UGI (UGI) 10-Q 4 Aug 22 2022 Q3 Quarterly report Financial data

Cover Page

Cover Page - shares	9 Months Ended
	Jun. 30, 2022	Jul. 31, 2022
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2022
Document Transition Report	false
Entity File Number	1-11071
Entity Registrant Name	UGI CORPORATION
Entity Incorporation, State or Country Code	PA
Entity Tax Identification Number	23-2668356
Entity Address, Address Line One	460 North Gulph Road
Entity Address, City or Town	King of Prussia
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	19406
City Area Code	610
Local Phone Number	337-1000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		209,381,438
Entity Central Index Key	0000884614
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--09-30
Common Stock, without par value
Document Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	UGI
Security Exchange Name	NYSE
Corporate Units
Document Information [Line Items]
Title of 12(b) Security	Corporate Units
Trading Symbol	UGIC
Security Exchange Name	NYSE

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) - USD ($) $ in Millions	Jun. 30, 2022	Sep. 30, 2021	Jun. 30, 2021
Current assets:
Cash and cash equivalents	$ 670	$ 855	$ 545
Restricted cash	14	22	31
Accounts receivable (less allowances for doubtful accounts of $66, $53 and $51, respectively)	1,234	880	848
Accrued utility revenues	19	15	8
Income taxes receivable	127	128	128
Inventories	496	469	296
Derivative instruments	773	665	350
Prepaid expenses and other current assets	176	236	171
Total current assets	3,509	3,270	2,377
Property, plant and equipment, (less accumulated depreciation of $4,160, $3,950 and $3,923, respectively)	7,839	7,558	7,085
Goodwill	3,671	3,770	3,543
Intangible assets, net	523	583	624
Utility regulatory assets	352	373	389
Derivative instruments	410	338	129
Other assets	807	831	859
Total assets	17,111	16,723	15,006
Current liabilities:
Current maturities of long-term debt	47	110	36
Short-term borrowings	276	367	207
Accounts payable	843	837	579
Derivative instruments	70	60	67
Other current liabilities	832	923	812
Total current liabilities	2,068	2,297	1,701
Long-term debt	6,399	6,339	5,811
Deferred income taxes	1,291	1,137	919
Derivative instruments	54	38	49
Other noncurrent liabilities	1,294	1,381	1,420
Total liabilities	11,106	11,192	9,900
Commitments and contingencies (Note 9)
UGI Corporation stockholders’ equity:
Preferred stock, without par value (authorized – 5,000,000 shares; issued – 220,000, 220,000 and 220,000 Series A shares, respectively)	162	213	213
UGI Common Stock, without par value (authorized — 450,000,000 shares; issued — 210,378,881, 209,843,296 and 209,725,554 shares, respectively)	1,474	1,394	1,388
Retained earnings	4,674	4,081	3,629
Accumulated other comprehensive loss	(273)	(140)	(105)
Treasury stock, at cost	(41)	(26)	(28)
Total UGI Corporation stockholders’ equity	5,996	5,522	5,097
Noncontrolling interests	9	9	9
Total equity	6,005	5,531	5,106
Total liabilities and equity	$ 17,111	$ 16,723	$ 15,006

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2022	Sep. 30, 2021	Jun. 30, 2021
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 66	$ 53	$ 51
Accumulated depreciation	$ 4,160	$ 3,950	$ 3,923
Preferred Stock, shares authorized (in shares)	5,000,000	5,000,000	5,000,000
Preferred Stock, shares issued (in shares)	220,000	220,000	220,000
Common Stock, shares authorized (in shares)	450,000,000	450,000,000	450,000,000
Common Stock, shares issued (in shares)	210,378,881	209,843,296	209,725,554

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (unaudited) - USD ($) shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Income Statement [Abstract]
Revenues	$ 2,033	$ 1,496	$ 8,172	$ 6,009
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)	1,361	516	4,951	2,623
Operating and administrative expenses	465	469	1,532	1,473
Depreciation and amortization	130	125	387	375
Other operating income, net	(22)	(5)	(61)	(26)
Costs and expenses	1,934	1,105	6,809	4,445
Operating income	99	391	1,363	1,564
Loss from equity investees	(45)	(86)	(32)	(69)
Loss on extinguishment of debt	0	0	(11)	0
Other non-operating income, net	20	1	41	0
Interest expense	(82)	(77)	(245)	(233)
(Loss) income before income taxes	(8)	229	1,116	1,262
Income tax benefit (expense)	1	(79)	(285)	(320)
Net (loss) income including noncontrolling interests	(7)	150	831	942
Deduct net income attributable to noncontrolling interests	0	0	(2)	0
Net (loss) income attributable to UGI Corporation	$ (7)	$ 150	$ 829	$ 942
(Loss) earnings per common share attributable to UGI Corporation stockholders:
Basic (in USD per share)	$ (0.03)	$ 0.72	$ 3.95	$ 4.51
Diluted (in USD per share)	$ (0.03)	$ 0.71	$ 3.84	$ 4.48
Weighted-average common shares outstanding (thousands):
Basic (in shares)	210,190	209,099	209,992	208,934
Diluted (in shares)	210,190	210,851	215,965	210,194

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Statement of Comprehensive Income [Abstract]
Net (loss) income including noncontrolling interests	$ (7)	$ 150	$ 831	$ 942
Other comprehensive (loss) income:
Net gains on derivative instruments (net of tax of $(3), $1, $(17) and $(1), respectively)	8	0	42	4
Reclassifications of net losses on derivative instruments (net of tax of $(1), $(1), $(4) and $(5), respectively)	3	5	13	14
Foreign currency adjustments (net of tax of $(17), $3, $(30) and $5, respectively)	(106)	16	(191)	23
Benefit plans (net of tax of $0, $(1), $(1) and $(1), respectively)	0	0	3	1
Other comprehensive (loss) income	(95)	21	(133)	42
Comprehensive (loss) income including noncontrolling interests	(102)	171	698	984
Deduct comprehensive income attributable to noncontrolling interests	0	0	(2)	0
Comprehensive (loss) income attributable to UGI Corporation	$ (102)	$ 171	$ 696	$ 984

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Statement of Comprehensive Income [Abstract]
Net gains on derivative instruments, tax	$ (3)	$ 1	$ (17)	$ (1)
Reclassifications of net losses on derivative instruments, tax	(1)	(1)	(4)	(5)
Foreign currency adjustments, tax	(17)	3	(30)	5
Benefit plans, tax	$ 0	$ (1)	$ (1)	$ (1)

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) - USD ($) $ in Millions	9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income including noncontrolling interests	$ 831	$ 942
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization	387	375
Deferred income tax expense, net	142	267
Provision for uncollectible accounts	46	25
Changes in unrealized gains and losses on derivative instruments	(372)	(509)
Loss on extinguishment of debt	11	0
Loss from equity investees	32	69
Other, net	37	10
Net change in:
Accounts receivable and accrued utility revenues	(486)	(213)
Income taxes receivable	1	(48)
Inventories	(42)	(55)
Utility deferred fuel and power costs, net of changes in unsettled derivatives	(7)	(9)
Accounts payable	50	123
Derivative instruments collateral deposits received	181	112
Other current assets	93	(17)
Other current liabilities	(56)	(25)
Net cash provided by operating activities	848	1,047
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(551)	(460)
Acquisitions of businesses and assets, net of cash and restricted cash acquired	(188)	(8)
Investments in equity method investees	(41)	(61)
Settlements of net investment hedges	26	0
Other, net	37	24
Net cash used by investing activities	(717)	(505)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(220)	(210)
Issuances of long-term debt, net of issuance costs	863	130
Repayments of long-term debt and finance leases, including redemption premiums	(806)	(329)
Decrease in short-term borrowings	(91)	(121)
Receivables Facility net repayments	0	(19)
Issuance of preferred stock, net of issuance costs	0	213
Payments on Purchase Contracts	(12)	0
Issuances of UGI Common Stock	14	15
Repurchases of UGI Common Stock	(38)	0
Net cash used by financing activities	(290)	(321)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(34)	(2)
Cash, cash equivalents and restricted cash (decrease) increase	(193)	219
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of period	684	576
Cash, cash equivalents and restricted cash at beginning of period	877	357
Cash, cash equivalents and restricted cash (decrease) increase	$ (193)	$ 219

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (unaudited) - USD ($) $ in Millions	Total	Total UGI stockholders’ equity	Preferred stock, without par value	Common stock, without par value	Retained earnings	Accumulated other comprehensive income (loss)	Treasury stock	Noncontrolling interests
Balance, beginning of period at Sep. 30, 2020			$ 0	$ 1,416	$ 2,908	$ (147)	$ (49)	$ 9
Increase (Decrease) in Stockholders' Equity
Issuance of preferred stock and equity			213	(45)
Other				(2)
Common Stock issued in connection with employee and director plans, net of tax withheld				6
Equity-based compensation expense				13
Losses on common stock transactions in connection with employee and director plans					(11)
Net (loss) income attributable to UGI Corporation	$ 942				942
Cash dividends on UGI Common Stock ($0.36, $0.35, $1.05, and $1.01, respectively)					(210)
Net gains on derivative instruments	4					4
Reclassification of net losses on derivative instruments	14					14
Benefit plans	1					1
Foreign currency adjustments	23					23
Common Stock issued in connection with employee and director plans, net of tax withheld							22
Reacquired UGI Common Stock - employee and director plans							(1)
Net (loss) income including noncontrolling interests	942
Balance, end of period at Jun. 30, 2021	5,106	$ 5,097	213	1,388	3,629	(105)	(28)	9
Balance, beginning of period at Mar. 31, 2021			0	1,428	3,557	(126)	(40)	9
Increase (Decrease) in Stockholders' Equity
Issuance of preferred stock and equity			213	(45)
Other				(2)
Common Stock issued in connection with employee and director plans, net of tax withheld				3
Equity-based compensation expense				4
Losses on common stock transactions in connection with employee and director plans					(6)
Net (loss) income attributable to UGI Corporation	150				150
Cash dividends on UGI Common Stock ($0.36, $0.35, $1.05, and $1.01, respectively)					(72)
Net gains on derivative instruments	0
Reclassification of net losses on derivative instruments	5					5
Benefit plans	0
Foreign currency adjustments	16					16
Common Stock issued in connection with employee and director plans, net of tax withheld							12
Net (loss) income including noncontrolling interests	150
Balance, end of period at Jun. 30, 2021	5,106	5,097	213	1,388	3,629	(105)	(28)	9
Balance, beginning of period at Sep. 30, 2021	5,531		213	1,394	4,081	(140)	(26)	9
Increase (Decrease) in Stockholders' Equity
Beneficial conversion feature			1		(1)
Other			(52)	53				(2)
Common Stock issued in connection with employee and director plans, net of tax withheld				13
Equity-based compensation expense				14
Losses on common stock transactions in connection with employee and director plans					(15)
Net (loss) income attributable to UGI Corporation	829				829
Cash dividends on UGI Common Stock ($0.36, $0.35, $1.05, and $1.01, respectively)					(220)
Net gains on derivative instruments	42					42
Reclassification of net losses on derivative instruments	13					13
Benefit plans	3					3
Foreign currency adjustments	(191)					(191)
Common Stock issued in connection with employee and director plans, net of tax withheld							33
Repurchases of UGI Common Stock							(38)
Reacquired UGI Common Stock - employee and director plans							(10)
Net (loss) income including noncontrolling interests	831							2
Balance, end of period at Jun. 30, 2022	6,005	5,996	162	1,474	4,674	(273)	(41)	9
Balance, beginning of period at Mar. 31, 2022			161	1,465	4,757	(178)	(5)	10
Increase (Decrease) in Stockholders' Equity
Beneficial conversion feature			1		(1)
Other								(1)
Common Stock issued in connection with employee and director plans, net of tax withheld				5
Equity-based compensation expense				4
Net (loss) income attributable to UGI Corporation	(7)				(7)
Cash dividends on UGI Common Stock ($0.36, $0.35, $1.05, and $1.01, respectively)					(75)
Net gains on derivative instruments	8					8
Reclassification of net losses on derivative instruments	3					3
Benefit plans	0
Foreign currency adjustments	(106)					(106)
Common Stock issued in connection with employee and director plans, net of tax withheld							3
Repurchases of UGI Common Stock							(38)
Reacquired UGI Common Stock - employee and director plans							(1)
Net (loss) income including noncontrolling interests	(7)
Balance, end of period at Jun. 30, 2022	$ 6,005	$ 5,996	$ 162	$ 1,474	$ 4,674	$ (273)	$ (41)	$ 9

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (unaudited) (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Statement of Stockholders' Equity [Abstract]
Cash dividends on common stock (in USD per share)	$ 0.36	$ 0.35	$ 1.05	$ 1.01

Nature of Operations

Nature of Operations	9 Months Ended
	Jun. 30, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations	Note 1 — Nature of Operations UGI is a holding company that, through subsidiaries and affiliates, distributes, stores, transports and markets energy products and related services. In the U.S., we own and operate (1) a retail propane marketing and distribution business; (2) natural gas and electric distribution utilities; and (3) energy marketing, midstream infrastructure, storage, natural gas gathering and processing, natural gas production, electricity generation and energy services businesses. In Europe, we market and distribute propane and other LPG, and market other energy products and services. We conduct a domestic propane marketing and distribution business through AmeriGas Partners. AmeriGas Partners conducts a national propane distribution business through its principal operating subsidiary, AmeriGas OLP. UGI International, through subsidiaries and affiliates, conducts (1) an LPG distribution business throughout much of Europe and (2) an energy marketing business in France, Belgium, the Netherlands and the United Kingdom. These businesses are conducted principally through our subsidiaries, UGI France, Flaga, AvantiGas, DVEP and UniverGas. Energy Services conducts, directly and through subsidiaries and affiliates, energy marketing, including RNG, midstream transmission, LNG storage, natural gas gathering and processing, natural gas and RNG production, electricity generation and energy services businesses primarily in the eastern region of the U.S., eastern Ohio, the panhandle of West Virginia and California. UGID owns electricity generation facilities principally located in Pennsylvania. Energy Services and its subsidiaries’ storage, LNG and portions of its midstream transmission operations are subject to regulation by the FERC. On September 1, 2021, UGI acquired Mountaineer, the largest natural gas distribution company in West Virginia, for a purchase price of $540, which includes the assumption of approximately $140 principal amounts of long-term debt. Mountaineer serves more than 200,000 customers across 50 of the state’s 55 counties. Mountaineer is subject to regulation by the WVPSC. For additional information on the Mountaineer Acquisition, see Note 5. Upon the acquisition of Mountaineer, our Utilities segment includes UGI Utilities and Mountaintop Energy Holdings, LLC. UGI Utilities directly owns and operates PA Gas Utility, a natural gas distribution utility business in eastern and central Pennsylvania and in a portion of one Maryland county. PA 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	9 Months Ended
	Jun. 30, 2022
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 2 — Summary of Significant Accounting Policies The accompanying condensed consolidated financial statements are unaudited and have been prepared in accordance with the rules and regulations of the SEC. They include all adjustments that we consider necessary for a fair statement of the results for the interim periods presented. Such adjustments consisted only of normal recurring items unless otherwise disclosed. The September 30, 2021, Condensed Consolidated Balance Sheet was derived from audited financial statements but does not include all footnote disclosures from the annual financial statements. These financial statements should be read in conjunction with the financial statements and related notes included in the Company’s 2021 Annual Report. Due to the seasonal nature of our businesses, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year. Restricted Cash. Restricted cash principally represents those cash balances in our commodity futures brokerage accounts that are restricted from withdrawal. The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Condensed Consolidated Balance Sheets to the corresponding amounts reported on the Condensed Consolidated Statements of Cash Flows. June 30, June 30, Cash and cash equivalents $ 670 $ 545 Restricted cash 14 31 Cash, cash equivalents and restricted cash $ 684 $ 576 Earnings Per Common Share. Basic earnings per share attributable to UGI stockholders reflect the weighted-average number of common shares outstanding. Diluted earnings per share attributable to UGI stockholders include the effects of dilutive stock options, common stock awards and Equity Units. Shares used in computing basic and diluted earnings per share are as follows: Three Months Ended Nine Months Ended 2022 2021 2022 2021 Denominator (thousands of shares): Weighted-average common shares outstanding — basic 210,190 209,099 209,992 208,934 Incremental shares issuable for stock options, common stock awards and Equity Units (a) — 1,752 5,973 1,260 Weighted-average common shares outstanding — diluted 210,190 210,851 215,965 210,194 (a) For the three months ended June 30, 2022, 5,668 of such shares have been excluded as these incremental shares would be antidilutive due to the net loss for the period. At June 30, 2022 and 2021, there were 5,718 and 2,502 shares, respectively, associated with outstanding stock option awards that were not included in the computation of diluted earnings per share above because their effect was antidilutive. Derivative Instruments. Derivative instruments are reported on the Condensed Consolidated Balance Sheets at their fair values, unless the NPNS exception is elected. The accounting for changes in fair value depends upon the purpose of the derivative instrument, whether it is subject to regulatory ratemaking mechanisms or if it qualifies and is designated as a hedge for accounting purposes. Certain of our derivative instruments qualify and are designated as cash flow hedges. For cash flow hedges, changes in the fair values of the derivative instruments are recorded in AOCI, to the extent effective at offsetting changes in the hedged item, until earnings are affected by the hedged item. We discontinue cash flow hedge accounting if occurrence of the forecasted transaction is determined to be no longer probable. Hedge accounting is also discontinued for derivatives that cease to be highly effective. We do not designate our commodity and certain foreign currency derivative instruments as hedges under GAAP. Changes in the fair values of these derivative instruments are reflected in net income. Gains and losses on substantially all of the commodity derivative instruments used by Utilities are included in regulatory assets or liabilities because it is probable such gains or losses will be recoverable from, or refundable to, customers. From time to time, we also enter into net investment hedges. Gains and losses on net investment hedges that relate to our foreign operations are included in the cumulative translation adjustment component in AOCI until such foreign net investment is substantially sold or liquidated. Cash flows from derivative instruments, other than certain cross-currency swaps and net investment hedges, if any, are included in cash flows from operating activities on the Condensed 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 Condensed Consolidated Statements of Cash Flows. For a more detailed description of the derivative instruments we use, our accounting for derivatives, our objectives for using them and other information, see Note 12. Use of Estimates. The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based on management’s knowledge of current events, historical experience and various other assumptions that are believed to be reasonable under the circumstances. Accordingly, actual results may be different from these estimates and assumptions. Reclassifications. For purposes of comparability, certain prior-period amounts have been reclassified to conform to the current-period presentation. During the second quarter of Fiscal 2022, the Company reclassified certain amounts on the Consolidated Balance Sheet and Consolidated Statement of Changes in Equity related to the accounting for the Equity Units issued in May 2021.

Accounting Changes

Accounting Changes	9 Months Ended
	Jun. 30, 2022
Accounting Changes and Error Corrections [Abstract]
Accounting Changes	Note 3 — Accounting Changes New Accounting Standard Adopted in Fiscal 2022 Income Taxes. Effective October 1, 2021, the Company adopted ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes” prospectively and retrospectively where deemed applicable. This ASU simplifies the accounting for income taxes by eliminating certain exceptions within the existing guidance for recognizing deferred taxes for equity method investments, performing intraperiod allocations and calculating income taxes in interim periods. Further, this ASU clarifies existing guidance related to, among other things, recognizing deferred taxes for goodwill and allocated taxes to members of a consolidated group. The adoption of the new guidance did not have a material impact on our consolidated financial statements. Accounting Standard Not Yet Adopted Debt and Derivatives and Hedging. In August 2020, the FASB issued ASU 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40).” The amendments in this ASU affect entities that issue convertible instruments and/or contracts indexed to and potentially settled in an entity’s own equity. This ASU reduces the number of accounting models for convertible debt instruments and convertible preferred stock, expands disclosure requirements for convertible instruments, and simplifies the related earnings per share guidance. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2022 (Fiscal 2023). Early adoption is permitted. The amendments in this ASU may be adopted using the modified or full retrospective transition methods. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the transition method and the period in which the new guidance will be adopted.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	9 Months Ended
	Jun. 30, 2022
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	Note 4 — Revenue from Contracts with Customers The Company recognizes revenue when control of promised goods or services is transferred to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. See Note 4 in the Company’s 2021 Annual Report for additional information on our revenues from contracts with customers. Revenue Disaggregation The following tables present our disaggregated revenues by reportable segment: Three Months Ended June 30, 2022 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 140 $ — $ — $ — $ — $ 140 $ — Commercial & Industrial 57 — — — — 57 — Large delivery service 38 — — — — 38 — Off-system sales and capacity releases 9 (24) — — — 33 — Other 5 — — — — 5 — Total Utility 249 (24) — — — 273 — Non-Utility: LPG: Retail 880 — 478 402 — — — Wholesale 107 — 48 59 — — — Energy Marketing 631 (70) — 246 455 — — Midstream: Pipeline 53 — — — 53 — — Peaking 9 (5) — — 14 — — Other 2 — — — 2 — — Electricity Generation 1 — — — 1 — — Other 72 — 51 21 — — — Total Non-Utility 1,755 (75) 577 728 525 — — Total revenues from contracts with customers 2,004 (99) 577 728 525 273 — Other revenues (b) 29 — 20 10 — 1 (2) Total revenues $ 2,033 $ (99) $ 597 $ 738 $ 525 $ 274 $ (2) Three Months Ended June 30, 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 90 $ — $ — $ — $ — $ 90 $ — Commercial & Industrial 34 — — — — 34 — Large delivery service 33 — — — — 33 — Off-system sales and capacity releases 6 (10) — — — 16 — Other 5 — — — — 5 — Total Utility 168 (10) — — — 178 — Non-Utility: LPG: Retail 800 — 424 376 — — — Wholesale 77 — 35 42 — — — Energy Marketing 311 (24) — 129 206 — — Midstream: Pipeline 45 — — — 45 — — Peaking 1 (5) — — 6 — — Other 2 — — — 2 — — Electricity Generation 1 — — — 1 — — Other 69 — 51 18 — — — Total Non-Utility 1,306 (29) 510 565 260 — — Total revenues from contracts with customers 1,474 (39) 510 565 260 178 — Other revenues (b) 22 (1) 16 7 1 3 (4) Total revenues $ 1,496 $ (40) $ 526 $ 572 $ 261 $ 181 $ (4) Nine Months Ended June 30, 2022 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 774 $ — $ — $ — $ — $ 774 $ — Commercial & Industrial 318 — — — — 318 — Large delivery service 135 — — — — 135 — Off-system sales and capacity releases 65 (86) — — — 151 — Other 17 (1) — — — 18 — Total Utility 1,309 (87) — — — 1,396 — Non-Utility: LPG: Retail 3,684 — 2,032 1,652 — — — Wholesale 401 — 172 229 — — — Energy Marketing 2,254 (206) — 1,045 1,415 — — Midstream: Pipeline 149 — — — 149 — — Peaking 38 (101) — — 139 — — Other 6 — — — 6 — — Electricity Generation 20 — — — 20 — — Other 221 — 163 58 — — — Total Non-Utility 6,773 (307) 2,367 2,984 1,729 — — Total revenues from contracts with customers 8,082 (394) 2,367 2,984 1,729 1,396 — Other revenues (b) 90 (2) 56 27 2 4 3 Total revenues $ 8,172 $ (396) $ 2,423 $ 3,011 $ 1,731 $ 1,400 $ 3 Nine Months Ended June 30, 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 498 $ — $ — $ — $ — $ 498 $ — Commercial & Industrial 190 — — — — 190 — Large delivery service 117 — — — — 117 — Off-system sales and capacity releases 43 (49) — — — 92 — Other 16 (1) — — — 17 — Total Utility 864 (50) — — — 914 — Non-Utility: LPG: Retail 3,250 — 1,829 1,421 — — — Wholesale 235 — 92 143 — — — Energy Marketing 1,205 (89) — 470 824 — — Midstream: Pipeline 138 — — — 138 — — Peaking 12 (94) — — 106 — — Other 6 — — — 6 — — Electricity Generation 8 — — — 8 — — Other 211 — 161 50 — — — Total Non-Utility 5,065 (183) 2,082 2,084 1,082 — — Total revenues from contracts with customers 5,929 (233) 2,082 2,084 1,082 914 — Other revenues (b) 80 (3) 50 22 4 9 (2) Total revenues $ 6,009 $ (236) $ 2,132 $ 2,106 $ 1,086 $ 923 $ (2) (a) Includes intersegment revenues principally among Midstream & Marketing, Utilities and AmeriGas Propane. (b) Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, revenues from alternative revenue programs at UGI Utilities and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP. Contract Balances The timing of revenue recognition may differ from the timing of invoicing to customers or cash receipts. Contract assets represent our right to consideration after the performance obligations have been satisfied when such right is conditioned on something other than the passage of time. Contract assets were not material for all periods presented. Substantially all of our receivables are unconditional rights to consideration and are included in “Accounts receivable” and, in the case of Utilities, “Accrued utility revenues” on the Condensed Consolidated Balance Sheets. Amounts billed are generally due within the following month. Contract liabilities arise when payment from a customer is received before the performance obligations have been satisfied and represent the Company’s obligations to transfer goods or services to a customer for which we have received consideration. The balances of contract liabilities were $128, $149 and $109 at June 30, 2022, September 30, 2021 and June 30, 2021, respectively, and are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets. Revenues recognized for the nine months ended June 30, 2022 and 2021, from the amounts included in contract liabilities at September 30, 2021 and 2020, were $117 and $137, respectively. Remaining Performance Obligations The Company excludes disclosures related to the aggregate amount of the transaction price allocated to certain performance obligations that are unsatisfied as of the end of the reporting period because these contracts have an initial expected term of one year or less, or we have a right to bill the customer in an amount that corresponds directly with the value of services provided to the customer to date. Certain contracts with customers at Midstream & Marketing and Utilities contain minimum future performance obligations through 2047 and 2053, respectively. At June 30, 2022, Midstream & Marketing and Utilities expect to record approximately $2.3 billion and $0.2 billion of revenues, respectively, related to the minimum future performance obligations over the remaining terms of the related contracts.

Acquisitions

Acquisitions	9 Months Ended
	Jun. 30, 2022
Business Combination and Asset Acquisition [Abstract]
Acquisitions	Note 5 — Acquisitions Stonehenge Acquisition On January 27, 2022, UGI through its wholly owned indirect subsidiary, Energy Services, completed the Stonehenge Acquisition in which Energy Services acquired all of the equity interests in Stonehenge for total cash consideration of approximately $190. The Stonehenge business includes a natural gas gathering system, located in western Pennsylvania, with more than 47 miles of pipeline and associated compression assets. The Stonehenge Acquisition is consistent with our growth strategies, including expanding our midstream natural gas gathering assets within the Appalachian basin production region. The Stonehenge Acquisition was funded using available cash. The Company has accounted for the Stonehenge Acquisition using the acquisition method and the purchase price has been primarily allocated to property, plant and equipment. We refer to Stonehenge and its assets as “UGI Moraine East”. Mountaineer Acquisition On September 1, 2021, UGI completed the Mountaineer Acquisition in which UGI acquired all of the equity interests in Mountaineer, the largest natural gas distribution company in West Virginia, for a purchase price of $540, including the assumption of $140 principal amounts of long-term debt. The Mountaineer Acquisition was consummated pursuant to a purchase and sale agreement between UGI and the iCON Sellers and is consistent with our growth strategies, including expanding our core utility operations in the mid-Atlantic region. The Mountaineer Acquisition was funded with cash proceeds from the UGI Corporation Senior Credit Facility $215 term loan and cash on hand including proceeds from the issuance of Equity Units . Accounts associated with Mountaineer are included within our Utilities reportable segment. The Company has accounted for the Mountaineer Acquisition using the acquisition method. During the nine months ended June 30, 2022, the Company recorded an adjustment to decrease goodwill by $5 primarily reflecting an adjustment to a valuation allowance on certain deferred income taxes. The Condensed Balance Sheet at June 30, 2022, reflects the final allocation of the purchase price to the assets acquired and liabilities assumed for the Mountaineer Acquisition. The components of the Mountaineer purchase price allocations are as follows: Assets acquired: Cash and cash equivalents $ 3 Accounts receivable 14 Inventories 41 Other current assets 21 Property, plant and equipment 397 Other noncurrent assets 48 Total assets acquired $ 524 Liabilities assumed: Short-term borrowings $ 55 Accounts payable 20 Other current liabilities 52 Long-term debt 164 Pension and other postretirement benefit obligation 33 Deferred income taxes 21 Other noncurrent liabilities 29 Total liabilities assumed $ 374 Goodwill 250 Net consideration transferred $ 400 Mountaineer is a regulated entity which accounts for the financial effects of regulation in accordance with ASC 980. The effects of regulation can impact the fair value of certain assets and liabilities acquired, and as such, the measurement of the fair value of regulated property assets using the predecessor’s carrying value is generally accepted since regulation attaches to the assets and regulation is so pervasive that the regulation extends to the individual assets. In certain other instances where assets or liabilities are subject to rate recovery, we recorded fair value adjustments to such assets and liabilities as regulatory assets and liabilities. The excess of the purchase price for the Mountaineer Acquisition over the fair values of the assets acquired and liabilities assumed has been reflected as goodwill, assigned to the Utilities reportable segment. Goodwill is attributable to the assembled workforce of Mountaineer, planned customer growth and planned growth in rate base through continued investment in utility infrastructure. The goodwill recognized from the Mountaineer Acquisition is not expected to be deductible for income tax purposes. The impact of the Mountaineer Acquisition on a pro forma basis as if the Mountaineer Acquisition had occurred on October 1, 2020 was not material to the Company’s revenues or net income for the three and nine months ended June 30, 2021.

Inventories

Inventories	9 Months Ended
	Jun. 30, 2022
Inventory Disclosure [Abstract]
Inventories	Note 6 — Inventories Inventories comprise the following: June 30, September 30, June 30, Non-utility LPG and natural gas $ 261 $ 278 $ 187 Gas Utility natural gas 84 68 16 Energy certificates 70 53 42 Materials, supplies and other 81 70 51 Total inventories $ 496 $ 469 $ 296

Utility Regulatory Assets and L

Utility Regulatory Assets and Liabilities and Regulatory Matters	9 Months Ended
	Jun. 30, 2022
Regulated Operations [Abstract]
Utility Regulatory Assets and Liabilities and Regulatory Matters	Note 7 — Utility Regulatory Assets and Liabilities and Regulatory Matters For a description of the Company’s regulatory assets and liabilities, other than those described below, see Note 9 in the Company’s 2021 Annual Report. Other than removal costs, Utilities currently does not recover a rate of return on its regulatory assets listed below. The following regulatory assets and liabilities associated with Utilities are included on the Condensed Consolidated Balance Sheets: June 30, September 30, June 30, Regulatory assets (a): Income taxes recoverable $ 151 $ 143 $ 131 Underfunded pension and postretirement plans 103 108 166 Environmental costs 34 58 58 Deferred fuel and power costs 14 11 — Removal costs, net 22 24 24 Other 47 53 17 Total regulatory assets $ 371 $ 397 $ 396 Regulatory liabilities (a): Postretirement benefit overcollections $ 12 $ 13 $ 12 Deferred fuel and power refunds 1 36 21 State tax benefits — distribution system repairs 34 32 30 Excess federal deferred income taxes 281 287 269 Other 8 20 2 Total regulatory liabilities $ 336 $ 388 $ 334 (a) Current regulatory assets are included in “Prepaid expenses and other current assets” and regulatory liabilities are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets. Deferred fuel and power - costs and refunds. Utilities’ tariffs contain clauses that permit recovery of all prudently incurred purchased gas and power costs through the application of PGC rates and DS tariffs. 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. PA Gas Utility uses derivative instruments to reduce volatility in the cost of gas it purchases for retail core-market customers. Realized and unrealized gains or losses on natural gas derivative instruments are included in deferred fuel and power costs or refunds. Net unrealized gains on such contracts at June 30, 2022, September 30, 2021 and June 30, 2021 were $7, $35 and $9, respectively. Other Regulatory Matters Base Rate Filings . On January 28, 2022, PA Gas Utility filed a request with the PAPUC to increase its base operating revenues for residential, commercial and industrial customers by $83 annually. The increased revenues would fund ongoing system improvements and operations necessary to maintain safe and reliable natural gas service and continue to fund programs designed to promote and reward customers’ efforts to increase efficient use of natural gas. On June 24, 2022, a Joint Petition for Approval of Settlement of all issues supported by all active parties was filed with the PAPUC providing for a $49 annual base distribution rate increase for PA Gas Utility, through a phased approach, with $38 beginning October 29, 2022 and an additional $11 beginning October 1, 2023. In accordance with the terms of the Joint Petition, PA Gas Utility will not be permitted to file a rate case prior to January 1, 2024. Also, in accordance with the terms of the Joint Petition, PA Gas Utility is authorized to implement a weather normalization adjustment rider as a 5-year pilot program beginning on the effective date of the new rates. Under this rider, customer billings for distribution services will be adjusted to reflect normal weather conditions if weather deviates more than 3% from normal. Additionally, under the terms of the Joint Petition, PA Gas Utility will be authorized to implement a DSIC once its total property, plant and equipment less accumulated depreciation reaches $3,368. The Joint Petition was approved by a PAPUC administrative law judge on July 28, 2022, and is further subject to receipt of an order from the PAPUC approving the settlement. The Company cannot predict the timing or the ultimate outcome of the rate case review process. On February 8, 2021, Electric Utility filed a rate request with the PAPUC to increase its annual base distribution revenues by $9. On October 28, 2021, the PAPUC issued a final order approving a settlement that permitted Electric Utility, effective November 9, 2021, to increase its base distribution revenues by $6. On January 28, 2020, PA 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 settlement that permitted PA Gas Utility 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, PA Gas Utility was authorized to implement a DSIC once PA Gas Utility total property, plant and equipment less accumulated depreciation reached $2,875. This threshold was achieved in December 2020, and PA Gas Utility implemented a DSIC effective April 1, 2021. The PAPUC’s final Order also included 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 PAPUC’s final order permitted PA 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 PA Gas Utility base rate case, to be recovered and amortized over a 10-year period. In accordance with the terms of the final Order, PA Gas Utility was not permitted to file a rate case prior to January 1, 2022.

Debt

Debt	9 Months Ended
	Jun. 30, 2022
Debt Disclosure [Abstract]
Debt	Note 8 — Debt UGI Utilities . On July 12, 2022, UGI Utilities amended the existing Utilities Term Loan. The amendment extended the maturity date of the loan from October 2022 to July 2027, among other things. The current amount outstanding under the Utilities Term Loan remains unchanged and is payable in quarterly installments of $2, with the balance of the principal being due and payable at maturity. We have entered into a forward-starting interest rate swap that will generally fix the underlying market-based interest rate on this variable-rate loan through June 2026. On June 30, 2022, UGI Utilities entered into a note purchase agreement which provides for the private placement of (1) $90 aggregate principal amount of 4.75% Senior Notes due July 15, 2032 and (2) $85 aggregate principal amount of 4.99% Senior Notes due September 15, 2052. On July 15, 2022, UGI Utilities issued $90 aggregate principal amount of 4.75% Senior Notes pursuant to the note purchase agreement. The net proceeds from the issuance of the 4.75% Senior Notes were used to reduce short-term borrowings and for general corporate purposes. The 4.99% Senior Notes are expected to be issued on or before September 15, 2022. These Senior Notes are unsecured and will rank equally with UGI Utilities’ existing outstanding senior debt. UGI Utilities expects to use the net proceeds from the issuance of the 4.99% Senior Notes to reduce short-term borrowings and for general corporate purposes. Mountaineer. On June 30, 2022, Mountaineer entered into a note purchase agreement which provides for the private placement of $40 aggregate principal amount of 4.49% Senior Notes due August 16, 2052. The 4.49% Senior Notes are expected to be issued on or before August 16, 2022. These Senior Notes are unsecured and will rank equally with Mountaineer’s existing outstanding senior debt. Mountaineer expects to use the net proceeds from the issuance of the 4.49% Senior Notes to reduce short-term borrowings and for general corporate purposes . UGI International. On December 7, 2021, UGI International, LLC issued, in an underwritten private placement, €400 principal amount of the UGI International 2.50% Senior Notes due December 1, 2029. The UGI International 2.50% Senior Notes rank equal in right of payment with indebtedness issued under the UGI International Credit Facilities Agreement. The net proceeds from the UGI International 2.50% Senior Notes were used (1) to repay all of the UGI International 3.25% Senior Notes due November 1, 2025 and associated fees and expenses and (2) for general corporate purposes. We have designated the UGI International 2.50% Senior Notes as a net investment hedge. In connection with this early repayment of debt, UGI International recognized a pre-tax loss of $11, which is reflected in “Loss on extinguishment of debt” on the Condensed Consolidated Statements of Income, and primarily comprises the write-off of unamortized debt issuance costs and early redemption premiums.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Jun. 30, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 9 — Commitments and Contingencies Environmental Matters UGI Utilities From the late 1800s through the mid-1900s, UGI Utilities and its former subsidiaries owned and operated a number of MGPs prior to the general availability of natural gas. Some constituents of coal tars and other residues of the manufactured gas process are today considered hazardous substances under the Superfund Law and may be present on the sites of former MGPs. Between 1882 and 1953, UGI Utilities owned the stock of subsidiary gas companies in Pennsylvania and elsewhere and also operated the businesses of some gas companies under agreement. By the early 1950s, UGI Utilities divested all of its utility operations other than certain gas and electric operations. Beginning in 2006 and 2008, UGI Utilities also owned and operated two acquired subsidiaries, with similar histories of owning, and in some cases operating, MGPs in Pennsylvania. UGI Utilities is subject to a COA with the PADEP to address the remediation of specified former MGP sites in Pennsylvania, which is scheduled to terminate at the end of 2031. In accordance with the COA, UGI Utilities is required to either obtain a certain number of points per calendar year based on defined eligible environmental investigatory and/or remedial activities at the MGPs, or make expenditures for such activities in an amount equal to an annual environmental minimum expenditure threshold. The annual minimum expenditure threshold of the COA is $5. The COA permits the transfer of the specified wells, with related costs counted towards the annual minimum expenditure. At June 30, 2022, September 30, 2021 and June 30, 2021, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the current COA and the predecessor agreements totaled $51, $50 and $49, respectively. We do not expect the costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to UGI Utilities’ results of operations because UGI Utilities receives ratemaking recovery of actual environmental investigation and remediation costs associated with the sites covered by the COA. This ratemaking recognition reconciles the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. As such, UGI Utilities has recorded an associated regulatory asset for these costs because recovery of these costs from customers is probable (see Note 7). From time to time, UGI Utilities is notified of sites outside Pennsylvania on which private parties allege MGPs were formerly owned or operated by UGI Utilities or owned or operated by a former subsidiary. Such parties generally investigate the extent of environmental contamination or perform environmental remediation. Management believes that under applicable law, UGI Utilities should not be liable in those instances in which a former subsidiary owned or operated an MGP. There could be, however, significant future costs of an uncertain amount associated with environmental damage caused by MGPs outside Pennsylvania that UGI Utilities directly operated, or that were owned or operated by a former subsidiary of UGI Utilities if a court were to conclude that (1) the subsidiary’s separate corporate form should be disregarded, or (2) UGI Utilities should be considered to have been an operator because of its conduct with respect to its subsidiary’s MGP. Neither the undiscounted nor the accrued liability for environmental investigation and cleanup costs for UGI Utilities’ MGP sites outside Pennsylvania were material for all periods presented. AmeriGas Propane AmeriGas OLP Saranac Lake. In 2008, the NYDEC notified AmeriGas OLP that the NYDEC had placed property purportedly owned by AmeriGas OLP in Saranac Lake, New York on the New York State Registry of Inactive Hazardous Waste Disposal Sites. A site characterization study performed by the NYDEC disclosed contamination related to a former MGP. AmeriGas OLP responded to the NYDEC in 2009 to dispute the contention it was a PRP as it did not operate the MGP and appeared to only own a portion of the site. In 2017, the NYDEC communicated to AmeriGas OLP that the NYDEC had previously issued three RODs related to remediation of the site totaling approximately $28 and requested additional information regarding AmeriGas OLP’s purported ownership. AmeriGas OLP renewed its challenge to designation as a PRP and identified potential defenses. The NYDEC subsequently identified a third party PRP with respect to the site. The NYDEC commenced implementation of the remediation plan in the spring of 2018. Based on our evaluation of the available information as of June 30, 2022, the Partnership has an undiscounted environmental remediation liability of $8 related to the site. Our share of the actual remediation costs could be significantly more or less than the accrued amount. 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.

Defined Benefit Pension and Oth

Defined Benefit Pension and Other Postretirement Plans	9 Months Ended
	Jun. 30, 2022
Retirement Benefits [Abstract]
Defined Benefit Pension and Other Postretirement Plans	Note 10 — Defined Benefit Pension and Other Postretirement Plans The Company maintains defined benefit plans and other postretirement plans for certain current and former employees. The service cost component of our pension and other postretirement plans, net of amounts capitalized, is reflected in “Operating and administrative expenses” on the Condensed Consolidated Statements of Income. The non-service cost component, net of amounts capitalized by Utilities as a regulatory asset, is reflected in “Other non-operating income, net” on the Condensed Consolidated Statements of Income. Other postretirement benefit cost was not material for all periods presented. Net periodic pension cost includes the following components: Three Months Ended June 30, 2022 2021 Service cost $ 4 $ 3 Interest cost 6 5 Expected return on assets (12) (10) Amortization of: Actuarial loss 2 4 Net cost $ — $ 2 Nine Months Ended June 30, 2022 2021 Service cost $ 12 $ 9 Interest cost 19 16 Expected return on assets (37) (30) Amortization of: Actuarial loss 6 11 Net cost $ — $ 6

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Jun. 30, 2022
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 11 — Fair Value Measurements Recurring Fair Value Measurements The following table presents, on a gross basis, our financial assets and liabilities, including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy: Asset (Liability) Level 1 Level 2 Level 3 Total June 30, 2022: Derivative instruments: Assets: Commodity contracts $ 816 $ 1,149 $ — $ 1,965 Foreign currency contracts $ — $ 59 $ — $ 59 Interest rate contracts $ — $ 44 $ — $ 44 Liabilities: Commodity contracts $ (324) $ (37) $ — $ (361) Foreign currency contracts $ — $ (2) $ — $ (2) Non-qualified supplemental postretirement grantor trust investments (a) $ 46 $ — $ — $ 46 September 30, 2021: Derivative instruments: Assets: Commodity contracts $ 641 $ 1,008 $ — $ 1,649 Foreign currency contracts $ — $ 38 $ — $ 38 Liabilities: Commodity contracts $ (264) $ (16) $ — $ (280) Foreign currency contracts $ — $ (8) $ — $ (8) Interest rate contracts $ — $ (29) $ — $ (29) Non-qualified supplemental postretirement grantor trust investments (a) $ 53 $ — $ — $ 53 June 30, 2021: Derivative instruments: Assets: Commodity contracts $ 241 $ 396 $ — $ 637 Foreign currency contracts $ — $ 24 $ — $ 24 Liabilities: Commodity contracts $ (136) $ (9) $ — $ (145) Foreign currency contracts $ — $ (13) $ — $ (13) Interest rate contracts $ — $ (35) $ — $ (35) Non-qualified supplemental postretirement grantor trust investments (a) $ 42 $ — $ — $ 42 (a) Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans. 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: June 30, 2022 September 30, 2021 June 30, 2021 Carrying amount $ 6,483 $ 6,491 $ 5,890 Estimated fair value $ 6,145 $ 6,996 $ 6,314

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	9 Months Ended
	Jun. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Note 12 — Derivative Instruments and Hedging Activities We are exposed to certain market risks related to our ongoing business operations. Management uses derivative financial and commodity instruments, among other things, to manage: (1) commodity price risk; (2) interest rate risk; and (3) foreign currency exchange rate risk. Although we use derivative financial and commodity instruments to reduce market risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes. The use of derivative instruments is controlled by our risk management and credit policies, which govern, among other things, the derivative instruments we can use, counterparty credit limits and contract authorization limits. Although our commodity derivative instruments extend over a number of years, a significant portion of our commodity derivative instruments economically hedge commodity price risk during the next twelve months. For information on the accounting for our derivative instruments, see Note 2. The following summarizes the types of derivative instruments used by the Company to manage certain market risks: Commodity Price Risk Regulated Utility Operations Natural Gas UGI Utilities’ tariffs contain clauses that permit recovery of all prudently incurred costs of natural gas it sells to retail core-market customers, including the cost of financial instruments used to hedge purchased gas costs. As permitted and agreed to by the PAPUC pursuant to PA Gas Utility’s annual PGC filings, PA Gas Utility currently uses NYMEX natural gas futures and option contracts to reduce commodity price volatility associated with a portion of the natural gas it purchases for its retail core-market customers. See Note 7 for further information on the regulatory accounting treatment for these derivative instruments. Non-utility Operations LPG In order to manage market price risk associated with the Partnership’s fixed-price programs and to reduce the effects of short-term commodity price volatility, the Partnership uses over-the-counter derivative commodity instruments, principally price swap contracts. In addition, the Partnership and our UGI International operations also use over-the-counter price swap and option contracts to reduce commodity price volatility associated with a portion of their forecasted LPG purchases. Natural Gas In order to manage market price risk relating to fixed-price sales contracts for physical natural gas, Midstream & Marketing enters into NYMEX and over-the-counter natural gas futures and over-the-counter and ICE natural gas basis swap contracts. In addition, Midstream & Marketing uses NYMEX and over-the-counter futures and options contracts to economically hedge price volatility associated with the gross margin derived from the purchase and anticipated later near-term sale of natural gas storage inventories. Outside of the financial market, Midstream & Marketing also uses ICE and over-the-counter forward physical contracts. UGI International also uses natural gas futures and forward contracts to economically hedge market price risk associated with a substantial portion of anticipated volumes under fixed-price sales contracts with its customers. 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 June 30, 2022, the amount of pre-tax net losses associated with interest rate hedges (excluding pay-fixed, receive-variable interest rate swaps) expected to be reclassified into earnings during the next twelve months is $3. Foreign Currency Exchange Rate Risk Forward Foreign Currency Exchange Contracts In order to reduce the volatility in net income associated with our foreign operations, principally as a result of changes in the USD exchange rate to the euro and British pound sterling, we enter into forward foreign currency exchange contracts. We layer in these foreign currency exchange contracts over a multi-year period to eventually equal approximately 90% of anticipated UGI International foreign currency earnings before income taxes. Because these contracts are not designated as hedging instruments, realized and unrealized gains and losses on these contracts are recorded in “Other non-operating income, net,” on the Condensed Consolidated Statements of Income. Net Investment Hedges From time to time, we also enter into certain forward foreign currency exchange contracts to reduce the volatility of the USD value of a portion of our UGI International euro-denominated net investments, including anticipated foreign currency denominated dividends. We account for these foreign currency exchange contracts as net investment hedges and all changes in the fair value of these contracts are reported in the cumulative translation adjustment component in AOCI. We use the spot rate method to measure ineffectiveness of our net investment hedges. Concurrent with the repayment of UGI International’s 3.25% Senior Notes on December 7, 2021, we settled an associated net investment hedge having a notional value of €93. Additionally, in May 2022, we restructured certain net investment hedges associated with anticipated foreign currency denominated dividends. Cash flows from these settlements are included in cash flows from investing activities on the Condensed Consolidated Statements of Cash Flows. Our euro-denominated long-term debt has also been designated as net investment hedges, representing a portion of our UGI International euro-denominated net investment. We recognized pre-tax gains (losses) associated with these net investment hedges in the cumulative translation adjustment component in AOCI of $41 and $(8) during the three months ended June 30, 2022 and 2021, respectively, $75 and $(9) during the nine months ended June 30, 2022 and 2021, respectively. Quantitative Disclosures Related to Derivative Instruments The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at June 30, 2022, September 30, 2021 and June 30, 2021, and the final settlement dates of the Company's open derivative contracts as of June 30, 2022, excluding those derivatives that qualified for the NPNS exception: Notional Amounts Type Units Settlements Extending Through June 30, 2022 September 30, 2021 June 30, 2021 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms October 2023 13 20 12 Non-utility Operations LPG swaps Gallons September 2024 669 708 688 Natural gas futures, forward, basis swap, options and pipeline contracts Dekatherms June 2026 353 355 344 Electricity forward and futures contracts Kilowatt hours November 2026 2,621 4,302 4,730 Interest Rate Risk: Interest rate swaps Euro October 2022 € 300 € 300 € 300 Interest rate swaps USD September 2024 $ 1,411 $ 1,421 $ 1,424 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD August 2025 $ 435 $ 509 $ 504 Net investment hedge forward foreign exchange contracts Euro December 2026 € 411 € 173 € 173 Derivative Instrument Credit Risk We are exposed to risk of loss in the event of nonperformance by our derivative instrument counterparties. Our derivative instrument counterparties principally comprise large energy companies and major U.S. and international financial institutions. We maintain credit policies with regard to our counterparties that we believe reduce overall credit risk. These policies include evaluating and monitoring our counterparties’ financial condition, including their credit ratings, and entering into agreements with counterparties that govern credit limits or entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. We have concentrations of credit risk associated with derivative instruments and we evaluate the creditworthiness of our derivative counterparties on an ongoing basis. As of June 30, 2022, the maximum amount of loss, based upon the gross fair values of the derivative instruments, we would incur if these counterparties failed to perform according to the terms of their contracts was $2,068. In general, many of our over-the-counter derivative instruments and all exchange contracts call for the posting of collateral by the counterparty or by the Company in the forms of letters of credit, parental guarantees or cash. At June 30, 2022, we had received cash collateral from derivative instrument counterparties totaling $659. In addition, we may have offsetting derivative liabilities and certain accounts payable balances with certain of these counterparties, which further mitigates the previously mentioned maximum amount of losses. Certain of the Partnership’s derivative contracts have credit-risk-related contingent features that may require the posting of additional collateral in the event of a downgrade of the Partnership’s debt rating. At June 30, 2022, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material. Offsetting Derivative Assets and Liabilities Derivative assets and liabilities are presented net by counterparty on the Condensed Consolidated Balance Sheets if the right of offset exists. We offset amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against amounts recognized for derivative instruments executed with the same counterparty. Our derivative instruments include both those that are executed on an exchange through brokers and centrally cleared and over-the-counter transactions. Exchange contracts utilize a financial intermediary, exchange or clearinghouse to enter, execute or clear the transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Certain over-the-counter and exchange contracts contain contractual rights of offset through master netting arrangements, derivative clearing agreements and contract default provisions. In addition, the contracts are subject to conditional rights of offset through counterparty nonperformance, insolvency or other conditions. In general, many of our over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral generally include cash or letters of credit. Cash collateral paid by us to our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative liabilities. Cash collateral received by us from our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative assets. Certain other accounts receivable and accounts payable balances recognized on the Condensed Consolidated Balance Sheets with our derivative counterparties are not included in the table below but could reduce our net exposure to such counterparties because such balances are subject to master netting or similar arrangements. Fair Value of Derivative Instruments The following table presents the Company’s derivative assets and liabilities by type, as well as the effects of offsetting: June 30, September 30, June 30, Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 28 $ 20 $ 15 Interest rate contracts 44 — — 72 20 15 Derivatives subject to PGC and DS mechanisms: Commodity contracts 30 58 14 Derivatives not designated as hedging instruments: Commodity contracts 1,935 1,591 623 Foreign currency contracts 31 18 9 1,966 1,609 632 Total derivative assets — gross 2,068 1,687 661 Gross amounts offset in the balance sheet (226) (216) (77) Cash collateral received (659) (468) (105) Total derivative assets — net $ 1,183 $ 1,003 $ 479 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts $ — $ (29) $ (35) Derivatives subject to PGC and DS mechanisms: Commodity contracts (23) (23) (6) Derivatives not designated as hedging instruments: Commodity contracts (338) (257) (139) Foreign currency contracts (2) (8) (13) (340) (265) (152) Total derivative liabilities — gross (363) (317) (193) Gross amounts offset in the balance sheet 226 216 77 Cash collateral pledged 13 3 — Total derivative liabilities — net $ (124) $ (98) $ (116) Effects of Derivative Instruments The following tables provide information on the effects of derivative instruments on the Condensed Consolidated Statements of Income and changes in AOCI: Three Months Ended June 30,: Gain (Loss) Loss Location of Loss Reclassified from Cash Flow Hedges: 2022 2021 2022 2021 Interest rate contracts $ 11 $ (1) $ (4) $ (6) Interest expense Net Investment Hedges: Foreign currency contracts $ 23 $ (1) Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2022 2021 Location of Gain (Loss) Recognized in Income Commodity contracts $ (6) $ (5) Revenues Commodity contracts 466 347 Cost of sales Commodity contracts 6 — Other operating income, net Foreign currency contracts 17 (1) Other non-operating income, net Total $ 483 $ 341 Nine Months Ended June 30,: Gain (Loss) Loss Location of Loss Reclassified from Cash Flow Hedges: 2022 2021 2022 2021 Interest rate contracts $ 59 $ 5 $ (17) $ (19) Interest expense Net Investment Hedges: Foreign currency contracts $ 34 $ (2) Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2022 2021 Location of Gain (Loss) Recognized in Income Commodity contracts $ (5) $ (4) Revenues Commodity contracts 792 585 Cost of sales Commodity contracts 6 5 Other operating income, net Foreign currency contracts 32 (4) Other non-operating income, net Total $ 825 $ 582 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)	9 Months Ended
	Jun. 30, 2022
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	Note 13 — Accumulated Other Comprehensive Income (Loss) The tables below present changes in AOCI, net of tax: Three Months Ended June 30, 2022 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — March 31, 2022 $ (14) $ 11 $ (175) $ (178) Other comprehensive income (loss) before reclassification adjustments — 8 (106) (98) Amounts reclassified from AOCI — 3 — 3 Other comprehensive income (loss) attributable to UGI — 11 (106) (95) AOCI — June 30, 2022 $ (14) $ 22 $ (281) $ (273) Three Months Ended June 30, 2021 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — March 31, 2021 $ (25) $ (41) $ (60) $ (126) Other comprehensive income before reclassification adjustments — — 16 16 Amounts reclassified from AOCI — 5 — 5 Other comprehensive income attributable to UGI — 5 16 21 AOCI — June 30, 2021 $ (25) $ (36) $ (44) $ (105) Nine Months Ended June 30, 2022 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2021 $ (17) $ (33) $ (90) $ (140) Other comprehensive income (loss) before reclassification adjustments — 42 (191) (149) Amounts reclassified from AOCI 3 13 — 16 Other comprehensive income (loss) attributable to UGI 3 55 (191) (133) AOCI — June 30, 2022 $ (14) $ 22 $ (281) $ (273) Nine Months Ended June 30, 2021 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2020 $ (26) $ (54) $ (67) $ (147) Other comprehensive income before reclassification adjustments — 4 23 27 Amounts reclassified from AOCI 1 14 — 15 Other comprehensive income attributable to UGI 1 18 23 42 AOCI — June 30, 2021 $ (25) $ (36) $ (44) $ (105)

Segment Information

Segment Information	9 Months Ended
	Jun. 30, 2022
Segment Reporting [Abstract]
Segment Information	Note 14 — Segment Information Our operations comprise four reportable segments generally based upon products or services sold, geographic location and regulatory environment: (1) AmeriGas Propane; (2) UGI International; (3) Midstream & Marketing; and (4) Utilities. Corporate & Other includes certain items that are excluded from our CODM’s assessment of segment performance (see below for further details on these items). Corporate & Other also includes the net expenses of UGI’s captive general liability insurance company, UGI’s corporate headquarters facility and UGI’s unallocated corporate and general expenses as well as interest expense on UGI debt that is not allocated. Corporate & Other assets principally comprise cash and cash equivalents of UGI and its captive insurance company, and UGI corporate headquarters’ assets. The accounting policies of our reportable segments are the same as those described in Note 2, “Summary of Significant Accounting Policies,” in the Company’s 2021 Annual Report. Three Months Ended June 30, 2022 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 2,033 $ — $ 597 $ 738 $ 450 $ 250 $ (2) Intersegment revenues $ — $ (99) (b) $ — $ — $ 75 $ 24 $ — Cost of sales $ 1,361 $ (99) (b) $ 370 $ 544 $ 436 $ 121 $ (11) Operating income (loss) $ 99 $ — $ (10) $ 22 $ 38 $ 38 $ 11 (Loss) income from equity investees (45) — — — 6 — (51) Other non-operating income, net 20 — — 4 — 2 14 Earnings (loss) before interest expense and income taxes 74 — (10) 26 44 40 (26) Interest expense (82) — (41) (7) (11) (15) (8) (Loss) income before income taxes $ (8) $ — $ (51) $ 19 $ 33 $ 25 $ (34) Depreciation and amortization $ 130 $ — $ 44 $ 29 $ 20 $ 37 $ — Capital expenditures (including the effects of accruals) $ 201 $ — $ 28 $ 25 $ 9 $ 139 $ — Three Months Ended June 30, 2021 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 1,496 $ — $ 526 $ 572 $ 232 $ 171 $ (5) Intersegment revenues $ — $ (40) (b) $ — $ — $ 29 $ 10 $ 1 Cost of sales $ 516 $ (39) (b) $ 267 $ 355 $ 196 $ 67 $ (330) Operating income $ 391 $ — $ 11 $ 40 $ 14 $ 24 $ 302 (Loss) income from equity investees (86) — — — 7 — (93) Other non-operating income (expense), net 1 — — 1 — 1 (1) Earnings before interest expense and income taxes 306 — 11 41 21 25 208 Interest expense (77) — (40) (8) (10) (14) (5) Income (loss) before income taxes $ 229 $ — $ (29) $ 33 $ 11 $ 11 $ 203 Depreciation and amortization $ 125 $ — $ 43 $ 33 $ 19 $ 29 $ 1 Capital expenditures (including the effects of accruals) $ 162 $ — $ 26 $ 21 $ 3 $ 112 $ — Nine Months Ended June 30, 2022 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 8,172 $ — $ 2,423 $ 3,011 $ 1,424 $ 1,313 $ 1 Intersegment revenues $ — $ (396) (b) $ — $ — $ 307 $ 87 $ 2 Cost of sales $ 4,951 $ (394) (b) $ 1,333 $ 2,267 $ 1,389 $ 701 $ (345) Operating income $ 1,363 $ — $ 303 $ 211 $ 197 $ 325 $ 327 (Loss) income from equity investees (32) — — — 19 — (51) Loss on extinguishments of debt (11) — — — — — (11) Other non-operating income, net 41 — — 17 — 7 17 Earnings before interest expense and income taxes 1,361 — 303 228 216 332 282 Interest expense (245) — (120) (22) (31) (47) (25) Income before income taxes $ 1,116 $ — $ 183 $ 206 $ 185 $ 285 $ 257 Depreciation and amortization $ 387 $ — $ 132 $ 89 $ 57 $ 108 $ 1 Capital expenditures (including the effects of accruals) $ 546 $ — $ 99 $ 71 $ 25 $ 351 $ — As of June 30, 2022 Total assets $ 17,111 $ (182) $ 4,365 $ 4,410 $ 3,198 $ 5,146 $ 174 Nine Months Ended June 30, 2021 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 6,009 $ — $ 2,132 $ 2,106 $ 903 $ 873 $ (5) Intersegment revenues $ — $ (236) (b) $ — $ — $ 183 $ 50 $ 3 Cost of sales $ 2,623 $ (233) (b) $ 970 $ 1,229 $ 776 $ 401 $ (520) Operating income $ 1,564 $ — $ 391 $ 322 $ 156 $ 243 $ 452 (Loss) income from equity investees (69) — — — 24 — (93) Other non-operating income (expense), net — — — 4 — 2 (6) Earnings before interest expense and income taxes 1,495 — 391 326 180 245 353 Interest expense (233) — (120) (21) (31) (42) (19) Income before income taxes $ 1,262 $ — $ 271 $ 305 $ 149 $ 203 $ 334 Depreciation and amortization $ 375 $ — $ 130 $ 100 $ 56 $ 87 $ 2 Capital expenditures (including the effects of accruals) $ 438 $ — $ 83 $ 68 $ 32 $ 255 $ — As of June 30, 2021 Total assets $ 15,006 $ (267) $ 4,381 $ 3,749 $ 2,904 $ 3,997 $ 242 (a) Corporate & Other includes specific items attributable to our reportable segments that are not included in the segment profit measures used by our CODM in assessing our reportable segments’ performance or allocating resources. The following table presents such pre-tax gains (losses) which have been included in Corporate & Other, and the reportable segments to which they relate: Three Months Ended June 30, 2022 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains (losses) on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 2 $ (4) Net (losses) gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ (46) $ 110 $ (51) Net gains on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ 6 $ — Restructuring costs Operating and administrative expenses $ (1) $ (2) $ (1) Unrealized gains on foreign currency derivative instruments Other non-operating income, net $ — $ 14 $ — Impairments associated with certain equity method investments Loss from equity investees $ — $ — $ (50) Three Months Ended June 30, 2021 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (4) Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 59 $ 226 $ 44 Unrealized losses on foreign currency derivative instruments Other non-operating income, net $ — $ (1) $ — Business transformation expenses Operating and administrative expenses $ (11) $ (6) $ — Impairments associated with certain equity method investments Loss from equity investees $ — $ — $ (93) Nine Months Ended June 30, 2022 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains (losses) on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 7 $ (6) Net (losses) gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ (83) $ 458 $ (29) Net gains on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ 6 $ — Restructuring costs Operating and administrative expenses $ (15) $ (4) $ (1) Loss on extinguishment of debt Loss on extinguishment of debt $ — $ (11) $ — Unrealized gains on foreign currency derivative instruments Other non-operating income, net $ — $ 19 $ — Impairments associated with certain equity method investments Loss from equity investees $ — $ — $ (50) Nine Months Ended June 30, 2021 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (4) Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 123 $ 380 $ 16 Unrealized losses on foreign currency derivative instruments Other non-operating income, net $ — $ (6) $ — Business transformation expenses Operating and administrative expenses $ (37) $ (12) $ — Impairments associated with certain equity method investments Loss from equity investees $ — $ — $ (93) (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, Utilities and AmeriGas Propane.

Business Transformation Initiat

Business Transformation Initiatives	9 Months Ended
	Jun. 30, 2022
Restructuring and Related Activities [Abstract]
Business Transformation Initiatives	Note 15 — Business Transformation Initiatives AmeriGas and UGI International. Beginning in Fiscal 2019, we began executing on multi-year business transformation initiatives at our AmeriGas Propane and UGI International business segments. These initiatives are designed to improve long-term operational performance by, among other things, reducing costs and improving efficiency in the areas of sales and marketing, supply and logistics, operations, purchasing, and administration. In addition, these business transformation initiatives focus on enhancing the customer experience through, among other things, enhanced customer relationship management and an improved digital customer experience. During the three and nine months ended June 30, 2021, we incurred $17 and $49 of costs, respectively, principally comprising consulting, advisory, marketing and employee-related costs. These costs are primarily reflected in “Operating and administrative expenses” on the Condensed Consolidated Statements of Income. These previously announced business transformation initiatives are substantially complete. Corporate Services. Beginning in Fiscal 2020, we initiated a transformation project focused on our support functions including: finance, procurement, human resources and information technology. This initiative will standardize processes and activities across our global platform, while leveraging the use of best practices and efficiencies between our businesses. In connection with this initiative, we recognized expenses of $2 and $4 during the three months ended June 30, 2022 and 2021, respectively, and $6 and $8 during the nine months ended June 30, 2022 and 2021, respectively. Amounts in connection with this initiative are reflected in “Operating and administrative expenses” on the Condensed Consolidated Statement of Income.

Impairments Associated with Cer

Impairments Associated with Certain Equity Method Investments	9 Months Ended
	Jun. 30, 2022
Equity Method Investments and Joint Ventures [Abstract]
Impairments Associated with Certain Equity Method Investments	Note 16 — Impairments Associated with Certain Equity Method Investments Pennant. Energy Services holds a 47% membership interest in Pennant, a natural gas gathering system located in northeast Ohio and western Pennsylvan i a. In connection with ongoing negotiations related to the acquisition of a controlling financial interest in Pennant, as of June 30, 2022, the Compa ny recognized an other-than-temporary pre-tax impairment charge of $50 related to its current 47% membership interest, which was recorded in “Loss from equity investees” in the Condensed Consolidated Statements of Income. Subject to agency approvals and other customary closing conditions, the Company expects to acquire a controlling financial interest in Pennant in the fourth quarter of Fiscal 2022. PennEast. UGI PennEast, LLC holds a 20% membership interest in PennEast, a partnership formed to construct an approximate 120-mile natural gas pipeline from Luzerne County, Pennsylvania to the Trenton-Woodbury interconnection in New Jersey. Due to remaining legal and regulatory contingencies that existed as of June 30, 2021, the Company concluded that its investment in PennEast was impaired at that time. The Company recognized an other-than-temporary pre-tax impairment charge of $93 in June 2021, which was recorded in “Loss from equity investees” in the Condensed Consolidated Statements of Income. On September 27, 2021, PennEast ceased further development of the proposed pipeline project. The carrying values of our investment in PennEast at June 30, 2022, September 30, 2021, and June 30, 2021 were not material.

Impact of Global Pandemic

Impact of Global Pandemic	9 Months Ended
	Jun. 30, 2022
Unusual or Infrequent Items, or Both [Abstract]
Impact of Global Pandemic	Note 17 — 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 has 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 effects of a prolonged disruption and the potential of 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; commodity price volatility and supply chain constraints; and the effects of government stimulus efforts including tax legislation in response to COVID-19. The Company cannot predict the duration or magnitude of the pandemic and the total effects on its business, financial position, results of operations, liquidity or cash flows at this time.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Jun. 30, 2022
Accounting Policies [Abstract]
Restricted Cash	Restricted Cash.
Earnings Per Common Share	Earnings Per Common Share.
Derivative Instruments	Derivative Instruments. Derivative instruments are reported on the Condensed Consolidated Balance Sheets at their fair values, unless the NPNS exception is elected. The accounting for changes in fair value depends upon the purpose of the derivative instrument, whether it is subject to regulatory ratemaking mechanisms or if it qualifies and is designated as a hedge for accounting purposes. Certain of our derivative instruments qualify and are designated as cash flow hedges. For cash flow hedges, changes in the fair values of the derivative instruments are recorded in AOCI, to the extent effective at offsetting changes in the hedged item, until earnings are affected by the hedged item. We discontinue cash flow hedge accounting if occurrence of the forecasted transaction is determined to be no longer probable. Hedge accounting is also discontinued for derivatives that cease to be highly effective. We do not designate our commodity and certain foreign currency derivative instruments as hedges under GAAP. Changes in the fair values of these derivative instruments are reflected in net income. Gains and losses on substantially all of the commodity derivative instruments used by Utilities are included in regulatory assets or liabilities because it is probable such gains or losses will be recoverable from, or refundable to, customers. From time to time, we also enter into net investment hedges. Gains and losses on net investment hedges that relate to our foreign operations are included in the cumulative translation adjustment component in AOCI until such foreign net investment is substantially sold or liquidated. Cash flows from derivative instruments, other than certain cross-currency swaps and net investment hedges, if any, are included in cash flows from operating activities on the Condensed 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 Condensed Consolidated Statements of Cash Flows.
Use of Estimates	Use of Estimates. The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based
Reclassifications	Reclassifications. For purposes of comparability, certain prior-period amounts have been reclassified to conform to the current-period presentation. During the second quarter of Fiscal 2022, the Company reclassified certain amounts on the Consolidated Balance Sheet and Consolidated Statement of Changes in Equity related to the accounting for the Equity Units issued in May 2021.
New Accounting Standards Adopted in Fiscal 2022 And Accounting Standard Not Yet Adopted	New Accounting Standard Adopted in Fiscal 2022 Income Taxes. Effective October 1, 2021, the Company adopted ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes” prospectively and retrospectively where deemed applicable. This ASU simplifies the accounting for income taxes by eliminating certain exceptions within the existing guidance for recognizing deferred taxes for equity method investments, performing intraperiod allocations and calculating income taxes in interim periods. Further, this ASU clarifies existing guidance related to, among other things, recognizing deferred taxes for goodwill and allocated taxes to members of a consolidated group. The adoption of the new guidance did not have a material impact on our consolidated financial statements. Accounting Standard Not Yet Adopted Debt and Derivatives and Hedging. In August 2020, the FASB issued ASU 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40).” The amendments in this ASU affect entities that issue convertible instruments and/or contracts indexed to and potentially settled in an entity’s own equity. This ASU reduces the number of accounting models for convertible debt instruments and convertible preferred stock, expands disclosure requirements for convertible instruments, and simplifies the related earnings per share guidance. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2022 (Fiscal 2023). Early adoption is permitted. The amendments in this ASU may be adopted using the modified or full retrospective transition methods. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the transition method and the period in which the new guidance will be adopted.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Jun. 30, 2022
Accounting Policies [Abstract]
Restrictions on Cash and Cash Equivalents	The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Condensed Consolidated Balance Sheets to the corresponding amounts reported on the Condensed Consolidated Statements of Cash Flows. June 30, June 30, Cash and cash equivalents $ 670 $ 545 Restricted cash 14 31 Cash, cash equivalents and restricted cash $ 684 $ 576
Schedule of Cash and Cash Equivalents	The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Condensed Consolidated Balance Sheets to the corresponding amounts reported on the Condensed Consolidated Statements of Cash Flows. June 30, June 30, Cash and cash equivalents $ 670 $ 545 Restricted cash 14 31 Cash, cash equivalents and restricted cash $ 684 $ 576
Shares Used in Computing Basic and Diluted Earnings Per Share	Shares used in computing basic and diluted earnings per share are as follows: Three Months Ended Nine Months Ended 2022 2021 2022 2021 Denominator (thousands of shares): Weighted-average common shares outstanding — basic 210,190 209,099 209,992 208,934 Incremental shares issuable for stock options, common stock awards and Equity Units (a) — 1,752 5,973 1,260 Weighted-average common shares outstanding — diluted 210,190 210,851 215,965 210,194 (a) For the three months ended June 30, 2022, 5,668 of such shares have been excluded as these incremental shares would be antidilutive due to the net loss for the period. At June 30, 2022 and 2021, there were 5,718 and 2,502 shares, respectively, associated with outstanding stock option awards that were not included in the computation of diluted earnings per share above because their effect was antidilutive.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	9 Months Ended
	Jun. 30, 2022
Revenue from Contract with Customer [Abstract]
Disaggregated Revenues by Reportable Segment	The following tables present our disaggregated revenues by reportable segment: Three Months Ended June 30, 2022 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 140 $ — $ — $ — $ — $ 140 $ — Commercial & Industrial 57 — — — — 57 — Large delivery service 38 — — — — 38 — Off-system sales and capacity releases 9 (24) — — — 33 — Other 5 — — — — 5 — Total Utility 249 (24) — — — 273 — Non-Utility: LPG: Retail 880 — 478 402 — — — Wholesale 107 — 48 59 — — — Energy Marketing 631 (70) — 246 455 — — Midstream: Pipeline 53 — — — 53 — — Peaking 9 (5) — — 14 — — Other 2 — — — 2 — — Electricity Generation 1 — — — 1 — — Other 72 — 51 21 — — — Total Non-Utility 1,755 (75) 577 728 525 — — Total revenues from contracts with customers 2,004 (99) 577 728 525 273 — Other revenues (b) 29 — 20 10 — 1 (2) Total revenues $ 2,033 $ (99) $ 597 $ 738 $ 525 $ 274 $ (2) Three Months Ended June 30, 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 90 $ — $ — $ — $ — $ 90 $ — Commercial & Industrial 34 — — — — 34 — Large delivery service 33 — — — — 33 — Off-system sales and capacity releases 6 (10) — — — 16 — Other 5 — — — — 5 — Total Utility 168 (10) — — — 178 — Non-Utility: LPG: Retail 800 — 424 376 — — — Wholesale 77 — 35 42 — — — Energy Marketing 311 (24) — 129 206 — — Midstream: Pipeline 45 — — — 45 — — Peaking 1 (5) — — 6 — — Other 2 — — — 2 — — Electricity Generation 1 — — — 1 — — Other 69 — 51 18 — — — Total Non-Utility 1,306 (29) 510 565 260 — — Total revenues from contracts with customers 1,474 (39) 510 565 260 178 — Other revenues (b) 22 (1) 16 7 1 3 (4) Total revenues $ 1,496 $ (40) $ 526 $ 572 $ 261 $ 181 $ (4) Nine Months Ended June 30, 2022 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 774 $ — $ — $ — $ — $ 774 $ — Commercial & Industrial 318 — — — — 318 — Large delivery service 135 — — — — 135 — Off-system sales and capacity releases 65 (86) — — — 151 — Other 17 (1) — — — 18 — Total Utility 1,309 (87) — — — 1,396 — Non-Utility: LPG: Retail 3,684 — 2,032 1,652 — — — Wholesale 401 — 172 229 — — — Energy Marketing 2,254 (206) — 1,045 1,415 — — Midstream: Pipeline 149 — — — 149 — — Peaking 38 (101) — — 139 — — Other 6 — — — 6 — — Electricity Generation 20 — — — 20 — — Other 221 — 163 58 — — — Total Non-Utility 6,773 (307) 2,367 2,984 1,729 — — Total revenues from contracts with customers 8,082 (394) 2,367 2,984 1,729 1,396 — Other revenues (b) 90 (2) 56 27 2 4 3 Total revenues $ 8,172 $ (396) $ 2,423 $ 3,011 $ 1,731 $ 1,400 $ 3 Nine Months Ended June 30, 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 498 $ — $ — $ — $ — $ 498 $ — Commercial & Industrial 190 — — — — 190 — Large delivery service 117 — — — — 117 — Off-system sales and capacity releases 43 (49) — — — 92 — Other 16 (1) — — — 17 — Total Utility 864 (50) — — — 914 — Non-Utility: LPG: Retail 3,250 — 1,829 1,421 — — — Wholesale 235 — 92 143 — — — Energy Marketing 1,205 (89) — 470 824 — — Midstream: Pipeline 138 — — — 138 — — Peaking 12 (94) — — 106 — — Other 6 — — — 6 — — Electricity Generation 8 — — — 8 — — Other 211 — 161 50 — — — Total Non-Utility 5,065 (183) 2,082 2,084 1,082 — — Total revenues from contracts with customers 5,929 (233) 2,082 2,084 1,082 914 — Other revenues (b) 80 (3) 50 22 4 9 (2) Total revenues $ 6,009 $ (236) $ 2,132 $ 2,106 $ 1,086 $ 923 $ (2) (a) Includes intersegment revenues principally among Midstream & Marketing, Utilities and AmeriGas Propane. (b) Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, revenues from alternative revenue programs at UGI Utilities and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP.

Acquisitions (Tables)

Acquisitions (Tables)	9 Months Ended
	Jun. 30, 2022
Business Combination and Asset Acquisition [Abstract]
Summary of Components of Purchase Price Allocations	The components of the Mountaineer purchase price allocations are as follows: Assets acquired: Cash and cash equivalents $ 3 Accounts receivable 14 Inventories 41 Other current assets 21 Property, plant and equipment 397 Other noncurrent assets 48 Total assets acquired $ 524 Liabilities assumed: Short-term borrowings $ 55 Accounts payable 20 Other current liabilities 52 Long-term debt 164 Pension and other postretirement benefit obligation 33 Deferred income taxes 21 Other noncurrent liabilities 29 Total liabilities assumed $ 374 Goodwill 250 Net consideration transferred $ 400

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Jun. 30, 2022
Inventory Disclosure [Abstract]
Components of Inventories	Inventories comprise the following: June 30, September 30, June 30, Non-utility LPG and natural gas $ 261 $ 278 $ 187 Gas Utility natural gas 84 68 16 Energy certificates 70 53 42 Materials, supplies and other 81 70 51 Total inventories $ 496 $ 469 $ 296

Utility Regulatory Assets and_2

Utility Regulatory Assets and Liabilities and Regulatory Matters (Tables)	9 Months Ended
	Jun. 30, 2022
Regulated Operations [Abstract]
Schedule of Regulatory Assets	The following regulatory assets and liabilities associated with Utilities are included on the Condensed Consolidated Balance Sheets: June 30, September 30, June 30, Regulatory assets (a): Income taxes recoverable $ 151 $ 143 $ 131 Underfunded pension and postretirement plans 103 108 166 Environmental costs 34 58 58 Deferred fuel and power costs 14 11 — Removal costs, net 22 24 24 Other 47 53 17 Total regulatory assets $ 371 $ 397 $ 396 Regulatory liabilities (a): Postretirement benefit overcollections $ 12 $ 13 $ 12 Deferred fuel and power refunds 1 36 21 State tax benefits — distribution system repairs 34 32 30 Excess federal deferred income taxes 281 287 269 Other 8 20 2 Total regulatory liabilities $ 336 $ 388 $ 334 (a) Current regulatory assets are included in “Prepaid expenses and other current assets” and regulatory liabilities are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets.
Schedule of Regulatory Liabilities	The following regulatory assets and liabilities associated with Utilities are included on the Condensed Consolidated Balance Sheets: June 30, September 30, June 30, Regulatory assets (a): Income taxes recoverable $ 151 $ 143 $ 131 Underfunded pension and postretirement plans 103 108 166 Environmental costs 34 58 58 Deferred fuel and power costs 14 11 — Removal costs, net 22 24 24 Other 47 53 17 Total regulatory assets $ 371 $ 397 $ 396 Regulatory liabilities (a): Postretirement benefit overcollections $ 12 $ 13 $ 12 Deferred fuel and power refunds 1 36 21 State tax benefits — distribution system repairs 34 32 30 Excess federal deferred income taxes 281 287 269 Other 8 20 2 Total regulatory liabilities $ 336 $ 388 $ 334 (a) Current regulatory assets are included in “Prepaid expenses and other current assets” and regulatory liabilities are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets.

Defined Benefit Pension and O_2

Defined Benefit Pension and Other Postretirement Plans (Tables)	9 Months Ended
	Jun. 30, 2022
Retirement Benefits [Abstract]
Components of Net Periodic Pension Cost	Net periodic pension cost includes the following components: Three Months Ended June 30, 2022 2021 Service cost $ 4 $ 3 Interest cost 6 5 Expected return on assets (12) (10) Amortization of: Actuarial loss 2 4 Net cost $ — $ 2 Nine Months Ended June 30, 2022 2021 Service cost $ 12 $ 9 Interest cost 19 16 Expected return on assets (37) (30) Amortization of: Actuarial loss 6 11 Net cost $ — $ 6

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Jun. 30, 2022
Fair Value Disclosures [Abstract]
Financial Assets and Liabilities Measured at Fair Value on a Recurring Basis	The following table presents, on a gross basis, our financial assets and liabilities, including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy: Asset (Liability) Level 1 Level 2 Level 3 Total June 30, 2022: Derivative instruments: Assets: Commodity contracts $ 816 $ 1,149 $ — $ 1,965 Foreign currency contracts $ — $ 59 $ — $ 59 Interest rate contracts $ — $ 44 $ — $ 44 Liabilities: Commodity contracts $ (324) $ (37) $ — $ (361) Foreign currency contracts $ — $ (2) $ — $ (2) Non-qualified supplemental postretirement grantor trust investments (a) $ 46 $ — $ — $ 46 September 30, 2021: Derivative instruments: Assets: Commodity contracts $ 641 $ 1,008 $ — $ 1,649 Foreign currency contracts $ — $ 38 $ — $ 38 Liabilities: Commodity contracts $ (264) $ (16) $ — $ (280) Foreign currency contracts $ — $ (8) $ — $ (8) Interest rate contracts $ — $ (29) $ — $ (29) Non-qualified supplemental postretirement grantor trust investments (a) $ 53 $ — $ — $ 53 June 30, 2021: Derivative instruments: Assets: Commodity contracts $ 241 $ 396 $ — $ 637 Foreign currency contracts $ — $ 24 $ — $ 24 Liabilities: Commodity contracts $ (136) $ (9) $ — $ (145) Foreign currency contracts $ — $ (13) $ — $ (13) Interest rate contracts $ — $ (35) $ — $ (35) Non-qualified supplemental postretirement grantor trust investments (a) $ 42 $ — $ — $ 42
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: June 30, 2022 September 30, 2021 June 30, 2021 Carrying amount $ 6,483 $ 6,491 $ 5,890 Estimated fair value $ 6,145 $ 6,996 $ 6,314

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Jun. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Notional Amounts Related to Open Derivative Contracts	The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at June 30, 2022, September 30, 2021 and June 30, 2021, and the final settlement dates of the Company's open derivative contracts as of June 30, 2022, excluding those derivatives that qualified for the NPNS exception: Notional Amounts Type Units Settlements Extending Through June 30, 2022 September 30, 2021 June 30, 2021 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms October 2023 13 20 12 Non-utility Operations LPG swaps Gallons September 2024 669 708 688 Natural gas futures, forward, basis swap, options and pipeline contracts Dekatherms June 2026 353 355 344 Electricity forward and futures contracts Kilowatt hours November 2026 2,621 4,302 4,730 Interest Rate Risk: Interest rate swaps Euro October 2022 € 300 € 300 € 300 Interest rate swaps USD September 2024 $ 1,411 $ 1,421 $ 1,424 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD August 2025 $ 435 $ 509 $ 504 Net investment hedge forward foreign exchange contracts Euro December 2026 € 411 € 173 € 173
Schedule of Derivative Assets, Liabilities and Effects of Offsetting	The following table presents the Company’s derivative assets and liabilities by type, as well as the effects of offsetting: June 30, September 30, June 30, Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 28 $ 20 $ 15 Interest rate contracts 44 — — 72 20 15 Derivatives subject to PGC and DS mechanisms: Commodity contracts 30 58 14 Derivatives not designated as hedging instruments: Commodity contracts 1,935 1,591 623 Foreign currency contracts 31 18 9 1,966 1,609 632 Total derivative assets — gross 2,068 1,687 661 Gross amounts offset in the balance sheet (226) (216) (77) Cash collateral received (659) (468) (105) Total derivative assets — net $ 1,183 $ 1,003 $ 479 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts $ — $ (29) $ (35) Derivatives subject to PGC and DS mechanisms: Commodity contracts (23) (23) (6) Derivatives not designated as hedging instruments: Commodity contracts (338) (257) (139) Foreign currency contracts (2) (8) (13) (340) (265) (152) Total derivative liabilities — gross (363) (317) (193) Gross amounts offset in the balance sheet 226 216 77 Cash collateral pledged 13 3 — Total derivative liabilities — net $ (124) $ (98) $ (116)
Effects of Derivative Instruments on Condensed Consolidated Statements of Income and Changes in AOCI	The following tables provide information on the effects of derivative instruments on the Condensed Consolidated Statements of Income and changes in AOCI: Three Months Ended June 30,: Gain (Loss) Loss Location of Loss Reclassified from Cash Flow Hedges: 2022 2021 2022 2021 Interest rate contracts $ 11 $ (1) $ (4) $ (6) Interest expense Net Investment Hedges: Foreign currency contracts $ 23 $ (1) Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2022 2021 Location of Gain (Loss) Recognized in Income Commodity contracts $ (6) $ (5) Revenues Commodity contracts 466 347 Cost of sales Commodity contracts 6 — Other operating income, net Foreign currency contracts 17 (1) Other non-operating income, net Total $ 483 $ 341 Nine Months Ended June 30,: Gain (Loss) Loss Location of Loss Reclassified from Cash Flow Hedges: 2022 2021 2022 2021 Interest rate contracts $ 59 $ 5 $ (17) $ (19) Interest expense Net Investment Hedges: Foreign currency contracts $ 34 $ (2) Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2022 2021 Location of Gain (Loss) Recognized in Income Commodity contracts $ (5) $ (4) Revenues Commodity contracts 792 585 Cost of sales Commodity contracts 6 5 Other operating income, net Foreign currency contracts 32 (4) Other non-operating income, net Total $ 825 $ 582

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	9 Months Ended
	Jun. 30, 2022
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income	The tables below present changes in AOCI, net of tax: Three Months Ended June 30, 2022 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — March 31, 2022 $ (14) $ 11 $ (175) $ (178) Other comprehensive income (loss) before reclassification adjustments — 8 (106) (98) Amounts reclassified from AOCI — 3 — 3 Other comprehensive income (loss) attributable to UGI — 11 (106) (95) AOCI — June 30, 2022 $ (14) $ 22 $ (281) $ (273) Three Months Ended June 30, 2021 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — March 31, 2021 $ (25) $ (41) $ (60) $ (126) Other comprehensive income before reclassification adjustments — — 16 16 Amounts reclassified from AOCI — 5 — 5 Other comprehensive income attributable to UGI — 5 16 21 AOCI — June 30, 2021 $ (25) $ (36) $ (44) $ (105) Nine Months Ended June 30, 2022 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2021 $ (17) $ (33) $ (90) $ (140) Other comprehensive income (loss) before reclassification adjustments — 42 (191) (149) Amounts reclassified from AOCI 3 13 — 16 Other comprehensive income (loss) attributable to UGI 3 55 (191) (133) AOCI — June 30, 2022 $ (14) $ 22 $ (281) $ (273) Nine Months Ended June 30, 2021 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2020 $ (26) $ (54) $ (67) $ (147) Other comprehensive income before reclassification adjustments — 4 23 27 Amounts reclassified from AOCI 1 14 — 15 Other comprehensive income attributable to UGI 1 18 23 42 AOCI — June 30, 2021 $ (25) $ (36) $ (44) $ (105)

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Jun. 30, 2022
Segment Reporting [Abstract]
Schedule of Segment Reporting Information	Three Months Ended June 30, 2022 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 2,033 $ — $ 597 $ 738 $ 450 $ 250 $ (2) Intersegment revenues $ — $ (99) (b) $ — $ — $ 75 $ 24 $ — Cost of sales $ 1,361 $ (99) (b) $ 370 $ 544 $ 436 $ 121 $ (11) Operating income (loss) $ 99 $ — $ (10) $ 22 $ 38 $ 38 $ 11 (Loss) income from equity investees (45) — — — 6 — (51) Other non-operating income, net 20 — — 4 — 2 14 Earnings (loss) before interest expense and income taxes 74 — (10) 26 44 40 (26) Interest expense (82) — (41) (7) (11) (15) (8) (Loss) income before income taxes $ (8) $ — $ (51) $ 19 $ 33 $ 25 $ (34) Depreciation and amortization $ 130 $ — $ 44 $ 29 $ 20 $ 37 $ — Capital expenditures (including the effects of accruals) $ 201 $ — $ 28 $ 25 $ 9 $ 139 $ — Three Months Ended June 30, 2021 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 1,496 $ — $ 526 $ 572 $ 232 $ 171 $ (5) Intersegment revenues $ — $ (40) (b) $ — $ — $ 29 $ 10 $ 1 Cost of sales $ 516 $ (39) (b) $ 267 $ 355 $ 196 $ 67 $ (330) Operating income $ 391 $ — $ 11 $ 40 $ 14 $ 24 $ 302 (Loss) income from equity investees (86) — — — 7 — (93) Other non-operating income (expense), net 1 — — 1 — 1 (1) Earnings before interest expense and income taxes 306 — 11 41 21 25 208 Interest expense (77) — (40) (8) (10) (14) (5) Income (loss) before income taxes $ 229 $ — $ (29) $ 33 $ 11 $ 11 $ 203 Depreciation and amortization $ 125 $ — $ 43 $ 33 $ 19 $ 29 $ 1 Capital expenditures (including the effects of accruals) $ 162 $ — $ 26 $ 21 $ 3 $ 112 $ — Nine Months Ended June 30, 2022 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 8,172 $ — $ 2,423 $ 3,011 $ 1,424 $ 1,313 $ 1 Intersegment revenues $ — $ (396) (b) $ — $ — $ 307 $ 87 $ 2 Cost of sales $ 4,951 $ (394) (b) $ 1,333 $ 2,267 $ 1,389 $ 701 $ (345) Operating income $ 1,363 $ — $ 303 $ 211 $ 197 $ 325 $ 327 (Loss) income from equity investees (32) — — — 19 — (51) Loss on extinguishments of debt (11) — — — — — (11) Other non-operating income, net 41 — — 17 — 7 17 Earnings before interest expense and income taxes 1,361 — 303 228 216 332 282 Interest expense (245) — (120) (22) (31) (47) (25) Income before income taxes $ 1,116 $ — $ 183 $ 206 $ 185 $ 285 $ 257 Depreciation and amortization $ 387 $ — $ 132 $ 89 $ 57 $ 108 $ 1 Capital expenditures (including the effects of accruals) $ 546 $ — $ 99 $ 71 $ 25 $ 351 $ — As of June 30, 2022 Total assets $ 17,111 $ (182) $ 4,365 $ 4,410 $ 3,198 $ 5,146 $ 174 Nine Months Ended June 30, 2021 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 6,009 $ — $ 2,132 $ 2,106 $ 903 $ 873 $ (5) Intersegment revenues $ — $ (236) (b) $ — $ — $ 183 $ 50 $ 3 Cost of sales $ 2,623 $ (233) (b) $ 970 $ 1,229 $ 776 $ 401 $ (520) Operating income $ 1,564 $ — $ 391 $ 322 $ 156 $ 243 $ 452 (Loss) income from equity investees (69) — — — 24 — (93) Other non-operating income (expense), net — — — 4 — 2 (6) Earnings before interest expense and income taxes 1,495 — 391 326 180 245 353 Interest expense (233) — (120) (21) (31) (42) (19) Income before income taxes $ 1,262 $ — $ 271 $ 305 $ 149 $ 203 $ 334 Depreciation and amortization $ 375 $ — $ 130 $ 100 $ 56 $ 87 $ 2 Capital expenditures (including the effects of accruals) $ 438 $ — $ 83 $ 68 $ 32 $ 255 $ — As of June 30, 2021 Total assets $ 15,006 $ (267) $ 4,381 $ 3,749 $ 2,904 $ 3,997 $ 242 (a) Corporate & Other includes specific items attributable to our reportable segments that are not included in the segment profit measures used by our CODM in assessing our reportable segments’ performance or allocating resources. The following table presents such pre-tax gains (losses) which have been included in Corporate & Other, and the reportable segments to which they relate: Three Months Ended June 30, 2022 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains (losses) on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 2 $ (4) Net (losses) gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ (46) $ 110 $ (51) Net gains on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ 6 $ — Restructuring costs Operating and administrative expenses $ (1) $ (2) $ (1) Unrealized gains on foreign currency derivative instruments Other non-operating income, net $ — $ 14 $ — Impairments associated with certain equity method investments Loss from equity investees $ — $ — $ (50) Three Months Ended June 30, 2021 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (4) Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 59 $ 226 $ 44 Unrealized losses on foreign currency derivative instruments Other non-operating income, net $ — $ (1) $ — Business transformation expenses Operating and administrative expenses $ (11) $ (6) $ — Impairments associated with certain equity method investments Loss from equity investees $ — $ — $ (93) Nine Months Ended June 30, 2022 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains (losses) on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 7 $ (6) Net (losses) gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ (83) $ 458 $ (29) Net gains on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ 6 $ — Restructuring costs Operating and administrative expenses $ (15) $ (4) $ (1) Loss on extinguishment of debt Loss on extinguishment of debt $ — $ (11) $ — Unrealized gains on foreign currency derivative instruments Other non-operating income, net $ — $ 19 $ — Impairments associated with certain equity method investments Loss from equity investees $ — $ — $ (50) Nine Months Ended June 30, 2021 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (4) Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 123 $ 380 $ 16 Unrealized losses on foreign currency derivative instruments Other non-operating income, net $ — $ (6) $ — Business transformation expenses Operating and administrative expenses $ (37) $ (12) $ — Impairments associated with certain equity method investments Loss from equity investees $ — $ — $ (93) (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, Utilities and AmeriGas Propane.

Nature of Operations (Details)

Nature of Operations (Details) - Mountaineer customer in Thousands, $ in Millions	Sep. 01, 2021 USD ($) county customer
Business Acquisition [Line Items]
Enterprise value	$ 540
Assumption of debt	$ 140
Customers served | customer	200
Number of counties of operation | county	50

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Schedule of Cash and Restricted Cash (Details) - USD ($) $ in Millions	Jun. 30, 2022	Sep. 30, 2021	Jun. 30, 2021	Sep. 30, 2020
Accounting Policies [Abstract]
Cash and cash equivalents	$ 670	$ 855	$ 545
Restricted cash	14	22	31
Cash, cash equivalents and restricted cash	$ 684	$ 877	$ 576	$ 357

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Shares Used in Computing Basic and Diluted Earnings Per Share (Details) - shares shares in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Denominator (thousands of shares):
Weighted-average common shares outstanding - basic (in shares)	210,190	209,099	209,992	208,934
Incremental shares issuable for stock options, common stock awards and Equity Units (in shares)	0	1,752	5,973	1,260
Weighted-average common shares outstanding - diluted (in shares)	210,190	210,851	215,965	210,194
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	5,668
Stock options
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	5,718	2,502	5,718	2,502

Revenue from Contracts with C_3

Revenue from Contracts with Customers - Disaggregated Revenues by Reportable Segment (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 2,004	$ 1,474	$ 8,082	$ 5,929
Other revenues	29	22	90	80
Total revenues	2,033	1,496	8,172	6,009
Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	249	168	1,309	864
Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	140	90	774	498
Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	57	34	318	190
Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	38	33	135	117
Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	9	6	65	43
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	5	5	17	16
Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,755	1,306	6,773	5,065
Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	880	800	3,684	3,250
Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	107	77	401	235
Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	631	311	2,254	1,205
Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	53	45	149	138
Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	9	1	38	12
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2	2	6	6
Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1	1	20	8
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	72	69	221	211
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(99)	(39)	(394)	(233)
Other revenues	0	(1)	(2)	(3)
Total revenues	(99)	(40)	(396)	(236)
Eliminations | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(24)	(10)	(87)	(50)
Eliminations | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(24)	(10)	(86)	(49)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	(1)	(1)
Eliminations | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(75)	(29)	(307)	(183)
Eliminations | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(70)	(24)	(206)	(89)
Eliminations | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(5)	(5)	(101)	(94)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Eliminations | UGI International
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Eliminations | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues	75	29	307	183
Eliminations | Utilities
Disaggregation of Revenue [Line Items]
Total revenues	24	10	87	50
Operating Segments | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	577	510	2,367	2,082
Other revenues	20	16	56	50
Total revenues	597	526	2,423	2,132
Operating Segments | AmeriGas Propane | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	577	510	2,367	2,082
Operating Segments | AmeriGas Propane | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	478	424	2,032	1,829
Operating Segments | AmeriGas Propane | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	48	35	172	92
Operating Segments | AmeriGas Propane | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	51	51	163	161
Operating Segments | UGI International
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	728	565	2,984	2,084
Other revenues	10	7	27	22
Total revenues	738	572	3,011	2,106
Operating Segments | UGI International | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	728	565	2,984	2,084
Operating Segments | UGI International | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	402	376	1,652	1,421
Operating Segments | UGI International | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	59	42	229	143
Operating Segments | UGI International | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	246	129	1,045	470
Operating Segments | UGI International | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	21	18	58	50
Operating Segments | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	525	260	1,729	1,082
Other revenues	0	1	2	4
Total revenues	525	261	1,731	1,086
Operating Segments | Midstream & Marketing | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	525	260	1,729	1,082
Operating Segments | Midstream & Marketing | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	455	206	1,415	824
Operating Segments | Midstream & Marketing | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	53	45	149	138
Operating Segments | Midstream & Marketing | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	14	6	139	106
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2	2	6	6
Operating Segments | Midstream & Marketing | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1	1	20	8
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	273	178	1,396	914
Other revenues	1	3	4	9
Total revenues	274	181	1,400	923
Operating Segments | Utilities | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	273	178	1,396	914
Operating Segments | Utilities | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	140	90	774	498
Operating Segments | Utilities | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	57	34	318	190
Operating Segments | Utilities | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	38	33	135	117
Operating Segments | Utilities | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	33	16	151	92
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	5	5	18	17
Operating Segments | Utilities | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Other revenues	(2)	(4)	3	(2)
Total revenues	(2)	(4)	3	(2)
Corporate & Other | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 0	$ 0	$ 0	$ 0

Revenue from Contracts with C_4

Revenue from Contracts with Customers - Narrative (Details) - USD ($) $ in Millions	9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Sep. 30, 2021
Disaggregation of Revenue [Line Items]
Contract liabilities	$ 128	$ 109	$ 149
Revenue recognized	117	$ 137
Midstream & Marketing
Disaggregation of Revenue [Line Items]
Expected revenue	2,300
Utilities
Disaggregation of Revenue [Line Items]
Expected revenue	$ 200

Acquisitions - Narrative (Detai

Acquisitions - Narrative (Details) - USD ($) $ in Millions			9 Months Ended
	Jan. 27, 2022	Sep. 01, 2021	Jun. 30, 2022
UGI Corporation Senior Credit Facility
Business Acquisition [Line Items]
Issuance of debt		$ 215
Stonehenge
Business Acquisition [Line Items]
Enterprise value	$ 190
Mountaineer
Business Acquisition [Line Items]
Enterprise value		540
Assumption of debt		$ 140
Goodwill decrease			$ 5

Acquisitions - Summary of Compo

Acquisitions - Summary of Components of Purchase Price Allocations (Details) - USD ($) $ in Millions	Jun. 30, 2022	Sep. 30, 2021	Sep. 01, 2021	Jun. 30, 2021
Liabilities assumed:
Goodwill	$ 3,671	$ 3,770		$ 3,543
Mountaineer
Assets acquired:
Cash and cash equivalents			$ 3
Accounts receivable			14
Inventories			41
Other current assets			21
Property, plant and equipment			397
Other noncurrent assets			48
Total assets acquired			524
Liabilities assumed:
Short-term borrowings			55
Accounts payable			20
Other current liabilities			52
Long-term debt			164
Pension and other postretirement benefit obligation			33
Deferred income taxes			21
Other noncurrent liabilities			29
Total liabilities assumed			374
Goodwill			250
Net consideration transferred			$ 400

Inventories - Components of Inv

Inventories - Components of Inventories (Details) - USD ($) $ in Millions	Jun. 30, 2022	Sep. 30, 2021	Jun. 30, 2021
Inventory
Total inventories	$ 496	$ 469	$ 296
Non-utility LPG and natural gas
Inventory
Total inventories	261	278	187
Gas Utility natural gas
Inventory
Total inventories	84	68	16
Energy certificates
Inventory
Total inventories	70	53	42
Materials, supplies and other
Inventory
Total inventories	$ 81	$ 70	$ 51

Utility Regulatory Assets and_3

Utility Regulatory Assets and Liabilities and Regulatory Matters - Schedule of Regulatory Assets and Liabilities (Details) - Utilities - USD ($) $ in Millions	Jun. 30, 2022	Sep. 30, 2021	Jun. 30, 2021
Regulatory Assets
Regulatory assets	$ 371	$ 397	$ 396
Regulatory Liabilities
Regulatory liabilities	336	388	334
Postretirement benefit overcollections
Regulatory Liabilities
Regulatory liabilities	12	13	12
Deferred fuel and power refunds
Regulatory Liabilities
Regulatory liabilities	1	36	21
State tax benefits — distribution system repairs
Regulatory Liabilities
Regulatory liabilities	34	32	30
Excess federal deferred income taxes
Regulatory Liabilities
Regulatory liabilities	281	287	269
Other
Regulatory Liabilities
Regulatory liabilities	8	20	2
Income taxes recoverable
Regulatory Assets
Regulatory assets	151	143	131
Underfunded pension and postretirement plans
Regulatory Assets
Regulatory assets	103	108	166
Environmental costs
Regulatory Assets
Regulatory assets	34	58	58
Deferred fuel and power costs
Regulatory Assets
Regulatory assets	14	11	0
Removal costs, net
Regulatory Assets
Regulatory assets	22	24	24
Other
Regulatory Assets
Regulatory assets	$ 47	$ 53	$ 17

Utility Regulatory Assets and_4

Utility Regulatory Assets and Liabilities and Regulatory Matters - Narrative (Details) - USD ($) $ in Thousands								3 Months Ended	9 Months Ended
	Jun. 24, 2022	Jan. 28, 2022	Nov. 09, 2021	Apr. 01, 2021	Feb. 08, 2021	Oct. 08, 2020	Jan. 28, 2020	Dec. 31, 2021	Jun. 30, 2022	Jun. 30, 2021
Regulatory Assets
Net unrealized gains (losses)									$ 372,000	$ 509,000
Gas Utility
Regulatory Assets
Net unrealized gains (losses)								$ 35,000	$ 7,000	$ 9,000
Gas Utility | PAPUC
Regulatory Assets
Requested rate increase		$ 83,000					$ 75,000
Property, plant and equipment, net threshold				$ 2,875,000
Amortization period				10 years
Gas Utility | PAPUC | Joint Petition
Regulatory Assets
Requested rate increase	$ 49,000
Rate period		5 years
Weather condition rate		3%
Property, plant and equipment, net threshold		$ 3,368
Gas Utility | PAPUC | Phase I
Regulatory Assets
Requested rate increase	38,000
Gas Utility | PAPUC | Phase II
Regulatory Assets
Requested rate increase	$ 11,000
Gas Utility | PAPUC | Annual Base Distribution
Regulatory Assets
Approved rate increase						$ 20,000
Gas Utility | PAPUC | Beginning January 1, 2021
Regulatory Assets
Approved rate increase						10,000
Gas Utility | PAPUC | Beginning July 1, 2021
Regulatory Assets
Approved rate increase						$ 10,000
Electric Utility | PAPUC
Regulatory Assets
Requested rate increase					$ 9,000
Electric Utility | PAPUC | Joint Petition
Regulatory Assets
Requested rate increase			$ 6,000

Debt (Details)

Debt (Details)			3 Months Ended		9 Months Ended
	Jul. 12, 2022 USD ($)	Dec. 07, 2021 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Sep. 15, 2022	Jul. 15, 2022 USD ($)	Dec. 07, 2021 EUR (€)
Debt Instrument [Line Items]
Loss on extinguishment of debt			$ 0	$ 0	$ 11,000,000	$ 0
Term Loan | UGI Utilities | Variable Rate | Subsequent event
Debt Instrument [Line Items]
Quarterly Installments	$ 2,000,000
Senior Notes | UGI Utilities | 4.75% Senior Notes due July 15, 2032 | Subsequent event
Debt Instrument [Line Items]
Principal amount								$ 90,000,000
Interest rate								4.75%
Senior Notes | UGI Utilities | 4.75% Senior Notes due July 15, 2032 | Expected
Debt Instrument [Line Items]
Principal amount			$ 90,000,000		$ 90,000,000
Interest rate			4.75%		4.75%
Senior Notes | UGI Utilities | 4.99% Senior Notes due September 15, 2052 | Expected
Debt Instrument [Line Items]
Principal amount			$ 85,000,000		$ 85,000,000
Interest rate			4.99%		4.99%
Senior Notes | UGI Utilities | 4.99% Senior Notes due September 15, 2052 | Forecast
Debt Instrument [Line Items]
Interest rate							4.99%
Senior Notes | Mountaineer | 4.49% Senior Notes due August 16, 2052 | Expected
Debt Instrument [Line Items]
Principal amount			$ 40,000,000		$ 40,000,000
Interest rate			4.49%		4.49%
Senior Notes | UGI International
Debt Instrument [Line Items]
Loss on extinguishment of debt		$ 11,000,000
Senior Notes | UGI International | 2.50% Senior Notes due December 1, 2029
Debt Instrument [Line Items]
Principal amount | €									€ 400,000,000
Interest rate									2.50%
Senior Notes | UGI International | 3.25% Senior Notes due November 1, 2025
Debt Instrument [Line Items]
Interest rate									3.25%

Commitments and Contingencies (

Commitments and Contingencies (Details)	9 Months Ended	12 Months Ended
	Jun. 30, 2022 USD ($) subsidiary	Sep. 30, 2017 USD ($) record_of_decision	Sep. 30, 2021 USD ($)	Jun. 30, 2021 USD ($)
Loss Contingencies
Environmental expenditures cap during calendar year	$ 5,000,000
CPG, PNG and UGI Gas COAs
Loss Contingencies
Accrual for environmental loss contingencies	$ 51,000,000		$ 50,000,000	$ 49,000,000
Utilities
Loss Contingencies
Number of subsidiaries acquired with similar histories | subsidiary	2
AmeriGas OLP | Saranac Lake, New York | NYDEC ROD
Loss Contingencies
Accrual for environmental loss contingencies	$ 8,000,000
Loss contingency, number of remediation plans | record_of_decision		3
Estimated remediation plan cost		$ 28,000,000

Defined Benefit Pension and O_3

Defined Benefit Pension and Other Postretirement Plans - Components of Net Periodic Pension Cost (Details) - Pension Benefits - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Defined Benefit Plan Disclosure
Service cost	$ 4	$ 3	$ 12	$ 9
Interest cost	6	5	19	16
Expected return on assets	(12)	(10)	(37)	(30)
Amortization of:
Actuarial loss	2	4	6	11
Net cost	$ 0	$ 2	$ 0	$ 6

Fair Value Measurements - Finan

Fair Value Measurements - Financial Assets and Liabilities that are Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Millions	Jun. 30, 2022	Sep. 30, 2021	Jun. 30, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	$ 2,068	$ 1,687	$ 661
Derivative instruments, Liabilities	(363)	(317)	(193)
Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	30	58	14
Derivative instruments, Liabilities	(23)	(23)	(6)
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	46	53	42
Recurring | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	1,965	1,649	637
Derivative instruments, Liabilities	(361)	(280)	(145)
Recurring | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	59	38	24
Derivative instruments, Liabilities	(2)	(8)	(13)
Recurring | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	44
Derivative instruments, Liabilities		(29)	(35)
Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	46	53	42
Recurring | Level 1 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	816	641	241
Derivative instruments, Liabilities	(324)	(264)	(136)
Recurring | Level 1 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	0	0	0
Derivative instruments, Liabilities	0	0	0
Recurring | Level 1 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	0
Derivative instruments, Liabilities		0	0
Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	0	0	0
Recurring | Level 2 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	1,149	1,008	396
Derivative instruments, Liabilities	(37)	(16)	(9)
Recurring | Level 2 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	59	38	24
Derivative instruments, Liabilities	(2)	(8)	(13)
Recurring | Level 2 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	44
Derivative instruments, Liabilities		(29)	(35)
Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	0	0	0
Recurring | Level 3 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	0	0	0
Derivative instruments, Liabilities	0	0	0
Recurring | Level 3 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	0	0	0
Derivative instruments, Liabilities	0	0	0
Recurring | Level 3 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	$ 0
Derivative instruments, Liabilities		$ 0	$ 0

Fair Value Measurements - Carry

Fair Value Measurements - Carrying Amounts and Estimated Fair Values of Long-term Debt (Details) - USD ($) $ in Millions	Jun. 30, 2022	Sep. 30, 2021	Jun. 30, 2021
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,483	$ 6,491	$ 5,890
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,145	$ 6,996	$ 6,314

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Narrative (Details)	3 Months Ended		9 Months Ended
	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2022 EUR (€)	Dec. 07, 2021 EUR (€)	Sep. 30, 2021 USD ($)	Sep. 30, 2021 EUR (€)	Jun. 30, 2021 EUR (€)
Derivative [Line Items]
Pre-tax (losses) gains associated with net investment hedges	$ 41,000,000	$ (8,000,000)	$ 75,000,000	$ (9,000,000)
Maximum amount of loss	2,068,000,000		2,068,000,000
Cash collateral received	(659,000,000)	(105,000,000)	(659,000,000)	(105,000,000)			$ (468,000,000)
UGI International | Senior Notes | 3.25% Senior Notes due November 1, 2025
Derivative [Line Items]
Interest rate						3.25%
IRPAs
Derivative [Line Items]
Notional amount	0	0	0	0			0
Pre-tax net losses associated with interest rate hedges	$ 3,000,000		$ 3,000,000
Forward foreign currency exchange contracts
Derivative [Line Items]
Derivative notional amount percent of required need coverage	90%		90%		90%
Foreign currency contracts
Derivative [Line Items]
Notional amount	$ 435,000,000	$ 504,000,000	$ 435,000,000	$ 504,000,000	€ 411,000,000		$ 509,000,000	€ 173,000,000	€ 173,000,000
Foreign currency contracts | UGI International | Net Investment Hedging
Derivative [Line Items]
Notional amount | €						€ 93,000,000

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Schedule of Notional Amounts (Details) € in Millions, kWh in Millions, gal in Millions, DTH in Millions, $ in Millions	Jun. 30, 2022 USD ($) DTH kWh gal	Jun. 30, 2022 EUR (€) DTH kWh gal	Sep. 30, 2021 USD ($) gal DTH kWh	Sep. 30, 2021 EUR (€) gal DTH kWh	Jun. 30, 2021 USD ($) gal kWh DTH	Jun. 30, 2021 EUR (€) gal kWh DTH
Commodity contracts | Regulated Utility Operations | Natural Gas
Derivative [Line Items]
Notional amount (in units)	13	13	20	20	12	12
Commodity contracts | Non-utility Operations | LPG
Derivative [Line Items]
Notional amount (in units) | gal	669	669	708	708	688	688
Commodity contracts | Non-utility Operations | Electricity
Derivative [Line Items]
Notional amount (in units) | kWh	2,621	2,621	4,302	4,302	4,730	4,730
Natural gas futures, forward and pipeline contracts (in dekatherms) | Non-utility Operations | Natural Gas
Derivative [Line Items]
Notional amount (in units)	353	353	355	355	344	344
Interest rate swaps
Derivative [Line Items]
Notional amount	$ 1,411	€ 300	$ 1,421	€ 300	$ 1,424	€ 300
Forward foreign currency exchange contracts
Derivative [Line Items]
Notional amount	$ 435	€ 411	$ 509	€ 173	$ 504	€ 173

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2022	Sep. 30, 2021	Jun. 30, 2021
Derivative assets:
Total derivative assets — gross	$ 2,068	$ 1,687	$ 661
Gross amounts offset in the balance sheet	(226)	(216)	(77)
Cash collateral received	(659)	(468)	(105)
Total derivative assets — net	1,183	1,003	479
Derivative liabilities:
Total derivative liabilities — gross	(363)	(317)	(193)
Gross amounts offset in the balance sheet	226	216	77
Cash collateral pledged	13	3	0
Total derivative liabilities — net	(124)	(98)	(116)
Commodity contracts
Derivative assets:
Total derivative assets — gross	30	58	14
Derivative liabilities:
Total derivative liabilities — gross	(23)	(23)	(6)
Derivatives designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	72	20	15
Derivatives designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	28	20	15
Derivatives designated as hedging instruments: | Interest rate contracts
Derivative assets:
Total derivative assets — gross	44	0	0
Derivative liabilities:
Total derivative liabilities — gross	0	(29)	(35)
Derivatives not designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	1,966	1,609	632
Derivative liabilities:
Total derivative liabilities — gross	(340)	(265)	(152)
Derivatives not designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	31	18	9
Derivative liabilities:
Total derivative liabilities — gross	(2)	(8)	(13)
Derivatives not designated as hedging instruments: | Commodity contracts
Derivative assets:
Total derivative assets — gross	1,935	1,591	623
Derivative liabilities:
Total derivative liabilities — gross	$ (338)	$ (257)	$ (139)

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Effects of Derivative Instruments on the Condensed Consolidated Statements of Income and Changes in AOCI (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Derivatives not designated as hedging instruments:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 483	$ 341	$ 825	$ 582
Interest rate contracts | Derivatives designated as hedging instruments: | Cash Flow Hedges
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	11	(1)	59	5
Interest rate contracts | Derivatives designated as hedging instruments: | Interest expense | Cash Flow Hedges
Derivative Instruments, Gain (Loss)
Loss Reclassified from AOCI into Income	(4)	(6)	(17)	(19)
Foreign currency contracts | Derivatives designated as hedging instruments: | Net Investment Hedging
Derivative Instruments, Gain (Loss)
Foreign currency contracts	23	(1)	34	(2)
Foreign currency contracts | Derivatives not designated as hedging instruments: | Other non-operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	17	(1)	32	(4)
Commodity contracts | Derivatives not designated as hedging instruments: | Revenues
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(6)	(5)	(5)	(4)
Commodity contracts | Derivatives not designated as hedging instruments: | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	466	347	792	585
Commodity contracts | Derivatives not designated as hedging instruments: | Other operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 6	$ 0	$ 6	$ 5

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period			$ 5,531
Other comprehensive income (loss) before reclassification adjustments	$ (98)	$ 16	(149)	$ 27
Amounts reclassified from AOCI	3	5	16	15
Other comprehensive income (loss) attributable to UGI	(95)	21	(133)	42
Balance, end of period	6,005	5,106	6,005	5,106
Postretirement Benefit Plans
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(14)	(25)	(17)	(26)
Other comprehensive income (loss) before reclassification adjustments	0	0	0	0
Amounts reclassified from AOCI	0	0	3	1
Other comprehensive income (loss) attributable to UGI	0	0	3	1
Balance, end of period	(14)	(25)	(14)	(25)
Derivative Instruments
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	11	(41)	(33)	(54)
Other comprehensive income (loss) before reclassification adjustments	8	0	42	4
Amounts reclassified from AOCI	3	5	13	14
Other comprehensive income (loss) attributable to UGI	11	5	55	18
Balance, end of period	22	(36)	22	(36)
Foreign Currency
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(175)	(60)	(90)	(67)
Other comprehensive income (loss) before reclassification adjustments	(106)	16	(191)	23
Amounts reclassified from AOCI	0	0	0	0
Other comprehensive income (loss) attributable to UGI	(106)	16	(191)	23
Balance, end of period	(281)	(44)	(281)	(44)
Total
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(178)	(126)	(140)	(147)
Balance, end of period	$ (273)	$ (105)	$ (273)	$ (105)

Segment Information - Narrative

Segment Information - Narrative (Details)	9 Months Ended
	Jun. 30, 2022 segment
Segment Reporting [Abstract]
Number of reportable segments	4

Segment Information - Schedule

Segment Information - Schedule of Segment Reporting Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Sep. 30, 2021
Segment Reporting Information [Line Items]
Revenues from external customers	$ 2,033	$ 1,496	$ 8,172	$ 6,009
Cost of sales	1,361	516	4,951	2,623
Operating income	99	391	1,363	1,564
(Loss) income from equity investees	(45)	(86)	(32)	(69)
Loss on extinguishment of debt	0	0	(11)	0
Other non-operating income (expense), net	20	1	41	0
Earnings before interest expense and income taxes	74	306	1,361	1,495
Interest expense	(82)	(77)	(245)	(233)
(Loss) income before income taxes	(8)	229	1,116	1,262
Depreciation and amortization	130	125	387	375
Capital expenditures (including the effects of accruals)	201	162	546	438
Total assets	17,111	15,006	17,111	15,006	$ 16,723
AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishment of debt			0
UGI International
Segment Reporting Information [Line Items]
Loss on extinguishment of debt			(11)
Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishment of debt			0
Eliminations
Segment Reporting Information [Line Items]
Revenues from external customers	(99)	(40)	(396)	(236)
Cost of sales	(99)	(39)	(394)	(233)
Operating income	0	0	0	0
(Loss) income from equity investees	0	0	0	0
Loss on extinguishment of debt			0
Other non-operating income (expense), net	0	0	0	0
Earnings before interest expense and income taxes	0	0	0	0
Interest expense	0	0	0	0
(Loss) income before income taxes	0	0	0	0
Depreciation and amortization	0	0	0	0
Capital expenditures (including the effects of accruals)	0	0	0	0
Total assets	(182)	(267)	(182)	(267)
Eliminations | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues from external customers	0	0	0	0
Eliminations | UGI International
Segment Reporting Information [Line Items]
Revenues from external customers	0	0	0	0
Eliminations | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues from external customers	75	29	307	183
Eliminations | Utilities
Segment Reporting Information [Line Items]
Revenues from external customers	24	10	87	50
Operating Segments | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues from external customers	597	526	2,423	2,132
Cost of sales	370	267	1,333	970
Operating income	(10)	11	303	391
(Loss) income from equity investees	0	0	0	0
Loss on extinguishment of debt			0
Other non-operating income (expense), net	0	0	0	0
Earnings before interest expense and income taxes	(10)	11	303	391
Interest expense	(41)	(40)	(120)	(120)
(Loss) income before income taxes	(51)	(29)	183	271
Depreciation and amortization	44	43	132	130
Capital expenditures (including the effects of accruals)	28	26	99	83
Total assets	4,365	4,381	4,365	4,381
Operating Segments | UGI International
Segment Reporting Information [Line Items]
Revenues from external customers	738	572	3,011	2,106
Cost of sales	544	355	2,267	1,229
Operating income	22	40	211	322
(Loss) income from equity investees	0	0	0	0
Loss on extinguishment of debt			0
Other non-operating income (expense), net	4	1	17	4
Earnings before interest expense and income taxes	26	41	228	326
Interest expense	(7)	(8)	(22)	(21)
(Loss) income before income taxes	19	33	206	305
Depreciation and amortization	29	33	89	100
Capital expenditures (including the effects of accruals)	25	21	71	68
Total assets	4,410	3,749	4,410	3,749
Operating Segments | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues from external customers	525	261	1,731	1,086
Revenues, before intersegment effect	450	232	1,424	903
Cost of sales	436	196	1,389	776
Operating income	38	14	197	156
(Loss) income from equity investees	6	7	19	24
Loss on extinguishment of debt			0
Other non-operating income (expense), net	0	0	0	0
Earnings before interest expense and income taxes	44	21	216	180
Interest expense	(11)	(10)	(31)	(31)
(Loss) income before income taxes	33	11	185	149
Depreciation and amortization	20	19	57	56
Capital expenditures (including the effects of accruals)	9	3	25	32
Total assets	3,198	2,904	3,198	2,904
Operating Segments | Utilities
Segment Reporting Information [Line Items]
Revenues from external customers	274	181	1,400	923
Revenues, before intersegment effect	250	171	1,313	873
Cost of sales	121	67	701	401
Operating income	38	24	325	243
(Loss) income from equity investees	0	0	0	0
Loss on extinguishment of debt			0
Other non-operating income (expense), net	2	1	7	2
Earnings before interest expense and income taxes	40	25	332	245
Interest expense	(15)	(14)	(47)	(42)
(Loss) income before income taxes	25	11	285	203
Depreciation and amortization	37	29	108	87
Capital expenditures (including the effects of accruals)	139	112	351	255
Total assets	5,146	3,997	5,146	3,997
Corporate & Other
Segment Reporting Information [Line Items]
Revenues, before intersegment effect	(2)	(5)	1	(5)
Cost of sales	(11)	(330)	(345)	(520)
Operating income	11	302	327	452
(Loss) income from equity investees	(51)	(93)	(51)	(93)
Loss on extinguishment of debt			(11)
Other non-operating income (expense), net	14	(1)	17	(6)
Earnings before interest expense and income taxes	(26)	208	282	353
Interest expense	(8)	(5)	(25)	(19)
(Loss) income before income taxes	(34)	203	257	334
Depreciation and amortization	0	1	1	2
Capital expenditures (including the effects of accruals)	0	0	0	0
Total assets	$ 174	242	174	242
Intersegment revenues Corporate & Other
Segment Reporting Information [Line Items]
Revenues from external customers		$ 1	$ 2	$ 3

Segment Information - Reconcili

Segment Information - Reconciliation of Partnership Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			$ 372	$ 509
Loss on extinguishment of debt	$ 0	$ 0	(11)	0
AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishment of debt			0
AmeriGas Propane | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
AmeriGas Propane | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(46)	59	(83)	123
AmeriGas Propane | Other operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0		0
AmeriGas Propane | Other non-operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
AmeriGas Propane | Operating and administrative expenses
Segment Reporting Information [Line Items]
Restructuring costs	(1)		(15)
Business transformation expenses		(11)		(37)
AmeriGas Propane | Loss from equity investees
Segment Reporting Information [Line Items]
Impairments associated with certain equity method investments	0	0	0	0
UGI International
Segment Reporting Information [Line Items]
Loss on extinguishment of debt			(11)
UGI International | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	2	0	7	0
UGI International | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	110	226	458	380
UGI International | Other operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	6		6
UGI International | Other non-operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	14	(1)	19	(6)
UGI International | Operating and administrative expenses
Segment Reporting Information [Line Items]
Restructuring costs	(2)		(4)
Business transformation expenses		(6)		(12)
UGI International | Loss from equity investees
Segment Reporting Information [Line Items]
Impairments associated with certain equity method investments	0	0	0	0
Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishment of debt			0
Midstream & Marketing | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(4)	(4)	(6)	(4)
Midstream & Marketing | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(51)	44	(29)	16
Midstream & Marketing | Other operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0		0
Midstream & Marketing | Other non-operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
Midstream & Marketing | Operating and administrative expenses
Segment Reporting Information [Line Items]
Restructuring costs	(1)		(1)
Business transformation expenses		0		0
Midstream & Marketing | Loss from equity investees
Segment Reporting Information [Line Items]
Impairments associated with certain equity method investments	$ (50)	$ (93)	$ (50)	$ (93)

Business Transformation Initi_2

Business Transformation Initiatives (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
AmeriGas and UGI International
Restructuring Cost and Reserve [Line Items]
Recognized expenses		$ 17		$ 49
Corporate Services
Restructuring Cost and Reserve [Line Items]
Recognized expenses	$ 2	$ 4	$ 6	$ 8

Impairments Associated with C_2

Impairments Associated with Certain Equity Method Investments (Details)	1 Months Ended	3 Months Ended		9 Months Ended
	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($) mi	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($) mi	Jun. 30, 2021 USD ($)	Sep. 30, 2021 USD ($)
Loss from equity investees | Midstream & Marketing
Schedule of Equity Method Investments [Line Items]
Impairments associated with certain equity method investments		$ 50,000,000	$ 93,000,000	$ 50,000,000	$ 93,000,000
Pennant | Energy Services
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent		47%		47%
Impairments associated with certain equity method investments		$ 50,000,000
PennEast | UGI Penn East LLC | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent		20%		20%
Area of natural gas pipeline to be constructed (in miles) | mi		120		120
Impairments associated with certain equity method investments	$ 93,000,000
PennEast | UGI Penn East LLC | Affiliated Entity | Level 2
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 0		$ 0		$ 0	$ 0