corporate

Segment Information - Corporate and Other segment information (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions									$ 81	$ (259)	$ 133
Loss on extinguishments of debt				$ (4)					0	(6)
Loss on disposals of Conemaugh and HVAC									(54)	0	0
AmeriGas Merger expenses									0	0	(75)
Operating income (loss)	$ (69)	$ (174)	$ (362)	$ (377)	$ 99	$ (9)	$ (539)	$ (168)	(982)	(617)	(1,065)
AmeriGas Propane | Scenario, Adjustment
Segment Reporting Information [Line Items]
Operating income (loss)									113
UGI International | Scenario, Adjustment
Segment Reporting Information [Line Items]
Operating income (loss)									4
Midstream & Marketing | Scenario, Adjustment
Segment Reporting Information [Line Items]
Operating income (loss)									70
UGI Utilities | Scenario, Adjustment
Segment Reporting Information [Line Items]
Operating income (loss)									8
Corporate & Other
Segment Reporting Information [Line Items]
Loss on extinguishments of debt										(6)
Operating income (loss)									1	345	21
Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishments of debt										0
LPG business transformation expenses									(44)	(15)
Loss on disposals of Conemaugh and HVAC									0
AmeriGas Merger expenses										(6)	(75)
Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Loss on extinguishments of debt										(6)
LPG business transformation expenses									(18)	(9)
Loss on disposals of Conemaugh and HVAC									0
AmeriGas Merger expenses										0	0
Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishments of debt										0
LPG business transformation expenses									0	0
Loss on disposals of Conemaugh and HVAC									(54)
AmeriGas Merger expenses										0	0
Commodity contracts | Corporate & Other | AmeriGas Propane | Revenues
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions									0	0	0
Commodity contracts | Corporate & Other | AmeriGas Propane | Cost of sales
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions									72	(117)	13
Commodity contracts | Corporate & Other | UGI International | Revenues
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions									0	0	0
Commodity contracts | Corporate & Other | UGI International | Cost of sales
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions									0	(143)	93
Commodity contracts | Corporate & Other | Midstream & Marketing | Revenues
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions									3	4	(4)
Commodity contracts | Corporate & Other | Midstream & Marketing | Cost of sales
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions									42	(35)	2
Foreign currency contracts | Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions									0	0	0
Foreign currency contracts | Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions									(36)	32	29
Foreign currency contracts | Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions									0	0	0
Trademarks and tradenames
Segment Reporting Information [Line Items]
AmeriGas Merger expenses		$ (37)
Affiliated Entity | CMG | Pennant | Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition									0	0
Affiliated Entity | CMG | Pennant | Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition									0	0
Affiliated Entity | CMG | Pennant | Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition									$ (2)	$ (16)
Affiliated Entity | Finagaz | Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition											0
Affiliated Entity | Finagaz | Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition											(31)
Affiliated Entity | Finagaz | Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition											$ 0

Global LPG Business Transform_2

Global LPG Business Transformation Initiatives (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Restructuring and Related Activities [Abstract]
Costs principally comprising consulting, advisory and employee-related costs	$ 62	$ 24

SCHEDULE I _ CONDENSED FINANC_3

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) - BALANCE SHEETS (Details) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2017
Current assets
Cash and cash equivalents	$ 336	$ 447	$ 452	$ 558
Prepaid expenses and other current assets	59	68
Total current assets	1,543	1,566
Other assets	854	498
Total assets	13,985	13,347	$ 11,981
Current liabilities
Current maturities of long-term debt	53	24
Total current liabilities	1,755	2,028
Long-term debt	5,981	5,780
Other noncurrent liabilities	1,413	1,123
Total liabilities	9,848	9,520
Commitments and contingencies (Note 1)
Common stockholders’ equity:
Common Stock, without par value (authorized – 450,000,000 shares; issued – 209,514,044 and 209,304,129 shares, respectively)	1,416	1,397
Retained earnings	2,908	2,653
Accumulated other comprehensive loss	(147)	(217)
Treasury stock, at cost	(49)	(16)
Total UGI Corporation stockholders’ equity	4,128	3,817
Total liabilities and equity	$ 13,985	$ 13,347
Condensed Financial Information of Registrant [Abstract]
Common stock, shares authorized (in shares)	450,000,000	450,000,000
Common stock, shares issued (in shares)	209,514,044	209,304,129
Parent Company
Current assets
Cash and cash equivalents	$ 67	$ 54
Accounts receivable – related parties	11	5
Prepaid expenses and other current assets	15	23
Total current assets	93	82
Property, plant and equipment, net	2	3
Investments in subsidiaries	4,898	4,585
Other assets	87	77
Total assets	5,080	4,747
Current liabilities
Current maturities of long-term debt	30	0
Accounts and notes payable	15	15
Accrued liabilities	29	9
Total current liabilities	74	24
Long-term debt	817	846
Other noncurrent liabilities	61	60
Total liabilities	952	930
Commitments and contingencies (Note 1)
Common stockholders’ equity:
Common Stock, without par value (authorized – 450,000,000 shares; issued – 209,514,044 and 209,304,129 shares, respectively)	1,416	1,397
Retained earnings	2,908	2,653
Accumulated other comprehensive loss	(147)	(217)
Treasury stock, at cost	(49)	(16)
Total UGI Corporation stockholders’ equity	4,128	3,817
Total liabilities and equity	$ 5,080	$ 4,747
Condensed Financial Information of Registrant [Abstract]
Common stock, shares issued (in shares)	209,514,044	209,304,129

SCHEDULE I _ CONDENSED FINANC_4

SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY) - Narrative (Details)	12 Months Ended
	Sep. 30, 2020USD ($)
Guarantee Obligations [Line Items]
Debt repayment in year 2021	$ 53,000,000
Debt repayment in year 2022	339,000,000
Debt repayment in year 2023	147,000,000
Debt repayment in year 2024	1,516,000,000
Parent Company
Guarantee Obligations [Line Items]
Surety bonds indemnified	80,000,000
Maximum amount authorized to guarantee obligations to suppliers and customers (up to)	475,000,000
Current carrying value	396,000,000
Debt repayment in year 2021	30,000,000
Debt repayment in year 2022	300,000,000
Debt repayment in year 2023	38,000,000
Debt repayment in year 2024	$ 482,000,000

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	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 1,124	$ 1,199	$ 2,229	$ 2,007	$ 1,150	$ 1,364	$ 2,606	$ 2,200	$ 6,559	$ 7,320	$ 7,651
Costs and expenses:
Operating and administrative expenses									1,911	1,963	2,013
Other operating income, net									21	31	32
Total costs and expenses									5,577	6,703	6,586
Operating income	69	174	362	377	(99)	9	539	168	982	617	1,065
Pension and other postretirement plans non-service expense									0	1	0
Income tax expense (benefit)									135	93	33
Equity in income of unconsolidated subsidiaries									27	9	4
Net income attributable to UGI Corporation	$ 9	$ 85	$ 226	$ 212	$ (52)	$ (2)	$ 246	$ 64	532	256	719
Comprehensive income attributable to UGI Corporation									$ 602	$ 156	$ 702
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)	$ 0.05	$ 0.41	$ 1.08	$ 1.01	$ (0.27)	$ (0.01)	$ 1.41	$ 0.37	$ 2.55	$ 1.44	$ 4.13
Diluted (in dollars per share)	$ 0.05	$ 0.41	$ 1.07	$ 1	$ (0.27)	$ (0.01)	$ 1.38	$ 0.36	$ 2.54	$ 1.41	$ 4.06
Weighted - average common shares outstanding (thousands):
Basic (in shares)	208,655	208,598	208,941	209,439	189,905	174,759	174,501	174,413	208,928	178,417	173,908
Diluted (in shares)	209,357	208,975	209,808	211,258	189,905	174,759	177,318	177,566	209,869	181,111	176,905
Parent Company
Condensed Financial Statements, Captions [Line Items]
Revenues									$ 0	$ 0	$ 0
Costs and expenses:
Operating and administrative expenses									56	50	63
Other operating income, net									(54)	(50)	(52)
Total costs and expenses									2	0	11
Operating income									(2)	0	(11)
Pension and other postretirement plans non-service expense									0	(1)	(1)
Interest expense									(32)	(6)
Loss before income taxes									(34)	(7)	(12)
Income tax expense (benefit)									17	(3)	6
Loss before equity in income of unconsolidated subsidiaries									(51)	(4)	(18)
Equity in income of unconsolidated subsidiaries									583	260	737
Net income attributable to UGI Corporation									532	256	719
Other comprehensive (loss) income									(12)	(3)	3
Equity in other comprehensive income (loss) of unconsolidated subsidiaries									82	(97)	(20)
Comprehensive income attributable to UGI Corporation									$ 602	$ 156	$ 702
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in dollars per share)									$ 2.55	$ 1.44	$ 4.13
Diluted (in dollars per share)									$ 2.54	$ 1.41	$ 4.06
Weighted - average common shares outstanding (thousands):
Basic (in shares)									208,928	178,417	173,908
Diluted (in shares)									209,869	181,111	176,905

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, 2020	Sep. 30, 2019	Sep. 30, 2018
Condensed Financial Statements, Captions [Line Items]
NET CASH PROVIDED BY OPERATING ACTIVITIES	$ 1,102	$ 1,078	$ 1,085
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(655)	(705)	(574)
Net cash used by investing activities	(649)	(2,055)	(749)
CASH FLOWS FROM FINANCING ACTIVITIES
Payment of dividends on Common Stock	(273)	(200)	(177)
Issuances of debt, net of issuance costs	209	2,412	124
Repayments of long-term debt	(86)	(738)	(149)
Issuances of Common Stock	2	17	35
Repurchases of UGI Common Stock	(38)	(17)	(60)
Other	0	(11)	(5)
Net cash (used) provided by financing activities	(635)	1,042	(438)
Cash, cash equivalents and restricted cash (decrease) increase	(154)	49	(107)
Cash and cash equivalents:
Cash, cash equivalents and restricted cash at end of year	357	511	462
Cash, cash equivalents and restricted cash at beginning of year	511	462	569
Cash and cash equivalents increase (decrease)	(154)	49	(107)
Parent Company
Condensed Financial Statements, Captions [Line Items]
NET CASH PROVIDED BY OPERATING ACTIVITIES	322	170	208
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	0	0	(2)
Net investments in unconsolidated subsidiaries	0	(768)	(7)
Net cash used by investing activities	0	(768)	(9)
CASH FLOWS FROM FINANCING ACTIVITIES
Payment of dividends on Common Stock	(273)	(200)	(177)
Issuances of debt, net of issuance costs	60	846	0
Repayments of long-term debt	(60)	0	0
Issuances of Common Stock	2	17	35
Repurchases of UGI Common Stock	(38)	(17)	(60)
Other	0	(7)	0
Net cash (used) provided by financing activities	(309)	639	(202)
Cash, cash equivalents and restricted cash (decrease) increase	13	41	(3)
Cash and cash equivalents:
Cash, cash equivalents and restricted cash at end of year	67	54	13
Cash, cash equivalents and restricted cash at beginning of year	54	13	16
Cash and cash equivalents increase (decrease)	13	41	(3)
Dividends from unconsolidated subsidiaries	$ 352	$ 163	$ 191

SCHEDULE II _ VALUATION AND Q_2

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Allowance for doubtful accounts
Valuation and Qualifying Account
Balance at beginning of year	$ 32	$ 35	$ 27
Charged (credited) to costs and expenses	32	29	36
Other	(22)	(32)	(28)
Balance at end of year	42	32	35
Deferred tax assets valuation allowance
Valuation and Qualifying Account
Balance at beginning of year	91	117	107
Charged (credited) to costs and expenses	0	(26)	10
Other	14	0	0
Balance at end of year	$ 105	$ 91	$ 117