UGI (UGI) 10-Q 8 Aug 23 2023 Q3 Quarterly report Financial data

Cover Page

Cover Page - shares	9 Months Ended
	Jun. 30, 2023	Jul. 31, 2023
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2023
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	500 North Gulph Road
Entity Address, City or Town	King of Prussia
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	19406
City Area Code	610
Local Phone Number	337-1000
Entity 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		209,478,774
Entity Central Index Key	0000884614
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--09-30
Former Address
Document Information [Line Items]
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
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, 2023	Sep. 30, 2022	Jun. 30, 2022
Current assets:
Cash and cash equivalents	$ 260	$ 405	$ 670
Restricted cash	78	64	14
Accounts receivable (less allowances for doubtful accounts of $87, $64 and $66, respectively)	955	1,127	1,234
Accrued utility revenues	29	23	19
Income taxes receivable	36	128	127
Inventories	410	665	496
Derivative instruments	31	865	773
Held for sale assets	64	295	0
Prepaid expenses and other current assets	172	230	176
Total current assets	2,035	3,802	3,509
Property, plant and equipment, (less accumulated depreciation of $4,536, $4,166 and $4,160, respectively)	8,394	8,040	7,839
Goodwill	3,060	3,612	3,671
Intangible assets, net	460	500	523
Utility regulatory assets	310	301	352
Derivative instruments	59	565	410
Other assets	925	755	807
Total assets	15,243	17,575	17,111
Current liabilities:
Current maturities of long-term debt	56	149	47
Short-term borrowings	481	368	276
Accounts payable	541	891	843
Derivative instruments	120	144	70
Held for sale liabilities	37	19	0
Other current liabilities	848	873	832
Total current liabilities	2,083	2,444	2,068
Long-term debt	6,579	6,483	6,399
Deferred income taxes	905	1,305	1,291
Derivative instruments	47	50	54
Other noncurrent liabilities	1,256	1,219	1,294
Total liabilities	10,870	11,501	11,106
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)	167	162	162
UGI Common Stock, without par value (authorized — 450,000,000 shares; issued — 210,882,552, 210,560,494 and 210,378,881 shares, respectively)	1,500	1,483	1,474
Retained earnings	2,974	4,841	4,674
Accumulated other comprehensive loss	(222)	(380)	(273)
Treasury stock, at cost	(55)	(40)	(41)
Total UGI Corporation stockholders’ equity	4,364	6,066	5,996
Noncontrolling interests	9	8	9
Total equity	4,373	6,074	6,005
Total liabilities and equity	$ 15,243	$ 17,575	$ 17,111

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2023	Sep. 30, 2022	Jun. 30, 2022
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 87	$ 64	$ 66
Accumulated depreciation	$ 4,536	$ 4,166	$ 4,160
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)	210,882,552	210,560,494	210,378,881

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (unaudited) - USD ($) shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Statement [Abstract]
Revenues	$ 1,659	$ 2,033	$ 7,524	$ 8,172
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)	1,104	1,361	6,358	4,951
Operating and administrative expenses	523	465	1,639	1,532
Depreciation and amortization	134	130	397	387
Impairment of goodwill	656	0	656	0
Loss on disposal of U.K. energy marketing business	0	0	215	0
Other operating income, net	(26)	(22)	(60)	(61)
Costs and expenses	2,391	1,934	9,205	6,809
Operating (loss) income	(732)	99	(1,681)	1,363
Income (loss) from equity investees	1	(45)	2	(32)
Loss on extinguishments of debt	(9)	0	(9)	(11)
Other non-operating income (expense), net	1	20	(25)	41
Interest expense	(96)	(82)	(281)	(245)
(Loss) income before income taxes	(835)	(8)	(1,994)	1,116
Income tax benefit (expense)	46	1	361	(285)
Net (loss) income including noncontrolling interests	(789)	(7)	(1,633)	831
Deduct net income attributable to noncontrolling interests	0	0	0	(2)
Net (loss) income attributable to UGI Corporation	$ (789)	$ (7)	$ (1,633)	$ 829
(Loss) earnings per common share attributable to UGI Corporation stockholders:
Basic (in USD per share)	$ (3.76)	$ (0.03)	$ (7.78)	$ 3.95
Diluted (in USD per share)	$ (3.76)	$ (0.03)	$ (7.78)	$ 3.84
Weighted-average common shares outstanding (thousands):
Basic (in shares)	209,706	210,190	209,811	209,992
Diluted (in shares)	209,706	210,190	209,811	215,965

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Comprehensive Income [Abstract]
Net (loss) income including noncontrolling interests	$ (789)	$ (7)	$ (1,633)	$ 831
Other comprehensive income (loss):
Net gains on derivative instruments (net of tax of $(10), $(3), $(5) and $(17), respectively)	22	8	10	42
Reclassifications of net (gains) losses on derivative instruments (net of tax of $4, $(1), $8 and $(4), respectively)	(10)	3	(20)	13
Foreign currency adjustments (net of tax of $2, $(17), $31 and $(30), respectively)	8	(106)	169	(191)
Benefit plans (net of tax of $1, $0, $1 and $(1), respectively)	(1)	0	(1)	3
Other comprehensive income (loss)	19	(95)	158	(133)
Comprehensive (loss) income including noncontrolling interests	(770)	(102)	(1,475)	698
Deduct comprehensive income attributable to noncontrolling interests	0	0	0	(2)
Comprehensive (loss) income attributable to UGI Corporation	$ (770)	$ (102)	$ (1,475)	$ 696

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Comprehensive Income [Abstract]
Net gains on derivative instruments, tax	$ (10)	$ (3)	$ (5)	$ (17)
Reclassifications of net (gains) losses on derivative instruments, tax	4	(1)	8	(4)
Foreign currency adjustments, tax	2	(17)	31	(30)
Benefit plans, tax	$ 1	$ 0	$ 1	$ (1)

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) - USD ($) $ in Millions	9 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income including noncontrolling interests	$ (1,633)	$ 831
Adjustments to reconcile net (loss) income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization	397	387
Deferred income tax (benefit) expense, net	(418)	142
Provision for uncollectible accounts	56	46
Changes in unrealized gains and losses on derivative instruments	1,866	(372)
Loss on disposal of U.K. energy marketing business	215	0
Impairment of assets	19	0
Impairment of goodwill	656	0
Loss on extinguishments of debt	9	11
(Income) loss from equity investees	(2)	32
Settlement of Energy Services interest rate swap	32	0
Amortization of settled Energy Services interest rate swap	(8)	0
Other, net	20	37
Net change in:
Accounts receivable and accrued utility revenues	139	(486)
Income taxes receivable	91	1
Inventories	275	(42)
Utility deferred fuel and power costs, net of changes in unsettled derivatives	73	(7)
Accounts payable	(365)	50
Derivative instruments collateral deposits (paid) received	(489)	181
Other current assets	(22)	93
Other current liabilities	(54)	(56)
Net cash provided by operating activities	857	848
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(670)	(551)
Acquisitions of businesses and assets, net of cash acquired	(9)	(188)
Investments in equity method investees	(101)	(41)
Settlements of net investment hedges	22	26
Other, net	(3)	37
Net cash used by investing activities	(761)	(717)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(230)	(220)
Issuances of long-term debt, net of discount and issuance costs	1,867	863
Repayments of long-term debt and finance leases, including redemption premiums	(1,953)	(806)
Increase (decrease) in short-term borrowings	49	(91)
Receivables Facility net borrowings	45	0
Payments on Purchase Contracts	(12)	(12)
Issuances of UGI Common Stock	12	14
Repurchases of UGI Common Stock	(22)	(38)
Net cash used by financing activities	(244)	(290)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	17	(34)
Cash, cash equivalents and restricted cash decrease	(131)	(193)
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of period	338	684
Cash, cash equivalents and restricted cash at beginning of period	469	877
Cash, cash equivalents and restricted cash decrease	$ (131)	$ (193)

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	Preferred stock, without par value Cumulative effect of change in accounting - ASU 2020-06 (Note 3)	Common stock, without par value	Common stock, without par value Cumulative effect of change in accounting - ASU 2020-06 (Note 3)	Retained earnings	Retained earnings Cumulative effect of change in accounting - ASU 2020-06 (Note 3)	Accumulated other comprehensive income (loss)	Treasury stock	Noncontrolling interests
Balance, beginning of period at Sep. 30, 2021			$ 213	$ 1	$ 1,394		$ 4,081	$ (1)	$ (140)	$ (26)	$ 9
Increase (Decrease) in Stockholders' Equity
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 ($0.375, $0.36, $1.095 and $1.05, respectively)							(220)
Net gains on derivative instruments	42								42
Reclassification of net (gains) 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 income attributable to 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 Sep. 30, 2021			213	1	1,394		4,081	(1)	(140)	(26)	9
Balance, end of period at Sep. 30, 2022	$ 6,074		162	5	1,483	$ (6)	4,841	1	(380)	(40)	8
Increase (Decrease) in Stockholders' Equity
Accounting Standards Update [Extensible List]	Accounting Standards Update 2020-06 [Member]
Balance, beginning of period at Mar. 31, 2022			161	1	1,465		4,757	(1)	(178)	(5)	10
Increase (Decrease) in Stockholders' Equity
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 ($0.375, $0.36, $1.095 and $1.05, respectively)							(75)
Net gains on derivative instruments	8								8
Reclassification of net (gains) 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 income attributable to noncontrolling interests	(7)
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 Sep. 30, 2022	6,074		162	$ 5	1,483	$ (6)	4,841	$ 1	(380)	(40)	8
Increase (Decrease) in Stockholders' Equity
Other											1
Common Stock issued in connection with employee and director plans, net of tax withheld					9
Equity-based compensation expense					14
Losses on common stock transactions in connection with employee and director plans							(5)
Net (loss) income attributable to UGI Corporation	(1,633)						(1,633)
Cash dividends on UGI Common Stock ($0.375, $0.36, $1.095 and $1.05, respectively)							(230)
Net gains on derivative instruments	10								10
Reclassification of net (gains) losses on derivative instruments	(20)								(20)
Benefit plans	(1)								(1)
Foreign currency adjustments	169								169
Common Stock issued in connection with employee and director plans, net of tax withheld										7
Repurchases of UGI Common Stock										(22)
Net income attributable to noncontrolling interests	(1,633)
Balance, end of period at Jun. 30, 2023	4,373	4,364	167		1,500		2,974		(222)	(55)	9
Balance, beginning of period at Mar. 31, 2023			167		1,492		3,842		(241)	(55)	9
Increase (Decrease) in Stockholders' Equity
Common Stock issued in connection with employee and director plans, net of tax withheld					3
Equity-based compensation expense					5
Net (loss) income attributable to UGI Corporation	(789)						(789)
Cash dividends on UGI Common Stock ($0.375, $0.36, $1.095 and $1.05, respectively)							(79)
Net gains on derivative instruments	22								22
Reclassification of net (gains) losses on derivative instruments	(10)								(10)
Benefit plans	(1)								(1)
Foreign currency adjustments	8								8
Net income attributable to noncontrolling interests	(789)
Balance, end of period at Jun. 30, 2023	$ 4,373	$ 4,364	$ 167		$ 1,500		$ 2,974		$ (222)	$ (55)	$ 9

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (unaudited) (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Stockholders' Equity [Abstract]
Cash dividends on common stock (in USD per share)	$ 0.375	$ 0.36	$ 1.095	$ 1.05

Nature of Operations

Nature of Operations	9 Months Ended
	Jun. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations	Note 1 — Nature of Operations UGI is a holding company that, through subsidiaries and affiliates, distributes, stores, transports and markets energy products and related services. In the U.S., we own and operate (1) a retail propane marketing and distribution business; (2) natural gas and electric distribution utilities; and (3) energy marketing, midstream infrastructure, storage, natural gas gathering and processing, natural gas production, electricity generation and energy services businesses. In Europe, we market and distribute propane and other LPG, and market other energy products and services. We conduct a domestic propane marketing and distribution business through AmeriGas Partners. AmeriGas Partners conducts its propane marketing and distribution business through its principal operating subsidiary, AmeriGas OLP. UGI International, LLC, through its subsidiaries and affiliates, conducts (1) an LPG distribution business throughout much of Europe and (2) an energy marketing business in France, Belgium, and the Netherlands. These businesses are conducted principally through our subsidiaries, UGI France, Flaga, AvantiGas, DVEP and UniverGas. See Note 5 for additional information regarding the UGI International energy marketing businesses. Energy Services conducts, directly and through subsidiaries and affiliates, energy marketing, including RNG, midstream transmission, LNG storage, natural gas gathering and processing, natural gas and RNG production, electricity generation and energy services businesses primarily in the eastern region of the U.S., eastern Ohio, the panhandle of West Virginia and California. UGID owns electricity generation facilities principally located in Pennsylvania. Energy Services and its subsidiaries’ storage, LNG and portions of its midstream transmission operations are subject to regulation by the FERC. Our Utilities segment includes UGI Utilities and Mountaineer. PA Gas Utility serves customers in eastern and central Pennsylvania and in portions of one Maryland county, and Mountaineer serves customers in West Virginia. Electric Utility serves customers in portions of Luzerne and Wyoming counties in northeastern Pennsylvania. PA Gas Utility is subject to regulation by the PAPUC and FERC and, with respect to its customers in Maryland, the MDPSC. Mountaineer is subject to regulation by the WVPSC and FERC. Electric Utility is subject to regulation by the PAPUC and FERC.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Jun. 30, 2023
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, 2022, 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 2022 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 $ 260 $ 670 Restricted cash 78 14 Cash, cash equivalents and restricted cash $ 338 $ 684 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 2023 2022 2023 2022 Denominator (thousands of shares): Weighted-average common shares outstanding — basic 209,706 210,190 209,811 209,992 Incremental shares issuable for stock options, common stock awards and Equity Units (a) — — — 5,973 Weighted-average common shares outstanding — diluted 209,706 210,190 209,811 215,965 (a) For the three months ended June 30, 2023 and 2022 and for the nine months ended June 30, 2023, 5,972, 5,668, and 6,222, of such shares, respectively, have been excluded as such incremental shares would be antidilutive due to the net losses for the periods. For the nine months ended June 30, 2022, 5,718 shares associated with outstanding stock option awards were excluded from the computation of diluted earnings per share because their effect was antidilutive. Equity Method Investments. We account for privately held equity securities of entities without readily determinable fair values in which we do not have control, but have significant influence over operating and financial policies, under the equity method. These are included in "Other assets" on the Condensed Consolidated Balance Sheets. Equity method earnings are included in "Income (loss) from equity investees" on the Condensed Consolidated Statements of Income. Our equity method investments primarily comprise MBL Bioenergy, Pine Run and other equity method investments in biomass and other renewable energy projects. MBL Bioenergy . The Company has an approximate 99.99% interest in MBL Bioenergy, a company jointly owned by UGI Dakota, LLC, Sevana Bioenergy and a subsidiary of California Bioenergy. The sole purpose of MBL Bioenergy is the development of RNG projects in South Dakota comprising three dairy waste anaerobic digester systems. MBL Bioenergy is a variable interest entity whereby the Company has determined that it is not the primary beneficiary since it does not direct the activities that most significantly impact the entity’s economic performance. The carrying value of our investment in MBL Bioenergy totaled $93 and $0 at June 30, 2023 and 2022, respectively. Pine Run. The Company has an approximately 49% interest in Pine Run, a company jointly owned by Stonehenge Energy Resources and UGI Pine Run LLC. Pine Run owns Pine Run Midstream, which operates dry gas gathering pipelines and compression assets in western Pennsylvania. The carrying value of our investment in Pine Run totaled $75 and $67 at June 30, 2023 and 2022, respectively. Pennant . At June 30, 2022, the carrying value of our investment in Pennant was $49. In connection with 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 then 47% membership interest, which was recorded in “Income (loss) from equity investees” in the Condensed Consolidated Statements of Income. During the fourth quarter of Fiscal 2022, UGI, through Energy Services, completed the Pennant Acquisition in which Energy Services acquired the remaining 53% of the equity interests in Pennant. The acquisition of the remaining interests was accounted for as an acquisition of assets, and the purchase price of approximately $61 was primarily allocated to property, plant and equipment. Other Equity Method Investments . The carrying values of our other equity method investments totaled $84 and $44 at June 30, 2023 and 2022, respectively, and principally comprise a number of investments in biomass and other renewable energy projects at Midstream & Marketing and a renewable energy joint venture at UGI International. Our maximum exposure to loss related to these investments is limited to the amount invested. 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. Goodwill. We do not amortize goodwill, but test it at least annually for impairment at the reporting unit level. A reporting unit is an operating segment, or one level below an operating segment (a component) if it constitutes a business for which discrete financial information is available and regularly reviewed by segment management. Components are aggregated into a single reporting unit if they have similar economic characteristics. Each of our reporting units with goodwill is required to perform impairment tests annually or whenever events or circumstances indicate that the value of goodwill may be impaired. During the quarter ended June 30, 2023, the Company identified interim impairment indicators related to goodwill within the AmeriGas Propane reporting unit: (1) AmeriGas Partners issued $500 of Senior Notes at an interest rate of 9.375%, which was significantly higher than the interest rates on the other AmeriGas Propane debt obligations; and (2) financial projections for the AmeriGas Propane reporting unit were reduced significantly compared to previous forecasts following declines in gross margins and customer retention and higher operating expenses. The Company concluded that these events constituted triggering events that indicate that the AmeriGas Propane goodwill may be impaired and, as such, performed an interim impairment test of its goodwill as of May 31, 2023. Using level 3 inputs, we performed a quantitative assessment of the AmeriGas Propane reporting unit using a weighting of the income and market approaches to determine its fair value. With respect to the income approach, management used a discounted cash flow (“DCF”) method, using unobservable inputs. The significant assumptions in our DCF model include projected gross margin, terminal growth rates, and a discount rate (and estimates in the discount rate inputs). With respect to the market approach, management used recent transaction market multiples for similar companies in the U.S. The resulting estimates of fair value from the income approach and the market approach were then weighted equally in determining the overall estimated fair value of AmeriGas Propane. Based on our evaluation, the estimated fair value of the reporting unit was determined to be less than its carrying value. As a result, the Company recorded a non-cash pre-tax goodwill impairment charge of $656, included in “Impairment of goodwill” on the Condensed Consolidated Statement of Income, to reduce the carrying value of AmeriGas Propane to its fair value. The Company calculated the deferred tax effect using the simultaneous equation method. The performance of the AmeriGas Propane reporting unit and the potential for future developments in the global economic environment, including the prospect of higher interest rates, introduces a heightened risk for additional impairment in the AmeriGas Propane reporting unit. If there is continued deterioration in the results of operations, a portion or all of the remaining recorded goodwill for the AmeriGas Propane reporting unit, which was $1.3 billion as of June 30, 2023, could be subject to further impairment. Impairment testing for long-lived assets (or an asset group) and definite lived intangible assets is required when circumstances indicate that such assets may be impaired. The impairment of AmeriGas Propane’s goodwill during the quarter ended June 30, 2023, was determined to be a triggering event requiring an interim impairment analysis of AmeriGas Propane’s long-lived and definite lived intangible assets. Accordingly, the Company performed a recoverability test of AmeriGas Propane’s long-lived assets, including right-of-use (“ROU”) assets and definite lived intangible assets, as of May 31, 2023, using estimated undiscounted cash flow projections expected to be generated over the remaining useful life of the primary asset of the asset group at the lowest level with identifiable cash flows that are independent of other assets. Based on the recoverability test performed, we determined that (1) AmeriGas Propane’s long-lived assets, including ROU assets and definite lived intangible assets, were recoverable and, as such, no impairment charges were recorded; and (2) no adjustments to the remaining useful lives were necessary.

Accounting Changes

Accounting Changes	9 Months Ended
	Jun. 30, 2023
Accounting Changes and Error Corrections [Abstract]
Accounting Changes	Note 3 — Accounting Changes New Accounting Standard Adopted in Fiscal 2023 Debt and Derivatives and Hedging. Effective October 1, 2022, the Company adopted ASU 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40).” 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. We adopted this ASU using the modified retrospective transition method and applied the new guidance to applicable features of our Equity Units. Periods prior to October 1, 2022 have not been restated. Upon adoption, we reclassified $6 from Common Stock to Preferred Stock associated with the previously separated equity-classified beneficial conversion feature, which was accounted for as a deemed dividend. The increase to Preferred Stock was partially offset by an increase of $1 to opening retained earnings for the previously recognized non-cash amortization of the beneficial conversion feature. The ASU 2020-06 also removes the presumption of cash settlement for contracts that may be settled in cash or shares. In accordance with the new guidance, we included the dilutive impact of the quarterly contract adjustment payment liability associated with the 2024 Purchase Contracts, which may be settled in cash or shares, in our computation of weighted average diluted common shares outstanding. The adoption of the new guidance did not, and is not expected to, have a material impact on our consolidated financial statements.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	9 Months Ended
	Jun. 30, 2023
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	Note 4 — Revenue from Contracts with Customers The Company recognizes revenue when control of promised goods or services is transferred to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. See Note 4 in the Company’s 2022 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, 2023 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 151 $ — $ — $ — $ — $ 151 $ — Commercial & Industrial 60 — — — — 60 — Large delivery service 39 — — — — 39 — Off-system sales and capacity releases 7 (7) — — — 14 — Other 8 — — — — 8 — Total Utility 265 (7) — — — 272 — Non-Utility: LPG: Retail 799 — 423 376 — — — Wholesale 76 — 24 52 — — — Energy Marketing 336 (14) — 156 194 — — Midstream: Pipeline 58 — — — 58 — — Peaking 1 (5) — — 6 — — Other 3 — — — 3 — — Electricity Generation 17 — — — 17 — — Other 65 — 47 18 — — — Total Non-Utility 1,355 (19) 494 602 278 — — Total revenues from contracts with customers 1,620 (26) 494 602 278 272 — Other revenues (b)(c) 39 1 20 9 1 6 2 Total revenues $ 1,659 $ (25) $ 514 $ 611 $ 279 $ 278 $ 2 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) Nine Months Ended June 30, 2023 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 911 $ — $ — $ — $ — $ 911 $ — Commercial & Industrial 369 — — — — 369 — Large delivery service 139 — — — — 139 — Off-system sales and capacity releases 84 (68) — — — 152 — Other 34 (1) — — — 35 — Total Utility 1,537 (69) — — — 1,606 — Non-Utility: LPG: Retail 3,243 — 1,812 1,431 — — — Wholesale 287 — 120 167 — — — Energy Marketing 1,854 (130) — 755 1,229 — — Midstream: Pipeline 189 — — — 189 — — Peaking 28 (102) — — 130 — — Other 10 — — — 10 — — Electricity Generation 27 — — — 27 — — Other 207 — 151 56 — — — Total Non-Utility 5,845 (232) 2,083 2,409 1,585 — — Total revenues from contracts with customers 7,382 (301) 2,083 2,409 1,585 1,606 — Other revenues (b)(c) 142 (1) 64 27 1 38 13 Total revenues $ 7,524 $ (302) $ 2,147 $ 2,436 $ 1,586 $ 1,644 $ 13 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 (a) Includes intersegment revenues principally among Midstream & Marketing, Utilities and AmeriGas Propane. (b) Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, revenues from alternative revenue programs at Utilities and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP. (c) Includes the impact of the weather normalization adjustment rider, a five-year pilot program beginning on November 1, 2022 for PA Gas Utility. See Note 7 for additional information. Contract Balances The timing of revenue recognition may differ from the timing of invoicing to customers or cash receipts. Contract assets represent our right to consideration after the performance obligations have been satisfied when such right is conditioned on something other than the passage of time. Contract assets were not material 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 $133, $164 and $128 at June 30, 2023, September 30, 2022 and June 30, 2022, 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, 2023 and 2022, from the amounts included in contract liabilities at September 30, 2022 and 2021, were $118 and $117, 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, 2023, Midstream & Marketing and Utilities expect to record approximately $2.2 billion and $0.2 billion of revenues, respectively, related to the minimum future performance obligations over the remaining terms of the related contracts.

Dispositions and Acquisition

Dispositions and Acquisition	9 Months Ended
	Jun. 30, 2023
Business Combination and Asset Acquisition [Abstract]
Dispositions and Acquisition	Note 5 — Dispositions and Acquisition UGI International Energy Marketing Businesses Sale of U.K. Energy Marketing Business. On October 21, 2022, UGI International, through a wholly-owned subsidiary, sold its natural gas marketing business located in the U.K. for a net cash payment of $19 which includes certain working capital adjustments. In conjunction with the sale, during the first quarter of Fiscal 2023, the Company recorded a pre-tax loss of $215 ($151 after-tax) substantially all of which loss was due to the non-cash transfer of commodity derivative instruments associated with the business. At the date of closing of the sale, these commodity derivative instruments had a net carrying value of $206 which is attributable to net unrealized gains on such instruments. At September 30, 2022, these derivative instruments were classified as held for sale assets and liabilities on the Condensed Consolidated Balance Sheet and had a net carrying value of $276. The change in the carrying value of these derivative instruments between September 30, 2022 and October 21, 2022 resulted from changes in their fair values during that period. Other UGI International Energy Marketing Businesses. In November 2022, the Company announced that it expected to sign a definitive agreement during the first quarter of Fiscal 2023 to sell its energy marketing business in France. In December 2022, the Company announced that it no longer expected to sign such agreement as extended negotiations with the potential buyer had been discontinued. During the first quarter of Fiscal 2023, the Company recorded a $19 pre-tax impairment charge to reduce the carrying values of certain assets associated with its energy marketing business in the Netherlands, comprising property, plant and equipment and intangible assets. The impairment charge is reflected in “Operating and administrative expenses” on the Condensed Consolidated Statement of Income and included in the UGI International reportable segment. On July 8, 2023, UGI International, through a wholly-owned subsidiary, entered into a definitive agreement to sell a substantial portion of its energy marketing business located in Belgium, principally comprising customer contracts and prepaid broker fees. The assets associated with the pending sale were not material at June 30, 2023 and have been classified as “Held for sale assets” on the Condensed Consolidated Balance Sheet as of June 30, 2023. The initially estimated cash proceeds, less a payment to the buyer, on or subsequent to the closing date, pursuant to the definitive agreement is not expected to be material. The cash payment to buyer is equal to an agreed upon portion of the fair value, as of the closing date, of associated derivative commodity hedge contracts currently held by UGI International. The closing of the pending sale is subject to regulatory and other third-party approvals and is expected to occur during the fourth quarter of Fiscal 2023. On August 1, 2023, UGI International, through a wholly-owned subsidiary, entered into a definitive agreement to sell a substantial portion of its energy marketing business located in France, principally comprising customer contracts, energy certificates and substantially all of its derivative commodity hedge contracts, for an initially estimated net cash payment to the buyer of €23. This initially estimated closing date payment is subject to adjustments relating to, among other things, the actual date of closing, the fair value of derivative commodity hedge contracts currently held by the Company but not subject to transfer to the buyer, and conditions associated with certain customer contracts. The effects of these adjustments will be settled on, or subsequent to, the closing date. The closing of the pending sale is subject to regulatory and other third-party approvals and is expected to occur during the first quarter of Fiscal 2024. The assets and liabilities associated with the energy marketing business in France, principally comprising the fair values of substantially all of its derivative commodity hedge contracts, have been classified as “Held for sale assets ” and “Held for sale liabilities” on the Condensed Consolidated Balance Sheet as of June 30, 2023. The net fair value of these derivative commodity hedge contracts at June 30, 2023 was an asset of $10. The amount of the gain or loss to be recognized upon the closing of these transactions will depend, in large part, on the fair values of the associated derivative commodity hedge contracts as of the respective dates of closing. The Company’s policy for the recognition of impairment charges is limited to the disposal group’s long-lived assets related to held for sale. The Company did not recognize any such impairment for the period ended June 30, 2023. The Company continues to pursue the wind-down of its energy marketing business located in the Netherlands and its remaining natural gas marketing business in France. On July 21, 2023, DVEP signed a definitive agreement to sell a substantial portion of its power purchase agreement portfolio for a net cash payment to the buyer. Such payment is not expected to be material. The closing of the pending sale is subject to regulatory and other third-party approvals and is expected to occur during the first half of Fiscal 2024. Acquisition of Assets Stonehenge . On January 27, 2022, UGI, through Energy Services, completed the Stonehenge Acquisition in which Energy Services acquired all of the equity interests in Stonehenge for total cash consideration of approximately $190. The Stonehenge business includes a natural gas gathering system, located in western Pennsylvania, with more than 47 miles of pipeline and associated compression assets. The Stonehenge Acquisition is consistent with our growth strategies, including expanding our midstream natural gas gathering assets within the Appalachian basin production region. The Stonehenge Acquisition was funded using available cash. This transaction has been accounted for as an acquisition of assets, and the purchase price has been primarily allocated to property, plant and equipment. We refer to Stonehenge and its assets as “UGI Moraine East.”

Inventories

Inventories	9 Months Ended
	Jun. 30, 2023
Inventory Disclosure [Abstract]
Inventories	Note 6 — Inventories Inventories comprise the following: June 30, September 30, June 30, Non-utility LPG and natural gas $ 189 $ 335 $ 261 Gas Utility natural gas 37 166 84 Energy certificates 68 70 70 Materials, supplies and other 116 94 81 Total inventories $ 410 $ 665 $ 496

Utility Regulatory Assets and L

Utility Regulatory Assets and Liabilities and Regulatory Matters	9 Months Ended
	Jun. 30, 2023
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 2022 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 $ 95 $ 83 $ 151 Underfunded pension plans 118 114 103 Environmental costs 28 37 34 Deferred fuel and power costs 30 32 14 Removal costs, net 22 22 22 Other 57 52 47 Total regulatory assets $ 350 $ 340 $ 371 Regulatory liabilities (a): Postretirement benefit overcollections $ 10 $ 11 $ 12 Deferred fuel and power refunds 63 3 1 State tax benefits — distribution system repairs 40 38 34 Excess federal deferred income taxes 260 279 281 Other 3 4 8 Total regulatory liabilities $ 376 $ 335 $ 336 (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, PGA rates and DS tariffs. These clauses provide for periodic adjustments to PGC, PGA and DS rates for differences between the total amount of purchased gas and electric generation supply costs collected from customers and recoverable costs incurred. Net undercollected costs are classified as a regulatory asset and net overcollections are classified as a regulatory liability. The WVPSC, in an effort to mitigate the impact of WV Gas Utility’s 2022 PGA rate increase to customers, delayed the effective date in 2022 from November 1 to December 1 and deferred $12 of unrecovered gas costs in determining the rates to be charged to the various customer classes effective December 1, 2022. Additionally, in order to lower winter bills for residential customers, the WVPSC removed transportation and storage costs from the volumetric rate and created a fixed monthly pipeline demand charge applicable only to residential customers. On April 12, 2023, the WVPSC issued a final Order that increased the PGA rate, which included the unrecovered gas cost balance initially deferred in the interim order, and continued the fixed monthly demand charge for residential customers. PA Gas Utility uses derivative instruments to reduce volatility in the cost of gas it purchases for retail core-market customers. Realized and unrealized gains or losses on natural gas derivative instruments are included in deferred fuel and power costs or refunds. Net unrealized (losses) gains on such contracts at June 30, 2023, September 30, 2022 and June 30, 2022 were $(7), $5 and $7, respectively. Other Regulatory Matters UGI Utilities. On January 27, 2023, Electric Utility filed a request with the PAPUC to increase its annual base distribution revenues by $11. The increased revenues would fund ongoing system improvements and operations necessary to maintain safe and reliable electric service. Electric Utility requested that the new electric rates become effective March 28, 2023. The PAPUC issued an order on March 2, 2023, suspending the effective date for the rate increase to allow for investigation and public hearings. On July 14, 2023, a Joint Petition for Approval of Settlement of all issues supported by all active parties was filed with the PAPUC providing for a $9 annual base distribution rate increase for Electric Utility. The Joint Petition is subject to receipt of a recommended decision and a final order of the PAPUC approving the settlement. In accordance with the terms of the Joint Petition, the proposed rate increase will become effective on or before October 1, 2023, or as directed by the PAPUC in the final order. The Company cannot predict the timing or the ultimate outcome of the rate case review process. On January 28, 2022, PA Gas Utility filed a request with the PAPUC to increase its base operating revenues for residential, commercial and industrial customers by $83 annually. On September 15, 2022, the PAPUC issued a final order approving a settlement providing for a $49 annual base distribution rate increase for PA Gas Utility, through a phased approach, with $38 beginning October 29, 2022 and an additional $11 beginning October 1, 2023. In accordance with the terms of the final order, PA Gas Utility will not be permitted to file a rate case prior to January 1, 2024. Also in accordance with the terms of the final order, PA Gas Utility was authorized to implement a weather normalization adjustment rider as a five-year pilot program beginning on November 1, 2022. Under this rider, when weather deviates from normal by more than 3%, residential and small commercial customer billings for distribution services are adjusted monthly for weather related impacts exceeding the 3% threshold. Additionally, under the terms of the final order, PA Gas Utility was authorized to implement a DSIC once its total property, plant and equipment less accumulated depreciation reached $3,368 (which threshold was achieved in September 2022). On February 8, 2021, Electric Utility filed a request with the PAPUC to increase its annual base distribution revenues by $9. On October 28, 2021, the PAPUC issued a final Order approving a settlement that permitted Electric Utility, effective November 9, 2021, to increase its base distribution revenues by $6. Mountaineer. On July 31, 2023, Mountaineer submitted its 2023 IREP filing to the WVPSC requesting recovery of $10 for costs associated with capital investments after December 31, 2022, that total $131, including $67 in calendar year 2024. With new base rates expected to be effective January 1, 2024, revenues from IREP rates would decrease by $12. The filing included capital investments totaling $383 over the 2024 - 2028 period. On July 28, 2023, Mountaineer submitted its annual PGA filing with the WVPSC. This filing allows the WVPSC to review the prudence of Mountaineer’s incurred gas costs, to review the computation of any over or under collection of gas costs, and to establish a PGA billing rate for the upcoming year. The new PGA billing rate is intended to settle past over or under collections and allows Mountaineer to recover its projected gas costs for the upcoming year. On March 6, 2023, Mountaineer submitted a base rate case filing with the WVPSC seeking a net revenue increase of $20, which consists of an increase in base rates of $38 and a decrease in the IREP rates of $18 annually to be effective on April 5, 2023. On March 31, 2023, the WVPSC suspended the effective date of the requested rate change increase until January 1, 2024 to allow for a full review of the filing.

Debt

Debt	9 Months Ended
	Jun. 30, 2023
Debt Disclosure [Abstract]
Debt	Note 8 — Debt AmeriGas Partners Senior Notes. On May 31, 2023, AmeriGas Partners and AmeriGas Finance Corp. issued $500 principal amount of 9.375% Senior Notes due May 2028. The 9.375% Senior Notes rank equally with AmeriGas Partners’ existing and future outstanding senior notes. The net proceeds from the issuance of the 9.375% Senior Notes, together with cash on hand, a $150 cash contribution from the Company and other sources of liquidity, were used for the early repayment, pursuant to a tender offer and notice of redemption, of all AmeriGas Partners 5.625% Senior Notes having an aggregate principal balance of $675, plus tender premiums and accrued and unpaid interest. In conjunction with the early repayment of the 5.625% Senior Notes, in June 2023 the Partnership recognized a pre-tax loss of $9 primarily comprising tender premiums and the write-off of unamortized debt issuance costs, which is reflected in “Loss on extinguishments of debt” on the Condensed Consolidated Statement of Income. The 9.375% Senior Notes are redeemable at the issuers’ option prior to June 2025 at a make whole premium or, on or after June 2025, at a call premium that declines from 4.688% to 0% depending on the year of redemption. The 9.375% Senior Notes indenture contains customary covenants and default provisions that limit AmeriGas Partners’ ability to, among other things: incur additional indebtedness; create or incur liens; engage in transactions with affiliates; engage in mergers or consolidations or sell all or substantially all of the issuers’ assets; make restricted payments, loans and investments; enter into business combinations and sell assets; and engage in other lines of business. 2022 AmeriGas OLP Credit Agreement. Under the 2022 AmeriGas OLP Credit Agreement, AmeriGas OLP, as borrower, is required to comply with financial covenants related to leverage and interest coverage measured at the Partnership and at AmeriGas OLP. The 2022 AmeriGas OLP Credit Agreement contains an equity cure provision, which allows AmeriGas OLP’s direct or indirect parent, including UGI and its other subsidiaries, to fund capital contributions to eliminate any EBITDA (as defined in the 2022 AmeriGas OLP Credit Agreement) shortfalls that would otherwise result in non-compliance with these financial covenants. Each equity cure is eligible to eliminate such EBITDA shortfalls up to four quarters after contribution. We are permitted to use the equity cure provision five times over the course of the Credit Agreement, twice during any rolling four-quarter period, and not in consecutive quarters. As of March 31, 2023, AmeriGas OLP was in breach of the leverage ratio debt covenant and interest coverage ratio, which it cured with the funds received from UGI. UGI made capital contributions to AmeriGas OLP of $20 and $11 on March 31, 2023 and April 24, 2023, respectively, which in aggregate represented one equity cure in accordance with the 2022 AmeriGas OLP Credit Agreement. As a result of these capital contributions, AmeriGas OLP and the Partnership were in compliance with all financial covenants after consideration of the equity cure provision as of June 30, 2023 and March 31, 2023. UGI also provided an irrevocable letter of support whereby UGI has committed to fund any such EBITDA shortfalls and debt service, if any. Based on the support and the projected EBITDA, AmeriGas OLP is expected to remain in compliance with its financial debt covenants for the succeeding twelve-month period. In addition, in May 2023, the Company contributed $52 in an equity contribution principally to fund debt service on the senior notes. UGI International 2023 Credit Facilities Agreement. On March 7, 2023, UGI International, LLC and its indirect wholly-owned subsidiary, UGI International Holdings B.V., entered into the UGI International 2023 Credit Facilities Agreement, a five-year unsecured senior facilities agreement, maturing March 7, 2028, with a consortium of banks. The UGI International 2023 Credit Facilities Agreement consists of (1) a €300 variable-rate term loan facility ("Facility A") and (2) a €500 multicurrency revolving credit facility, including a €100 sublimit for swingline loans ("Facility B"). We have designated borrowings under Facility A as a net investment hedge. In connection with the entering into of the UGI International 2023 Credit Facilities Agreement, UGI International, LLC paid off in full and terminated the UGI International Credit Facilities Agreement, dated as of October 18, 2018. The net proceeds from the UGI International 2023 Credit Facilities Agreement were used to refinance the UGI International Credit Facilities Agreement. Borrowings under the multicurrency revolving credit facility may be used to finance the working capital needs of UGI International, LLC and its subsidiaries and for general corporate purposes. Borrowings under Facility A bear interest at the euro interbank offered rate plus the applicable margin and borrowings under Facility B bear interest at the daily non-cumulative compounded Reference Rate Terms, as defined in the Agreement, plus the applicable margin. The applicable margin for Facility A ranges from 1.70% to 3.35%, and for Facility B from 1.35% to 3.35%, and are dependent on the total net leverage ratio of UGI International, LLC and its subsidiaries on a consolidated basis. UGI International, LLC entered into an interest rate swap, effective March 31, 2023, that fixes the underlying market-based interest rate on Facility A at 3.10% through March 2026. The UGI International 2023 Credit Facilities Agreement requires UGI International, LLC to maintain a consolidated net leverage ratio of not more than 3.85 to 1.00, provided the maximum ratio permitted may be increased to 4.25 to 1.00 for two consecutive testing dates following a permitted acquisition. UGI Energy Services Credit Agreement. On May 12, 2023, Energy Services entered into the second amendment to the UGI Energy Services Credit Agreement, which provides that the Term SOFR rate (as defined in the UGI Energy Services Credit Agreement) shall replace LIBOR as a reference rate. After giving effect to the second amendment, the UGI Energy Services Credit Agreement shall bear interest at a floating rate of, at Energy Services’ option, either (i) Term SOFR plus the Applicable Rate (as defined in the UGI Energy Services Credit Agreement) plus a credit spread adjustment of 0.10%, or (ii) the base rate plus the applicable margin that is based on the leverage of Energy Services. Energy Services Amended Term Loan Credit Agreement. On February 23, 2023, Energy Services entered into the Energy Services Amended Term Loan Credit Agreement, the first amendment to the Energy Services Term Loan Credit Agreement, dated August 13, 2019. The Energy Services Amended Term Loan Credit Agreement provides, among other items, that (i) the outstanding principal amount of the loans will be increased by $125 to $800, (ii) the maturity date of the loans shall be extended to February 22, 2030, (iii) Term SOFR (as defined in the Energy Services Amended Term Loan Credit Agreement) shall replace LIBOR as a reference rate and (iv) borrowings under the Energy Services Amended Term Loan Credit Agreement shall bear interest at a floating rate of, at Energy Services’ option, either (x) Term SOFR plus the applicable margin plus a credit spread adjustment of 0.10% or (y) the base rate, as defined in the Agreement, plus the applicable margin. The applicable margin shall be 3.25% per annum for Term SOFR loans and 2.25% per annum for base rate loans. Borrowings under the Energy Services Amended Term Loan Credit Agreement are payable in equal quarterly installments of $2, commencing in March 2023, with the balance of the principal being due and payable in full at maturity. The Energy Services Amended Term Loan Credit Agreement contains customary covenants and default provisions and requires compliance with certain financial covenants including a minimum debt service coverage ratio as defined in the Agreement. On March 1, 2023, in connection with the Energy Services Amended Term Loan Credit Agreement, Energy Services terminated and settled its existing interest rate swap derivative instrument associated with the Energy Services Term Loan Credit Agreement at a $32 gain. This gain has been deferred in AOCI and is being amortized to interest expense over the remaining term of the initial interest rate swap ending July 2024. Energy Services entered into a new interest rate swap, effective March 31, 2023, that fixes the underlying market-based interest rate on this variable-rate term loan at 4.53% through September 2026. UGI Utilities Credit Agreement. On December 13, 2022, UGI Utilities entered into an amendment to the UGI Utilities Credit Agreement, providing for borrowings up to $425 and to replace the use of LIBOR with Term SOFR. Borrowings under the amended UGI Utilities Credit Agreement can be used to finance the working capital needs of UGI Utilities and for general corporate purposes. The UGI Utilities Credit Agreement is scheduled to expire June 2024. Borrowings under the amended UGI Utilities Credit Agreement bear interest, subject to our election, at a floating rate of either (i) Term SOFR plus the applicable margin plus a credit spread adjustment of 0.10% or (ii) the base rate plus the applicable margin. The applicable margin remains unchanged from the original credit agreement. Mountaineer Credit Agreement. On October 20, 2022, Mountaineer entered into the Mountaineer 2023 Credit Agreement, with a group of lenders. The Mountaineer 2023 Credit Agreement amends and restates a previous credit agreement and provides for borrowings up to $150, including a $20 sublimit for letters of credit. Mountaineer may request an increase in the amount of loan commitments to a maximum aggregate amount of $250, subject to certain terms and conditions. Borrowings under the Mountaineer 2023 Credit Agreement can be used to finance the working capital needs of Mountaineer and for general corporate purposes. The Mountaineer 2023 Credit Agreement is scheduled to expire in November 2024, with an option to extend the maturity date. Borrowings under the Mountaineer 2023 Credit Agreement bear interest, subject to our election, at either (i) the base rate, defined as the highest of (a) the prime rate, (b) the federal funds rate plus 0.50% and (c) the adjusted Term SOFR rate for a one-month tenor plus 1%, in each case, plus the applicable margin or (ii) the adjusted Term SOFR rate plus the applicable margin. The applicable margin for base rate loans ranges from 0% to 1.25%, and for Term SOFR loans from 1.00% to 2.25%, depending on the debt rating of Mountaineer. The adjusted Term SOFR rate is defined as the Term SOFR reference rate for the selected interest period, plus 0.10% per annum for a one-month interest period, 0.15% per annum for a three-month interest period, or 0.25% per annum for a six-month interest period. The Mountaineer Credit Agreement contains customary covenants and default provisions and requires compliance with certain financial covenants including a maximum leverage ratio and a minimum interest coverage ratio as defined in the agreement. UGI Corporation Credit Agreement . On May 12, 2023, the Company entered into the second amendment to the UGI Corporation Credit Agreement, which provides that the Term SOFR rate (as defined in the UGI Corporation Credit Agreement) shall replace LIBOR as a reference rate. After giving effect to the second amendment, the UGI Corporation Credit Agreement shall bear interest at a floating rate of, at the Company’s option, either (i) Term SOFR plus the Applicable Rate (as defined in the UGI Corporation Credit Agreement) plus a credit spread adjustment of 0.10%, or (ii) the base rate plus the applicable margin that will be based on the leverage of the Company or credit ratings assigned to certain indebtedness of the Company.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Jun. 30, 2023
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. At June 30, 2023, September 30, 2022 and June 30, 2022, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the COA totaled $52, $53 and $51, 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, 2023, the Partnership has an undiscounted environmental remediation liability of $8 related to the site. Our share of the actual remediation costs could be significantly more or less than the accrued amount. Other Matters West Reading, Pennsylvania Explosion . On March 24, 2023, an explosion occurred in West Reading, Pennsylvania which resulted in seven fatalities, significant injuries to eleven others, and extensive property damage to buildings owned by R.M. Palmer, a local chocolate manufacturer, and other neighboring structures. The NTSB, OSHA and the PAPUC are investigating the West Reading incident. On July 18, 2023, the NTSB issued an Investigative Update in its ongoing investigation. That report identifies a fracture in a retired UGI gas service tee and a fracture in a nearby steam system, but it does not address causation of the fractures or the explosion. The NTSB investigative team includes representatives from the Company, the PAPUC, the local fire department and the Pipeline and Hazardous Materials Safety Administration. The Company is cooperating with the investigation. The NTSB may invite other parties to participate. While the investigation into this incident is still underway and the cause of the explosion has not been determined, the Company has received claims as a result of the explosion and is involved in lawsuits relative to the incident. The Company maintains liability insurance for personal injury, property and casualty damages and believes that third-party claims associated with the explosion, in excess of the Company’s deductible, are recoverable through the Company’s insurance. The Company cannot predict the result of these pending or future claims and legal actions at this time. In addition to the matters described above, there are other pending claims and legal actions arising in the normal course of our businesses. Although we cannot predict the final results of these pending claims and legal actions, including those described above, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our financial statements.

Defined Benefit Pension and Oth

Defined Benefit Pension and Other Postretirement Plans	9 Months Ended
	Jun. 30, 2023
Retirement Benefits [Abstract]
Defined Benefit Pension and Other Postretirement Plans	Note 10 — Defined Benefit Pension and Other Postretirement Plans The Company maintains defined benefit pension 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 components, net of amounts capitalized by Utilities as a regulatory asset, are reflected in “Other non-operating income (expense), net” on the Condensed Consolidated Statements of Income. Other postretirement benefit cost was not material for all periods presented. Net periodic pension benefit includes the following components: Pension Benefits Three Months Ended June 30, 2023 2022 Service cost $ 2 $ 4 Interest cost 9 6 Expected return on assets (11) (12) Amortization of: Actuarial (gain) loss (1) 2 Net benefit $ (1) $ — Nine Months Ended June 30, 2023 2022 Service cost $ 7 $ 12 Interest cost 26 19 Expected return on plan assets (34) (37) Amortization of: Actuarial (gain) loss (2) 6 Net benefit $ (3) $ —

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Jun. 30, 2023
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, 2023: Derivative instruments: Assets: Commodity contracts (c) $ 146 $ 111 $ — $ 257 Foreign currency contracts $ — $ 18 $ — $ 18 Interest rate contracts $ — $ 30 $ — $ 30 Liabilities: Commodity contracts (c) $ (242) $ (224) $ — $ (466) Foreign currency contracts $ — $ (4) $ — $ (4) Interest rate contracts $ — $ (4) $ — $ (4) Non-qualified supplemental postretirement grantor trust investments (a) $ 40 $ — $ — $ 40 September 30, 2022: Derivative instruments: Assets: Commodity contracts (b) $ 938 $ 1,268 $ 27 $ 2,233 Foreign currency contracts $ — $ 119 $ — $ 119 Interest rate contracts $ — $ 66 $ — $ 66 Liabilities: Commodity contracts (b) $ (377) $ (136) $ — $ (513) Foreign currency contracts $ — $ (2) $ — $ (2) Non-qualified supplemental postretirement grantor trust investments (a) $ 43 $ — $ — $ 43 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 (a) Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans. (b) Includes derivative assets and liabilities associated with the October 2022 sale of the U.K. energy marketing business classified as held for sale (see Note 5). (c) Includes derivative assets and liabilities associated with certain UGI International energy marketing businesses classified as held for sale (see Note 5). The fair values of our Level 1 exchange-traded commodity futures and option contracts and non-exchange-traded commodity futures and forward contracts are based upon actively quoted market prices for identical assets and liabilities. Substantially all of the remaining derivative instruments are designated as Level 2. The fair values of certain non-exchange-traded commodity derivatives designated as Level 2 are based upon indicative price quotations available through brokers, industry price publications or recent market transactions and related market indicators. The fair values of our Level 2 interest rate contracts and foreign currency contracts are based upon third-party quotes or indicative values based on recent market transactions. The fair values of our Level 3 natural gas commodity contracts at September 30, 2022 attributable to our UGI International operations have been determined using unobservable inputs in an illiquid market and ranged from $7 to $27 given the available inputs considered. The fair values of investments held in grantor trusts are derived from quoted market prices as substantially all of the investments in these trusts have active markets. Nonrecurring Fair Value Measurements During the quarter ended June 30, 2023, the Company performed an interim goodwill impairment test for its AmeriGas Propane reporting unit, which resulted in a non-cash pre-tax goodwill impairment charge of $656 to reduce the carrying value of AmeriGas Propane to its fair value as of May 31, 2023. See Note 2 for further information on the results of the impairment test including the key assumptions used to determine the fair value of the AmeriGas Propane reporting unit. Other Financial Instruments The carrying amounts of other financial instruments included in current assets and current liabilities (except for current maturities of long-term debt) approximate their fair values because of their short-term nature. We estimate the fair value of long-term debt by using current market rates and by discounting future cash flows using rates available for similar type debt (Level 2). The carrying amounts and estimated fair values of our long-term debt (including current maturities but excluding unamortized debt issuance costs) were as follows: June 30, 2023 September 30, 2022 June 30, 2022 Carrying amount $ 6,682 $ 6,665 $ 6,483 Estimated fair value $ 6,318 $ 6,189 $ 6,145

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	9 Months Ended
	Jun. 30, 2023
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 sections summarize the types of derivative instruments used by the Company to manage these market risks. Commodity Price Risk Regulated Utility Operations Natural Gas PA Gas Utility’s tariffs contain clauses that permit recovery of all prudently incurred costs of natural gas it sells to retail core-market customers, including the cost of financial instruments used to hedge purchased gas costs. As permitted and agreed to by the PAPUC pursuant to PA Gas Utility’s annual PGC filings, PA Gas Utility currently uses NYMEX natural gas futures and option contracts to reduce commodity price volatility associated with a portion of the natural gas it purchases for its retail core-market customers. See Note 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, 2023, the amount of pre-tax net gains associated with interest rate hedges expected to be reclassified into earnings during the next twelve months is $49. Foreign Currency Exchange Rate Risk Forward Foreign Currency Exchange Contracts In order to reduce the volatility in net income associated with our foreign operations, principally as a result of changes in the USD exchange rate to the euro and British pound sterling, we enter into forward foreign currency exchange contracts. We layer in these foreign currency exchange contracts over multi-year periods to eventually equal approximately 90% of anticipated UGI International foreign currency earnings before income taxes. Because these contracts are not designated as hedging instruments, realized and unrealized gains and losses on these contracts are recorded in “Other non-operating income (expense), 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 (losses) gains associated with these net investment hedges in the cumulative translation adjustment component in AOCI of $(7) and $41 during the three months ended June 30, 2023 and 2022, respectively, and $(80) and $75 during the nine months ended June 30, 2023 and 2022, 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, 2023, September 30, 2022 and June 30, 2022, and the final settlement dates of the Company's open derivative contracts as of June 30, 2023, but excluding those derivatives that qualified for the NPNS exception: Notional Amounts Type Units Settlements Extending Through June 30, 2023 September 30, 2022 June 30, 2022 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms February 2024 24 19 13 Non-utility Operations LPG swaps Gallons September 2025 734 874 669 Natural gas futures, forward, basis swap, options and pipeline contracts (a) Dekatherms October 2027 357 363 353 Electricity forward and futures contracts Kilowatt hours December 2026 1,586 2,446 2,621 Interest Rate Risk: Interest rate swaps Euro March 2026 € 300 € 300 € 300 Interest rate swaps USD September 2026 $ 1,274 $ 1,358 $ 1,411 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD September 2026 $ 434 $ 465 $ 435 Net investment hedge forward foreign exchange contracts Euro December 2026 € 256 € 411 € 411 (a) Amounts at June 30, 2023 and September 30, 2022 include contracts associated with certain UGI International energy marketing businesses classified as held for sale (see Note 5). Derivative Instrument Credit Risk We are exposed to risk of loss in the event of nonperformance by our derivative instrument counterparties. Our derivative instrument counterparties principally comprise large energy companies and major U.S. and international financial institutions. We maintain credit policies with regard to our counterparties that we believe reduce overall credit risk. These policies include evaluating and monitoring our counterparties’ financial condition, including their credit ratings, and entering into agreements with counterparties that govern credit limits or entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. We have concentrations of credit risk associated with derivative instruments and we evaluate the creditworthiness of our derivative counterparties on an ongoing basis. As of June 30, 2023, the maximum amount of loss, based upon the gross fair values of the derivative instruments, we would incur if these counterparties failed to perform according to the terms of their contracts was $305. 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, 2023, we had received cash collateral from derivative instrument counterparties totaling $36. 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, 2023, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material. Offsetting Derivative Assets and Liabilities Derivative assets and liabilities are presented net by counterparty on the 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 $ 6 $ 57 $ 28 Interest rate contracts 30 66 44 36 123 72 Derivatives subject to PGC and DS mechanisms: Commodity contracts 11 31 30 Derivatives not designated as hedging instruments: Commodity contracts (a) 246 2,202 1,935 Foreign currency contracts 12 62 31 258 2,264 1,966 Total derivative assets — gross 305 2,418 2,068 Gross amounts offset in the balance sheet (134) (295) (226) Cash collateral received (36) (398) (659) Total derivative assets — net $ 135 $ 1,725 $ 1,183 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts (4) — — Derivatives subject to PGC and DS mechanisms: Commodity contracts (18) (26) (23) Derivatives not designated as hedging instruments: Commodity contracts (a) (448) (487) (338) Foreign currency contracts (4) (2) (2) (452) (489) (340) Total derivative liabilities — gross (474) (515) (363) Gross amounts offset in the balance sheet 134 295 226 Cash collateral pledged 137 7 13 Total derivative liabilities — net $ (203) $ (213) $ (124) (a) Amounts at June 30, 2023 and September 30, 2022 include contracts associated with certain UGI International energy marketing businesses classified as held for sale (see Note 5). 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) Gain (Loss) Location of Gain (Loss) Reclassified from Cash Flow Hedges: 2023 2022 2023 2022 Interest rate contracts $ 32 $ 11 $ 14 $ (4) Interest expense Net Investment Hedges: Foreign currency contracts $ (5) $ 23 Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2023 2022 Location of Gain (Loss) Recognized in Income Commodity contracts $ 1 $ (6) Revenues Commodity contracts (224) 466 Cost of sales Commodity contracts (10) 6 Other operating income, net Foreign currency contracts (2) 17 Other non-operating income (expense), net Total $ (235) $ 483 Nine Months Ended June 30,: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from Cash Flow Hedges: 2023 2022 2023 2022 Interest rate contracts $ 15 $ 59 $ 28 $ (17) Interest expense Net Investment Hedges: Foreign currency contracts $ (28) $ 34 Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2023 2022 Location of Gain (Loss) Recognized in Income Commodity contracts $ 11 $ (5) Revenues Commodity contracts (1,893) 792 Cost of sales Commodity contracts (5) 6 Other operating income, net Foreign currency contracts (36) 32 Other non-operating income (expense), net Total $ (1,923) $ 825 We are also a party to a number of other contracts that have elements of a derivative instrument. However, these contracts qualify for NPNS exception accounting because they provide for the delivery of products or services in quantities that are expected to be used in the normal course of operating our business and the price in these contracts are based on an underlying that is directly associated with the price of the product or service being purchased or sold. These contracts include, among others, binding purchase orders, contracts that provide for the purchase and delivery, or sale, of energy products, and service contracts that require the counterparty to provide commodity storage, transportation or capacity service to meet our normal sales commitments.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	9 Months Ended
	Jun. 30, 2023
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, 2023 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — March 31, 2023 $ 14 $ 15 $ (270) $ (241) Other comprehensive income before reclassification adjustments — 22 8 30 Amounts reclassified from AOCI (1) (10) — (11) Other comprehensive (loss) income attributable to UGI (1) 12 8 19 AOCI — June 30, 2023 $ 13 $ 27 $ (262) $ (222) 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) Nine Months Ended June 30, 2023 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2022 $ 14 $ 37 $ (431) $ (380) Other comprehensive income before reclassification adjustments — 10 169 179 Amounts reclassified from AOCI (1) (20) — (21) Other comprehensive (loss) income attributable to UGI (1) (10) 169 158 AOCI — June 30, 2023 $ 13 $ 27 $ (262) $ (222) 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)

Segment Information

Segment Information	9 Months Ended
	Jun. 30, 2023
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 2022 Annual Report. Three Months Ended June 30, 2023 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 1,659 $ — $ 514 $ 611 $ 260 $ 270 $ 4 Intersegment revenues $ — $ (25) (b) $ — $ — $ 19 $ 8 $ (2) Cost of sales $ 1,104 $ (26) (b) $ 251 $ 418 $ 192 $ 118 $ 151 Operating (loss) income $ (732) $ — $ (8) $ 21 $ 40 $ 32 $ (817) Income from equity investees 1 — — — 1 — — Loss on extinguishment of debt (9) — — — — — (9) Other non-operating income (expense), net 1 — — 1 — 2 (2) (Loss) earnings before interest expense and income taxes (739) — (8) 22 41 34 (828) Interest expense (96) — (40) (10) (11) (20) (15) (Loss) income before income taxes $ (835) $ — $ (48) $ 12 $ 30 $ 14 $ (843) Depreciation and amortization $ 134 $ — $ 43 $ 30 $ 22 $ 38 $ 1 Capital expenditures (including the effects of accruals) $ 255 $ — $ 42 $ 27 $ 40 $ 146 $ — 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 $ — Nine Months Ended June 30, 2023 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 7,524 $ — $ 2,147 $ 2,436 $ 1,354 $ 1,575 $ 12 Intersegment revenues $ — $ (302) (b) $ — $ — $ 232 $ 69 $ 1 Cost of sales $ 6,358 $ (301) (b) $ 1,067 $ 1,713 $ 1,185 $ 873 $ 1,821 Operating (loss) income $ (1,681) $ — $ 240 $ 197 $ 249 $ 361 $ (2,728) Income (loss) from equity investees 2 — — (2) 4 — — Loss on extinguishment of debt (9) — — — — — (9) Other non-operating (loss) income, net (25) — — 21 — 6 (52) (Loss) earnings before interest expense and income taxes (1,713) — 240 216 253 367 (2,789) Interest expense (281) — (122) (26) (33) (62) (38) (Loss) income before income taxes $ (1,994) $ — $ 118 $ 190 $ 220 $ 305 $ (2,827) Depreciation and amortization $ 397 $ — $ 132 $ 86 $ 65 $ 112 $ 2 Capital expenditures (including the effects of accruals) $ 647 $ — $ 93 $ 84 $ 74 $ 396 $ — As of June 30, 2023 Total assets $ 15,243 $ (182) $ 3,443 $ 3,179 $ 3,050 $ 5,560 $ 193 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 (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, 2023 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 1 $ 1 Net losses on commodity derivative instruments not associated with current-period transactions Cost of sales $ (51) $ (87) $ (14) Net losses on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ (1) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ (6) $ — $ — Loss on extinguishment of debt Loss on extinguishments of debt $ (9) $ — $ — Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (2) $ — Loss associated with impairment of AmeriGas Propane goodwill Impairment of goodwill $ (656) $ — $ — 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 (expense), net $ — $ 14 $ — Impairments associated with certain equity method investments Income (loss) from equity investees $ — $ — $ (50) Nine Months Ended June 30, 2023 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 4 $ 7 Net losses on commodity derivative instruments not associated with current-period transactions Cost of sales $ (55) $ (1,491) $ (275) Net losses on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ (4) $ — Loss on extinguishment of debt Loss on extinguishments of debt $ (9) $ — $ — Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (52) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ (19) $ — $ — Loss on disposal of U.K. energy marketing business Loss on disposal of U.K. energy marketing business $ — $ (215) $ — Impairment of assets Operating and administrative expenses $ — $ (19) $ — Loss associated with impairment of AmeriGas Propane goodwill Impairment of goodwill $ (656) $ — $ — 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 gain on foreign currency derivative instruments Other non-operating income (expense), net $ — $ 19 $ — Impairments associated with certain equity method investments Income (loss) from equity investees $ — $ — $ (50) (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, Utilities and AmeriGas Propane.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Pay vs Performance Disclosure
Net (loss) income attributable to UGI Corporation	$ (789)	$ (7)	$ (1,633)	$ 829

Insider Trading Arrangements

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

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Jun. 30, 2023
Accounting Policies [Abstract]
Restricted Cash	Restricted Cash.
Earnings Per Common Share	Earnings Per Common Share.
Equity Method Investments	Equity Method Investments. We account for privately held equity securities of entities without readily determinable fair values in which we do not have control, but have significant influence over operating and financial policies, under the equity method. These are included in "Other assets" on the Condensed Consolidated Balance Sheets. Equity method earnings are included in "Income (loss) from equity investees" on the Condensed Consolidated Statements of Income. Our equity method investments primarily comprise MBL Bioenergy, Pine Run and other equity method investments in biomass and other renewable energy projects. MBL Bioenergy . The Company has an approximate 99.99% interest in MBL Bioenergy, a company jointly owned by UGI Dakota, LLC, Sevana Bioenergy and a subsidiary of California Bioenergy. The sole purpose of MBL Bioenergy is the development of RNG projects in South Dakota comprising three dairy waste anaerobic digester systems. MBL Bioenergy is a variable interest entity whereby the Company has determined that it is not the primary beneficiary since it does not direct the activities that most significantly impact the entity’s economic performance. The carrying value of our investment in MBL Bioenergy totaled $93 and $0 at June 30, 2023 and 2022, respectively. Pine Run. The Company has an approximately 49% interest in Pine Run, a company jointly owned by Stonehenge Energy Resources and UGI Pine Run LLC. Pine Run owns Pine Run Midstream, which operates dry gas gathering pipelines and compression assets in western Pennsylvania. The carrying value of our investment in Pine Run totaled $75 and $67 at June 30, 2023 and 2022, respectively. Pennant . At June 30, 2022, the carrying value of our investment in Pennant was $49. In connection with 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 then 47% membership interest, which was recorded in “Income (loss) from equity investees” in the Condensed Consolidated Statements of Income. During the fourth quarter of Fiscal 2022, UGI, through Energy Services, completed the Pennant Acquisition in which Energy Services acquired the remaining 53% of the equity interests in Pennant. The acquisition of the remaining interests was accounted for as an acquisition of assets, and the purchase price of approximately $61 was primarily allocated to property, plant and equipment. Other Equity Method Investments . The carrying values of our other equity method investments totaled $84 and $44 at June 30, 2023 and 2022, respectively, and principally comprise a number of investments in biomass and other renewable energy projects at Midstream & Marketing and a renewable energy joint venture at UGI International. Our maximum exposure to loss related to these investments is limited to the amount invested.
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 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.
Goodwill	Goodwill. We do not amortize goodwill, but test it at least annually for impairment at the reporting unit level. A reporting unit is an operating segment, or one level below an operating segment (a component) if it constitutes a business for which discrete financial information is available and regularly reviewed by segment management. Components are aggregated into a single reporting unit if they have similar economic characteristics. Each of our reporting units with goodwill is required to perform impairment tests annually or whenever events or circumstances indicate that the value of goodwill may be impaired. During the quarter ended June 30, 2023, the Company identified interim impairment indicators related to goodwill within the AmeriGas Propane reporting unit: (1) AmeriGas Partners issued $500 of Senior Notes at an interest rate of 9.375%, which was significantly higher than the interest rates on the other AmeriGas Propane debt obligations; and (2) financial projections for the AmeriGas Propane reporting unit were reduced significantly compared to previous forecasts following declines in gross margins and customer retention and higher operating expenses. The Company concluded that these events constituted triggering events that indicate that the AmeriGas Propane goodwill may be impaired and, as such, performed an interim impairment test of its goodwill as of May 31, 2023. Using level 3 inputs, we performed a quantitative assessment of the AmeriGas Propane reporting unit using a weighting of the income and market approaches to determine its fair value. With respect to the income approach, management used a discounted cash flow (“DCF”) method, using unobservable inputs. The significant assumptions in our DCF model include projected gross margin, terminal growth rates, and a discount rate (and estimates in the discount rate inputs). With respect to the market approach, management used recent transaction market multiples for similar companies in the U.S. The resulting estimates of fair value from the income approach and the market approach were then weighted equally in determining the overall estimated fair value of AmeriGas Propane. Based on our evaluation, the estimated fair value of the reporting unit was determined to be less than its carrying value. As a result, the Company recorded a non-cash pre-tax goodwill impairment charge of $656, included in “Impairment of goodwill” on the Condensed Consolidated Statement of Income, to reduce the carrying value of AmeriGas Propane to its fair value. The Company calculated the deferred tax effect using the simultaneous equation method. The performance of the AmeriGas Propane reporting unit and the potential for future developments in the global economic environment, including the prospect of higher interest rates, introduces a heightened risk for additional impairment in the AmeriGas Propane reporting unit. If there is continued deterioration in the results of operations, a portion or all of the remaining recorded goodwill for the AmeriGas Propane reporting unit, which was $1.3 billion as of June 30, 2023, could be subject to further impairment. Impairment testing for long-lived assets (or an asset group) and definite lived intangible assets is required when circumstances indicate that such assets may be impaired. The impairment of AmeriGas Propane’s goodwill during the quarter ended June 30, 2023, was determined to be a triggering event requiring an interim impairment analysis of AmeriGas Propane’s long-lived and definite lived intangible assets. Accordingly, the Company performed a recoverability test of AmeriGas Propane’s long-lived assets, including right-of-use (“ROU”) assets and definite lived intangible assets, as of May 31, 2023, using estimated undiscounted cash flow projections expected to be generated over the remaining useful life of the primary asset of the asset group at the lowest level with identifiable cash flows that are independent of other assets. Based on the recoverability test performed, we determined that (1) AmeriGas Propane’s long-lived assets, including ROU assets and definite lived intangible assets, were recoverable and, as such, no impairment charges were recorded; and (2) no adjustments to the remaining useful lives were necessary.
New Accounting Standard Adopted	New Accounting Standard Adopted in Fiscal 2023 Debt and Derivatives and Hedging. Effective October 1, 2022, the Company adopted ASU 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40).” 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. We adopted this ASU using the modified retrospective transition method and applied the new guidance to applicable features of our Equity Units. Periods prior to October 1, 2022 have not been restated. Upon adoption, we reclassified $6 from Common Stock to Preferred Stock associated with the previously separated equity-classified beneficial conversion feature, which was accounted for as a deemed dividend. The increase to Preferred Stock was partially offset by an increase of $1 to opening retained earnings for the previously recognized non-cash amortization of the beneficial conversion feature. The ASU 2020-06 also removes the presumption of cash settlement for contracts that may be settled in cash or shares. In accordance with the new guidance, we included the dilutive impact of the quarterly contract adjustment payment liability associated with the 2024 Purchase Contracts, which may be settled in cash or shares, in our computation of weighted average diluted common shares outstanding. The adoption of the new guidance did not, and is not expected to, have a material impact on our consolidated financial statements.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Jun. 30, 2023
Accounting Policies [Abstract]
Schedule of 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 $ 260 $ 670 Restricted cash 78 14 Cash, cash equivalents and restricted cash $ 338 $ 684
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 $ 260 $ 670 Restricted cash 78 14 Cash, cash equivalents and restricted cash $ 338 $ 684
Schedule of 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 2023 2022 2023 2022 Denominator (thousands of shares): Weighted-average common shares outstanding — basic 209,706 210,190 209,811 209,992 Incremental shares issuable for stock options, common stock awards and Equity Units (a) — — — 5,973 Weighted-average common shares outstanding — diluted 209,706 210,190 209,811 215,965

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	9 Months Ended
	Jun. 30, 2023
Revenue from Contract with Customer [Abstract]
Schedule of Disaggregated Revenues by Reportable Segment	The following tables present our disaggregated revenues by reportable segment: Three Months Ended June 30, 2023 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 151 $ — $ — $ — $ — $ 151 $ — Commercial & Industrial 60 — — — — 60 — Large delivery service 39 — — — — 39 — Off-system sales and capacity releases 7 (7) — — — 14 — Other 8 — — — — 8 — Total Utility 265 (7) — — — 272 — Non-Utility: LPG: Retail 799 — 423 376 — — — Wholesale 76 — 24 52 — — — Energy Marketing 336 (14) — 156 194 — — Midstream: Pipeline 58 — — — 58 — — Peaking 1 (5) — — 6 — — Other 3 — — — 3 — — Electricity Generation 17 — — — 17 — — Other 65 — 47 18 — — — Total Non-Utility 1,355 (19) 494 602 278 — — Total revenues from contracts with customers 1,620 (26) 494 602 278 272 — Other revenues (b)(c) 39 1 20 9 1 6 2 Total revenues $ 1,659 $ (25) $ 514 $ 611 $ 279 $ 278 $ 2 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) Nine Months Ended June 30, 2023 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 911 $ — $ — $ — $ — $ 911 $ — Commercial & Industrial 369 — — — — 369 — Large delivery service 139 — — — — 139 — Off-system sales and capacity releases 84 (68) — — — 152 — Other 34 (1) — — — 35 — Total Utility 1,537 (69) — — — 1,606 — Non-Utility: LPG: Retail 3,243 — 1,812 1,431 — — — Wholesale 287 — 120 167 — — — Energy Marketing 1,854 (130) — 755 1,229 — — Midstream: Pipeline 189 — — — 189 — — Peaking 28 (102) — — 130 — — Other 10 — — — 10 — — Electricity Generation 27 — — — 27 — — Other 207 — 151 56 — — — Total Non-Utility 5,845 (232) 2,083 2,409 1,585 — — Total revenues from contracts with customers 7,382 (301) 2,083 2,409 1,585 1,606 — Other revenues (b)(c) 142 (1) 64 27 1 38 13 Total revenues $ 7,524 $ (302) $ 2,147 $ 2,436 $ 1,586 $ 1,644 $ 13 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 (a) Includes intersegment revenues principally among Midstream & Marketing, Utilities and AmeriGas Propane. (b) Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, revenues from alternative revenue programs at Utilities and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP.

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Jun. 30, 2023
Inventory Disclosure [Abstract]
Schedule of Components of Inventories	Inventories comprise the following: June 30, September 30, June 30, Non-utility LPG and natural gas $ 189 $ 335 $ 261 Gas Utility natural gas 37 166 84 Energy certificates 68 70 70 Materials, supplies and other 116 94 81 Total inventories $ 410 $ 665 $ 496

Utility Regulatory Assets and_2

Utility Regulatory Assets and Liabilities and Regulatory Matters (Tables)	9 Months Ended
	Jun. 30, 2023
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 $ 95 $ 83 $ 151 Underfunded pension plans 118 114 103 Environmental costs 28 37 34 Deferred fuel and power costs 30 32 14 Removal costs, net 22 22 22 Other 57 52 47 Total regulatory assets $ 350 $ 340 $ 371 Regulatory liabilities (a): Postretirement benefit overcollections $ 10 $ 11 $ 12 Deferred fuel and power refunds 63 3 1 State tax benefits — distribution system repairs 40 38 34 Excess federal deferred income taxes 260 279 281 Other 3 4 8 Total regulatory liabilities $ 376 $ 335 $ 336 (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 $ 95 $ 83 $ 151 Underfunded pension plans 118 114 103 Environmental costs 28 37 34 Deferred fuel and power costs 30 32 14 Removal costs, net 22 22 22 Other 57 52 47 Total regulatory assets $ 350 $ 340 $ 371 Regulatory liabilities (a): Postretirement benefit overcollections $ 10 $ 11 $ 12 Deferred fuel and power refunds 63 3 1 State tax benefits — distribution system repairs 40 38 34 Excess federal deferred income taxes 260 279 281 Other 3 4 8 Total regulatory liabilities $ 376 $ 335 $ 336 (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, 2023
Retirement Benefits [Abstract]
Schedule of Components of Net Periodic Pension Benefit	Net periodic pension benefit includes the following components: Pension Benefits Three Months Ended June 30, 2023 2022 Service cost $ 2 $ 4 Interest cost 9 6 Expected return on assets (11) (12) Amortization of: Actuarial (gain) loss (1) 2 Net benefit $ (1) $ — Nine Months Ended June 30, 2023 2022 Service cost $ 7 $ 12 Interest cost 26 19 Expected return on plan assets (34) (37) Amortization of: Actuarial (gain) loss (2) 6 Net benefit $ (3) $ —

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Jun. 30, 2023
Fair Value Disclosures [Abstract]
Schedule of 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, 2023: Derivative instruments: Assets: Commodity contracts (c) $ 146 $ 111 $ — $ 257 Foreign currency contracts $ — $ 18 $ — $ 18 Interest rate contracts $ — $ 30 $ — $ 30 Liabilities: Commodity contracts (c) $ (242) $ (224) $ — $ (466) Foreign currency contracts $ — $ (4) $ — $ (4) Interest rate contracts $ — $ (4) $ — $ (4) Non-qualified supplemental postretirement grantor trust investments (a) $ 40 $ — $ — $ 40 September 30, 2022: Derivative instruments: Assets: Commodity contracts (b) $ 938 $ 1,268 $ 27 $ 2,233 Foreign currency contracts $ — $ 119 $ — $ 119 Interest rate contracts $ — $ 66 $ — $ 66 Liabilities: Commodity contracts (b) $ (377) $ (136) $ — $ (513) Foreign currency contracts $ — $ (2) $ — $ (2) Non-qualified supplemental postretirement grantor trust investments (a) $ 43 $ — $ — $ 43 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 (a) Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans. (b) Includes derivative assets and liabilities associated with the October 2022 sale of the U.K. energy marketing business classified as held for sale (see Note 5). (c) Includes derivative assets and liabilities associated with certain UGI International energy marketing businesses classified as held for sale (see Note 5).
Schedule of Carrying Amount and Estimated Fair Value of Long-term Debt	The carrying amounts and estimated fair values of our long-term debt (including current maturities but excluding unamortized debt issuance costs) were as follows: June 30, 2023 September 30, 2022 June 30, 2022 Carrying amount $ 6,682 $ 6,665 $ 6,483 Estimated fair value $ 6,318 $ 6,189 $ 6,145

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Jun. 30, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Notional Amounts Related to Open Derivative Contracts	The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at June 30, 2023, September 30, 2022 and June 30, 2022, and the final settlement dates of the Company's open derivative contracts as of June 30, 2023, but excluding those derivatives that qualified for the NPNS exception: Notional Amounts Type Units Settlements Extending Through June 30, 2023 September 30, 2022 June 30, 2022 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms February 2024 24 19 13 Non-utility Operations LPG swaps Gallons September 2025 734 874 669 Natural gas futures, forward, basis swap, options and pipeline contracts (a) Dekatherms October 2027 357 363 353 Electricity forward and futures contracts Kilowatt hours December 2026 1,586 2,446 2,621 Interest Rate Risk: Interest rate swaps Euro March 2026 € 300 € 300 € 300 Interest rate swaps USD September 2026 $ 1,274 $ 1,358 $ 1,411 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD September 2026 $ 434 $ 465 $ 435 Net investment hedge forward foreign exchange contracts Euro December 2026 € 256 € 411 € 411 (a) Amounts at June 30, 2023 and September 30, 2022 include contracts associated with certain UGI International energy marketing businesses classified as held for sale (see Note 5).
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 $ 6 $ 57 $ 28 Interest rate contracts 30 66 44 36 123 72 Derivatives subject to PGC and DS mechanisms: Commodity contracts 11 31 30 Derivatives not designated as hedging instruments: Commodity contracts (a) 246 2,202 1,935 Foreign currency contracts 12 62 31 258 2,264 1,966 Total derivative assets — gross 305 2,418 2,068 Gross amounts offset in the balance sheet (134) (295) (226) Cash collateral received (36) (398) (659) Total derivative assets — net $ 135 $ 1,725 $ 1,183 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts (4) — — Derivatives subject to PGC and DS mechanisms: Commodity contracts (18) (26) (23) Derivatives not designated as hedging instruments: Commodity contracts (a) (448) (487) (338) Foreign currency contracts (4) (2) (2) (452) (489) (340) Total derivative liabilities — gross (474) (515) (363) Gross amounts offset in the balance sheet 134 295 226 Cash collateral pledged 137 7 13 Total derivative liabilities — net $ (203) $ (213) $ (124) (a) Amounts at June 30, 2023 and September 30, 2022 include contracts associated with certain UGI International energy marketing businesses classified as held for sale (see Note 5).
Schedule of 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) Gain (Loss) Location of Gain (Loss) Reclassified from Cash Flow Hedges: 2023 2022 2023 2022 Interest rate contracts $ 32 $ 11 $ 14 $ (4) Interest expense Net Investment Hedges: Foreign currency contracts $ (5) $ 23 Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2023 2022 Location of Gain (Loss) Recognized in Income Commodity contracts $ 1 $ (6) Revenues Commodity contracts (224) 466 Cost of sales Commodity contracts (10) 6 Other operating income, net Foreign currency contracts (2) 17 Other non-operating income (expense), net Total $ (235) $ 483 Nine Months Ended June 30,: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from Cash Flow Hedges: 2023 2022 2023 2022 Interest rate contracts $ 15 $ 59 $ 28 $ (17) Interest expense Net Investment Hedges: Foreign currency contracts $ (28) $ 34 Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2023 2022 Location of Gain (Loss) Recognized in Income Commodity contracts $ 11 $ (5) Revenues Commodity contracts (1,893) 792 Cost of sales Commodity contracts (5) 6 Other operating income, net Foreign currency contracts (36) 32 Other non-operating income (expense), net Total $ (1,923) $ 825

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	9 Months Ended
	Jun. 30, 2023
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income, Net of Tax	The tables below present changes in AOCI, net of tax: Three Months Ended June 30, 2023 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — March 31, 2023 $ 14 $ 15 $ (270) $ (241) Other comprehensive income before reclassification adjustments — 22 8 30 Amounts reclassified from AOCI (1) (10) — (11) Other comprehensive (loss) income attributable to UGI (1) 12 8 19 AOCI — June 30, 2023 $ 13 $ 27 $ (262) $ (222) 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) Nine Months Ended June 30, 2023 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2022 $ 14 $ 37 $ (431) $ (380) Other comprehensive income before reclassification adjustments — 10 169 179 Amounts reclassified from AOCI (1) (20) — (21) Other comprehensive (loss) income attributable to UGI (1) (10) 169 158 AOCI — June 30, 2023 $ 13 $ 27 $ (262) $ (222) 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)

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Jun. 30, 2023
Segment Reporting [Abstract]
Schedule of Segment Reporting Information	Three Months Ended June 30, 2023 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 1,659 $ — $ 514 $ 611 $ 260 $ 270 $ 4 Intersegment revenues $ — $ (25) (b) $ — $ — $ 19 $ 8 $ (2) Cost of sales $ 1,104 $ (26) (b) $ 251 $ 418 $ 192 $ 118 $ 151 Operating (loss) income $ (732) $ — $ (8) $ 21 $ 40 $ 32 $ (817) Income from equity investees 1 — — — 1 — — Loss on extinguishment of debt (9) — — — — — (9) Other non-operating income (expense), net 1 — — 1 — 2 (2) (Loss) earnings before interest expense and income taxes (739) — (8) 22 41 34 (828) Interest expense (96) — (40) (10) (11) (20) (15) (Loss) income before income taxes $ (835) $ — $ (48) $ 12 $ 30 $ 14 $ (843) Depreciation and amortization $ 134 $ — $ 43 $ 30 $ 22 $ 38 $ 1 Capital expenditures (including the effects of accruals) $ 255 $ — $ 42 $ 27 $ 40 $ 146 $ — 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 $ — Nine Months Ended June 30, 2023 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 7,524 $ — $ 2,147 $ 2,436 $ 1,354 $ 1,575 $ 12 Intersegment revenues $ — $ (302) (b) $ — $ — $ 232 $ 69 $ 1 Cost of sales $ 6,358 $ (301) (b) $ 1,067 $ 1,713 $ 1,185 $ 873 $ 1,821 Operating (loss) income $ (1,681) $ — $ 240 $ 197 $ 249 $ 361 $ (2,728) Income (loss) from equity investees 2 — — (2) 4 — — Loss on extinguishment of debt (9) — — — — — (9) Other non-operating (loss) income, net (25) — — 21 — 6 (52) (Loss) earnings before interest expense and income taxes (1,713) — 240 216 253 367 (2,789) Interest expense (281) — (122) (26) (33) (62) (38) (Loss) income before income taxes $ (1,994) $ — $ 118 $ 190 $ 220 $ 305 $ (2,827) Depreciation and amortization $ 397 $ — $ 132 $ 86 $ 65 $ 112 $ 2 Capital expenditures (including the effects of accruals) $ 647 $ — $ 93 $ 84 $ 74 $ 396 $ — As of June 30, 2023 Total assets $ 15,243 $ (182) $ 3,443 $ 3,179 $ 3,050 $ 5,560 $ 193 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 (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, 2023 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 1 $ 1 Net losses on commodity derivative instruments not associated with current-period transactions Cost of sales $ (51) $ (87) $ (14) Net losses on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ (1) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ (6) $ — $ — Loss on extinguishment of debt Loss on extinguishments of debt $ (9) $ — $ — Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (2) $ — Loss associated with impairment of AmeriGas Propane goodwill Impairment of goodwill $ (656) $ — $ — 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 (expense), net $ — $ 14 $ — Impairments associated with certain equity method investments Income (loss) from equity investees $ — $ — $ (50) Nine Months Ended June 30, 2023 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 4 $ 7 Net losses on commodity derivative instruments not associated with current-period transactions Cost of sales $ (55) $ (1,491) $ (275) Net losses on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ (4) $ — Loss on extinguishment of debt Loss on extinguishments of debt $ (9) $ — $ — Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (52) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ (19) $ — $ — Loss on disposal of U.K. energy marketing business Loss on disposal of U.K. energy marketing business $ — $ (215) $ — Impairment of assets Operating and administrative expenses $ — $ (19) $ — Loss associated with impairment of AmeriGas Propane goodwill Impairment of goodwill $ (656) $ — $ — 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 gain on foreign currency derivative instruments Other non-operating income (expense), net $ — $ 19 $ — Impairments associated with certain equity method investments Income (loss) from equity investees $ — $ — $ (50) (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, Utilities and AmeriGas Propane.

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Schedule of Cash and Restricted Cash (Details) - USD ($) $ in Millions	Jun. 30, 2023	Sep. 30, 2022	Jun. 30, 2022	Sep. 30, 2021
Accounting Policies [Abstract]
Cash and cash equivalents	$ 260	$ 405	$ 670
Restricted cash	78	64	14
Cash, cash equivalents and restricted cash	$ 338	$ 469	$ 684	$ 877

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, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Denominator (thousands of shares):
Weighted-average common shares outstanding - basic (in shares)	209,706	210,190	209,811	209,992
Incremental shares issuable for stock options, common stock awards and Equity Units (in shares)	0	0	0	5,973
Weighted-average common shares outstanding - diluted (in shares)	209,706	210,190	209,811	215,965
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	5,972	5,668	6,222
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

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Narrative (Details) - USD ($)	3 Months Ended			9 Months Ended
	Jun. 30, 2023	Sep. 30, 2022	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	May 31, 2023
Schedule of Equity Method Investments [Line Items]
Impairment of goodwill	$ 656,000,000		$ 0	$ 656,000,000	$ 0
Goodwill	3,060,000,000	$ 3,612,000,000	3,671,000,000	3,060,000,000	3,671,000,000
AmeriGas Propane
Schedule of Equity Method Investments [Line Items]
Impairment of goodwill	656,000,000
Goodwill	$ 1,300,000,000			$ 1,300,000,000
AmeriGas Partners And AmeriGas Finance Corp. | Senior Notes Due 2028 | Senior Notes
Schedule of Equity Method Investments [Line Items]
Principal amount						$ 500,000,000
Interest rate						9.375%
Pennant | Energy Services
Schedule of Equity Method Investments [Line Items]
Equity interest acquired		53%
Purchase price		$ 61,000,000
MBL Bioenergy
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent	99.99%			99.99%
Equity method investments	$ 93,000,000		0	$ 93,000,000	0
Pine Run Midstream, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent	49%			49%
Equity method investments	$ 75,000,000		67,000,000	$ 75,000,000	67,000,000
Pennant | Energy Services
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent	47%			47%
Equity method investments			49,000,000		49,000,000
Other equity method investments				$ 50,000,000
Other equity method investments
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 84,000,000		$ 44,000,000	$ 84,000,000	$ 44,000,000

Accounting Changes (Details)

Accounting Changes (Details) - USD ($) $ in Millions	Jun. 30, 2023	Mar. 31, 2023	Oct. 01, 2022	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Beneficial conversion feature	$ 4,373			$ 6,074	$ 6,005
Common Stock | Cumulative effect of change in accounting - ASU 2020-06 (Note 3)
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Beneficial conversion feature			$ (6)
Preferred Stock
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Beneficial conversion feature	167	$ 167		162	162	$ 161	$ 213
Preferred Stock | Cumulative effect of change in accounting - ASU 2020-06 (Note 3)
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Beneficial conversion feature			6	5		1	1
Retained Earnings
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Beneficial conversion feature	$ 2,974	$ 3,842		4,841	$ 4,674	4,757	4,081
Retained Earnings | Cumulative effect of change in accounting - ASU 2020-06 (Note 3)
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Beneficial conversion feature			$ 1	$ 1		$ (1)	$ (1)

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
	Nov. 01, 2022	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		$ 1,620	$ 2,004	$ 7,382	$ 8,082
Other revenues		39	29	142	90
Total revenues		1,659	2,033	7,524	8,172
Weather Normalization Adjustment Rider | PAPUC | Gas Utility
Disaggregation of Revenue [Line Items]
Rate period	5 years
Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		265	249	1,537	1,309
Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		151	140	911	774
Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		60	57	369	318
Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		39	38	139	135
Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		7	9	84	65
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		8	5	34	17
Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1,355	1,755	5,845	6,773
Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		799	880	3,243	3,684
Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		76	107	287	401
Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		336	631	1,854	2,254
Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		58	53	189	149
Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		1	9	28	38
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		3	2	10	6
Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		17	1	27	20
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		65	72	207	221
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(26)	(99)	(301)	(394)
Other revenues		1	0	(1)	(2)
Total revenues		(25)	(99)	(302)	(396)
Eliminations | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		(7)	(24)	(69)	(87)
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		(7)	(24)	(68)	(86)
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		(19)	(75)	(232)	(307)
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		(14)	(70)	(130)	(206)
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)	(102)	(101)
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		19	75	232	307
Eliminations | Utilities
Disaggregation of Revenue [Line Items]
Total revenues		8	24	69	87
Operating Segments | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		494	577	2,083	2,367
Other revenues		20	20	64	56
Total revenues		514	597	2,147	2,423
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		494	577	2,083	2,367
Operating Segments | AmeriGas Propane | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		423	478	1,812	2,032
Operating Segments | AmeriGas Propane | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		24	48	120	172
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		47	51	151	163
Operating Segments | UGI International
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		602	728	2,409	2,984
Other revenues		9	10	27	27
Total revenues		611	738	2,436	3,011
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		602	728	2,409	2,984
Operating Segments | UGI International | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		376	402	1,431	1,652
Operating Segments | UGI International | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		52	59	167	229
Operating Segments | UGI International | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		156	246	755	1,045
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		18	21	56	58
Operating Segments | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		278	525	1,585	1,729
Other revenues		1	0	1	2
Total revenues		279	525	1,586	1,731
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		278	525	1,585	1,729
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		194	455	1,229	1,415
Operating Segments | Midstream & Marketing | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		58	53	189	149
Operating Segments | Midstream & Marketing | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		6	14	130	139
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		3	2	10	6
Operating Segments | Midstream & Marketing | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		17	1	27	20
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		272	273	1,606	1,396
Other revenues		6	1	38	4
Total revenues		278	274	1,644	1,400
Operating Segments | Utilities | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		272	273	1,606	1,396
Operating Segments | Utilities | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		151	140	911	774
Operating Segments | Utilities | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		60	57	369	318
Operating Segments | Utilities | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		39	38	139	135
Operating Segments | Utilities | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		14	33	152	151
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers		8	5	35	18
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	(2)	13	3
Total revenues		2	(2)	13	3
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, 2023	Jun. 30, 2022	Sep. 30, 2022
Disaggregation of Revenue [Line Items]
Contract liabilities	$ 133	$ 128	$ 164
Revenue recognized	118	$ 117
Midstream & Marketing
Disaggregation of Revenue [Line Items]
Expected revenue	2,200
Utilities
Disaggregation of Revenue [Line Items]
Expected revenue	$ 200

Dispositions and Acquisition (D

Dispositions and Acquisition (Details) € in Millions, $ in Millions		3 Months Ended
	Jan. 27, 2022 USD ($)	Mar. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Aug. 01, 2023 EUR (€)	Jun. 30, 2023 USD ($)	Oct. 21, 2022 USD ($)	Sep. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Held for sale assets					$ 64		$ 295	$ 0
Stonehenge | Energy Services
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Enterprise value	$ 190
Sale | Sale of U.K. Energy Marketing Business
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Net cash payment						$ 19
Pre-tax loss			$ 215
After tax loss		$ 151
Net carrying value						$ 206	$ 276
Sale | Other UGI International Energy Marketing Businesses
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Pre-tax impairment charges			$ 19
Disposal Group, Held-for-Sale, Not Discontinued Operations | Sale of France Energy Marketing Business
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Held for sale assets					$ 10
Disposal Group, Held-for-Sale, Not Discontinued Operations | Sale of France Energy Marketing Business | Subsequent event
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration paid | €				€ 23

Inventories - Components of Inv

Inventories - Components of Inventories (Details) - USD ($) $ in Millions	Jun. 30, 2023	Sep. 30, 2022	Jun. 30, 2022
Inventory
Total inventories	$ 410	$ 665	$ 496
Non-utility LPG and natural gas
Inventory
Total inventories	189	335	261
Gas Utility natural gas
Inventory
Total inventories	37	166	84
Energy certificates
Inventory
Total inventories	68	70	70
Materials, supplies and other
Inventory
Total inventories	$ 116	$ 94	$ 81

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, 2023	Sep. 30, 2022	Jun. 30, 2022
Regulatory Assets
Regulatory assets	$ 350	$ 340	$ 371
Regulatory Liabilities
Regulatory liabilities	376	335	336
Postretirement benefit overcollections
Regulatory Liabilities
Regulatory liabilities	10	11	12
Deferred fuel and power refunds
Regulatory Liabilities
Regulatory liabilities	63	3	1
State tax benefits — distribution system repairs
Regulatory Liabilities
Regulatory liabilities	40	38	34
Excess federal deferred income taxes
Regulatory Liabilities
Regulatory liabilities	260	279	281
Other
Regulatory Liabilities
Regulatory liabilities	3	4	8
Income taxes recoverable
Regulatory Assets
Regulatory assets	95	83	151
Underfunded pension plans
Regulatory Assets
Regulatory assets	118	114	103
Environmental costs
Regulatory Assets
Regulatory assets	28	37	34
Deferred fuel and power costs
Regulatory Assets
Regulatory assets	30	32	14
Removal costs, net
Regulatory Assets
Regulatory assets	22	22	22
Other
Regulatory Assets
Regulatory assets	$ 57	$ 52	$ 47

Utility Regulatory Assets and_4

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

9 Months Ended

12 Months Ended

Jul. 31, 2023

Jul. 14, 2023

Mar. 06, 2023

Jan. 27, 2023

Nov. 16, 2022

Nov. 01, 2022

Sep. 15, 2022

Jul. 29, 2022

Jan. 28, 2022

Nov. 09, 2021

Feb. 08, 2021

Jun. 30, 2023

Jun. 30, 2022

Sep. 30, 2022

Dec. 01, 2022

Regulatory Assets

Net unrealized gains

$ (1,866,000)

$ 372,000

Pilot program duration

5 years

WVPSC

Regulatory Assets

Under-recovery of gas cost

$ 12,000

Gas Utility

Regulatory Assets

Net unrealized gains

$ (7,000)

$ 7,000

$ 5,000

Gas Utility | PAPUC

Regulatory Assets

Requested rate increase (decrease)

$ 83,000

Gas Utility | PAPUC | Joint Petition

Regulatory Assets

Requested rate increase (decrease)

$ 49,000

Approved rate

3%

Property, plant and equipment, net threshold

$ 3,368

Gas Utility | PAPUC | Beginning October 29, 2022

Regulatory Assets

Requested rate increase (decrease)

38,000

Gas Utility | PAPUC | Beginning October 1, 2023

Regulatory Assets

Requested rate increase (decrease)

$ 11,000

Gas Utility | PAPUC | Weather Normalization Adjustment Rider

Regulatory Assets

Approved rate

3%

Utilities | PAPUC

Regulatory Assets

Requested rate increase (decrease)

$ 11,000

$ 9,000

Approved rate increase

$ 6,000

Utilities | PAPUC | Subsequent event

Regulatory Assets

Requested rate increase (decrease)

$ 9,000

Mountaineer | WVPSC | 2023 IREP Recovery | Subsequent event

Regulatory Assets

Requested rate increase (decrease)

$ 10,000

Public Utilities Requested Rate Change, Requested Rate Increase (Decrease), Revenue

(12,000)

Public Utilities, Requested Rate Change, Capital Investments

383,000

Mountaineer | WVPSC | 2023 IREP | Subsequent event

Regulatory Assets

Public Utilities Requested Rate Change, Capital Investment Costs

131,000

Mountaineer | WVPSC | 2023 IREP For 2024 | Subsequent event

Regulatory Assets

Public Utilities Requested Rate Change, Capital Investment Costs

$ 67,000

Mountaineer | WVPSC | Net Revenue Increase

Regulatory Assets

Requested rate increase (decrease)

$ 20,000

Mountaineer | WVPSC | Base Rate Case, Base Rate

Regulatory Assets

Requested rate increase (decrease)

38,000

Mountaineer | WVPSC | Base Rate Case, Infrastructure Rider

Regulatory Assets

Requested rate increase (decrease)

$ (18,000)

Mountaineer | WVPSC | Over 2023 - 2027

Regulatory Assets

Requested rate increase (decrease)

$ 354,000

Mountaineer | WVPSC | Calendar Year 2023

Regulatory Assets

Requested rate increase (decrease)

$ 64,000

Mountaineer | WVPSC | 2023 IREP Revenue

Regulatory Assets

Requested rate increase (decrease)

$ 22,000

Mountaineer | WVPSC | 2021 IREP

Regulatory Assets

Requested rate increase (decrease)

$ 1,000

Debt (Details)

Debt (Details)

1 Months Ended

3 Months Ended

9 Months Ended

May 31, 2023 USD ($)

May 12, 2023

Apr. 24, 2023 USD ($)

Mar. 31, 2023 USD ($)

Mar. 07, 2023 EUR (€)

Mar. 01, 2023 USD ($)

Feb. 23, 2023 USD ($)

Dec. 13, 2022 USD ($)

Oct. 20, 2022 USD ($)

Jun. 30, 2023 USD ($)

May 31, 2023 USD ($)

Jun. 30, 2023 USD ($) cure

Jun. 30, 2022 USD ($)

Jun. 30, 2023 USD ($) cure

Jun. 30, 2022 USD ($)

Debt Instrument [Line Items]

Loss on extinguishments of debt

$ (9,000,000)

$ 0

$ (9,000,000)

$ (11,000,000)

Settlement of Energy Services interest rate swap

$ (32,000,000)

$ 0

Interest rate swaps

Debt Instrument [Line Items]

Fixed rate

3.10%

AmeriGas OLP

Debt Instrument [Line Items]

Capital contributions

$ 11,000,000

$ 20,000,000

$ 52,000,000

2022 AmeriGas OLP Credit Agreement | AmeriGas OLP

Debt Instrument [Line Items]

Permitted usage of equity cure provision | cure

5

Number of equity cure | cure

1

Senior Notes | Senior Notes Due 2028 | AmeriGas Partners And AmeriGas Finance Corp.

Debt Instrument [Line Items]

Principal amount

$ 500,000,000

$ 500,000,000

Interest rate

9.375%

9.375%

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

Debt Instrument [Line Items]

Call premium

4.688%

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

Debt Instrument [Line Items]

Call premium

0%

Senior Notes | AmeriGas Partners Senior Notes | AmeriGas Partners And AmeriGas Finance Corp.

Debt Instrument [Line Items]

Principal amount

$ 675,000,000

$ 675,000,000

Interest rate

5.625%

5.625%

Repayment of debt

$ 150,000,000

Loss on extinguishments of debt

$ (9,000,000)

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

Debt Instrument [Line Items]

Principal amount | €

€ 300,000,000

Debt term

5 years

Line of Credit | UGI International Credit Facilities Agreement | Revolving Credit Facility

Debt Instrument [Line Items]

Maximum borrowing capacity | €

€ 500,000,000

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

Debt Instrument [Line Items]

Basis spread on variable rate

3.35%

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

Debt Instrument [Line Items]

Basis spread on variable rate

1.70%

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

Debt Instrument [Line Items]

Maximum borrowing capacity | €

€ 100,000,000

Consolidated net leverage ratio

3.85

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

Debt Instrument [Line Items]

Consolidated net leverage ratio

4.25

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

Debt Instrument [Line Items]

Basis spread on variable rate

3.35%

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

Debt Instrument [Line Items]

Basis spread on variable rate

1.35%

Line of Credit | UGI Energy Services Credit Agreement | SOFR

Debt Instrument [Line Items]

Basis spread on variable rate

0.10%

Line of Credit | Energy Services Term Loan Credit Agreement | Revolving Credit Facility

Debt Instrument [Line Items]

Principal amount

$ 800,000,000

Fixed rate

4.53%

Increase to limit

125,000,000

Quarterly installments

$ 2,000,000

Settlement of Energy Services interest rate swap

$ 32,000,000

Line of Credit | Energy Services Term Loan Credit Agreement | Revolving Credit Facility | SOFR

Debt Instrument [Line Items]

Basis spread on variable rate

3.25%

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

Debt Instrument [Line Items]

Basis spread on variable rate

0.10%

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

Debt Instrument [Line Items]

Basis spread on variable rate

2.25%

Line of Credit | UGI Utilities Credit Agreement | Utilities | Revolving Credit Facility

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 425,000,000

Line of Credit | UGI Utilities Credit Agreement | Utilities | Revolving Credit Facility | SOFR

Debt Instrument [Line Items]

Basis spread on variable rate

0.10%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 150,000,000

Option to increase capacity

$ 250,000,000

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | SOFR

Debt Instrument [Line Items]

Basis spread on variable rate

1%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | SOFR | Maximum

Debt Instrument [Line Items]

Basis spread on variable rate

2.25%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | SOFR | Minimum

Debt Instrument [Line Items]

Basis spread on variable rate

1%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | Federal Funds Rate

Debt Instrument [Line Items]

Basis spread on variable rate

0.50%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | Base Rate Margin | Maximum

Debt Instrument [Line Items]

Basis spread on variable rate

1.25%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | Base Rate Margin | Minimum

Debt Instrument [Line Items]

Basis spread on variable rate

0%

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

Debt Instrument [Line Items]

Basis spread on variable rate

0.10%

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

Debt Instrument [Line Items]

Basis spread on variable rate

0.15%

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

Debt Instrument [Line Items]

Basis spread on variable rate

0.25%

Line of Credit | Mountaineer Credit Agreement | Mountaineer | Letters of Credit

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 20,000,000

Line of Credit | UGI Corporation Credit Agreement | Revolving Credit Facility | SOFR

Debt Instrument [Line Items]

Basis spread on variable rate

0.10%

Commitments and Contingencies (

Commitments and Contingencies (Details)	9 Months Ended	12 Months Ended
	Jun. 30, 2023 USD ($) subsidiary	Sep. 30, 2017 USD ($) record_of_decision	Mar. 24, 2023 person	Sep. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)
Loss Contingencies
Environmental expenditures cap during calendar year	$ 5,000,000
West Reading, Pennsylvania Explosion
Loss Contingencies
Number of fatalities | person			7
Number of injuries | person			11
MGP sites in Pennsylvania
Loss Contingencies
Accrual for environmental loss contingencies	$ 52,000,000			$ 53,000,000	$ 51,000,000
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 Benefit (Details) - Pension Plan - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Defined Benefit Plan Disclosure
Service cost	$ 2	$ 4	$ 7	$ 12
Interest cost	9	6	26	19
Expected return on plan assets	(11)	(12)	(34)	(37)
Amortization of:
Actuarial (gain) loss	(1)	2	(2)	6
Net benefit	$ (1)	$ 0	$ (3)	$ 0

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, 2023	Sep. 30, 2022	Jun. 30, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	$ 305	$ 2,418	$ 2,068
Liabilities:	(474)	(515)	(363)
Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	11	31	30
Liabilities:	(18)	(26)	(23)
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	40	43	46
Recurring | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	257	2,233	1,965
Liabilities:	(466)	(513)	(361)
Recurring | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	18	119	59
Liabilities:	(4)	(2)	(2)
Recurring | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	30	66	44
Liabilities:	(4)
Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	40	43	46
Recurring | Level 1 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	146	938	816
Liabilities:	(242)	(377)	(324)
Recurring | Level 1 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	0	0	0
Liabilities:	0	0	0
Recurring | Level 1 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	0	0	0
Liabilities:	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
Assets:	111	1,268	1,149
Liabilities:	(224)	(136)	(37)
Recurring | Level 2 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	18	119	59
Liabilities:	(4)	(2)	(2)
Recurring | Level 2 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	30	66	44
Liabilities:	(4)
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
Assets:	0	27	0
Liabilities:	0	0	0
Recurring | Level 3 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	0	0	0
Liabilities:	0	0	0
Recurring | Level 3 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	0	$ 0	$ 0
Liabilities:	$ 0

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Sep. 30, 2022
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Impairment of goodwill	$ 656	$ 0	$ 656	$ 0
AmeriGas Propane
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Impairment of goodwill	$ 656
Level 3 | Commodity contracts | Minimum
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value					$ 7
Level 3 | Commodity contracts | Maximum
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value					$ 27

Fair Value Measurements - Carry

Fair Value Measurements - Carrying Amounts and Estimated Fair Values of Long-term Debt (Details) - USD ($) $ in Millions	Jun. 30, 2023	Sep. 30, 2022	Jun. 30, 2022
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,682	$ 6,665	$ 6,483
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,318	$ 6,189	$ 6,145

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Narrative (Details)	3 Months Ended		9 Months Ended
	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2023 EUR (€)	Sep. 30, 2022 USD ($)	Sep. 30, 2022 EUR (€)	Jun. 30, 2022 EUR (€)	Dec. 07, 2021 EUR (€)
Derivative [Line Items]
Pre-tax (losses) gains associated with net investment hedges	$ (7,000,000)	$ 41,000,000	$ (80,000,000)	$ 75,000,000
Maximum amount of loss	305,000,000		305,000,000
Cash collateral received	36,000,000	659,000,000	36,000,000	659,000,000		$ 398,000,000
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 gains associated with interest rate hedges	$ 49,000,000		$ 49,000,000
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	$ 434,000,000	$ 435,000,000	$ 434,000,000	$ 435,000,000	€ 256,000,000	$ 465,000,000	€ 411,000,000	€ 411,000,000
Foreign currency contracts | UGI International | Net Investment Hedges:
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, 2023 USD ($) kWh DTH gal	Jun. 30, 2023 EUR (€) kWh DTH gal	Sep. 30, 2022 USD ($) kWh DTH gal	Sep. 30, 2022 EUR (€) kWh DTH gal	Jun. 30, 2022 USD ($) gal DTH kWh	Jun. 30, 2022 EUR (€) gal DTH kWh
Commodity contracts | Regulated Utility Operations | Natural Gas
Derivative [Line Items]
Notional amount (in units)	24	24	19	19	13	13
Commodity contracts | Non-utility Operations | LPG swaps
Derivative [Line Items]
Notional amount (in units) | gal	734	734	874	874	669	669
Commodity contracts | Non-utility Operations | Electricity forward and futures contracts
Derivative [Line Items]
Notional amount (in units) | kWh	1,586	1,586	2,446	2,446	2,621	2,621
Natural gas futures, forward, basis swap, options and pipeline contracts | Non-utility Operations | Natural Gas
Derivative [Line Items]
Notional amount (in units)	357	357	363	363	353	353
Interest rate swaps
Derivative [Line Items]
Notional amount	$ 1,274	€ 300	$ 1,358	€ 300	$ 1,411	€ 300
Forward foreign currency exchange contracts
Derivative [Line Items]
Notional amount	$ 434	€ 256	$ 465	€ 411	$ 435	€ 411

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2023	Sep. 30, 2022	Jun. 30, 2022
Derivative assets:
Total derivative assets — gross	$ 305	$ 2,418	$ 2,068
Gross amounts offset in the balance sheet	(134)	(295)	(226)
Cash collateral received	(36)	(398)	(659)
Total derivative assets — net	135	1,725	1,183
Derivative liabilities:
Total derivative liabilities — gross	(474)	(515)	(363)
Gross amounts offset in the balance sheet	134	295	226
Cash collateral pledged	137	7	13
Total derivative liabilities — net	(203)	(213)	(124)
Commodity contracts
Derivative assets:
Total derivative assets — gross	11	31	30
Derivative liabilities:
Total derivative liabilities — gross	(18)	(26)	(23)
Derivatives designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	36	123	72
Derivatives designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	6	57	28
Derivatives designated as hedging instruments: | Interest rate contracts
Derivative assets:
Total derivative assets — gross	30	66	44
Derivative liabilities:
Total derivative liabilities — gross	(4)	0	0
Derivatives not designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	258	2,264	1,966
Derivative liabilities:
Total derivative liabilities — gross	(452)	(489)	(340)
Derivatives not designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	12	62	31
Derivative liabilities:
Total derivative liabilities — gross	(4)	(2)	(2)
Derivatives not designated as hedging instruments: | Commodity contracts
Derivative assets:
Total derivative assets — gross	246	2,202	1,935
Derivative liabilities:
Total derivative liabilities — gross	$ (448)	$ (487)	$ (338)

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, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Derivatives not designated as hedging instruments:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ (235)	$ 483	$ (1,923)	$ 825
Interest rate contracts | Derivatives designated as hedging instruments: | Cash Flow Hedges:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	32	11	15	59
Interest rate contracts | Derivatives designated as hedging instruments: | Interest expense | Cash Flow Hedges:
Derivative Instruments, Gain (Loss)
Gain (Loss) Reclassified from AOCI into Income	14	(4)	28	(17)
Foreign currency contracts | Derivatives designated as hedging instruments: | Net Investment Hedges:
Derivative Instruments, Gain (Loss)
Foreign currency contracts	(5)	23	(28)	34
Foreign currency contracts | Derivatives not designated as hedging instruments: | Other non-operating income (expense), net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(2)	17	(36)	32
Commodity contracts | Derivatives not designated as hedging instruments: | Revenues
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	1	(6)	11	(5)
Commodity contracts | Derivatives not designated as hedging instruments: | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(224)	466	(1,893)	792
Commodity contracts | Derivatives not designated as hedging instruments: | Other operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ (10)	$ 6	$ (5)	$ 6

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period			$ 6,074
Other comprehensive income (loss) before reclassification adjustments	$ 30	$ (98)	179	$ (149)
Amounts reclassified from AOCI	(11)	3	(21)	16
Other comprehensive (loss) income attributable to UGI	19	(95)	158	(133)
Balance, end of period	4,373	6,005	4,373	6,005
Total
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(241)	(178)	(380)	(140)
Balance, end of period	(222)	(273)	(222)	(273)
Postretirement Benefit Plans
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	14	(14)	14	(17)
Other comprehensive income (loss) before reclassification adjustments	0	0	0	0
Amounts reclassified from AOCI	(1)	0	(1)	3
Other comprehensive (loss) income attributable to UGI	(1)	0	(1)	3
Balance, end of period	13	(14)	13	(14)
Derivative Instruments
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	15	11	37	(33)
Other comprehensive income (loss) before reclassification adjustments	22	8	10	42
Amounts reclassified from AOCI	(10)	3	(20)	13
Other comprehensive (loss) income attributable to UGI	12	11	(10)	55
Balance, end of period	27	22	27	22
Foreign Currency
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(270)	(175)	(431)	(90)
Other comprehensive income (loss) before reclassification adjustments	8	(106)	169	(191)
Amounts reclassified from AOCI	0	0	0	0
Other comprehensive (loss) income attributable to UGI	8	(106)	169	(191)
Balance, end of period	$ (262)	$ (281)	$ (262)	$ (281)

Segment Information - Narrative

Segment Information - Narrative (Details)	9 Months Ended
	Jun. 30, 2023 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, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Sep. 30, 2022
Segment Reporting Information [Line Items]
Revenues	$ 1,659	$ 2,033	$ 7,524	$ 8,172
Cost of sales	1,104	1,361	6,358	4,951
Operating (loss) income	(732)	99	(1,681)	1,363
(Loss) income from equity investees	1	(45)	2	(32)
Loss on extinguishments of debt	(9)	0	(9)	(11)
Other non-operating (loss) income, net	1	20	(25)	41
(Loss) earnings before interest expense and income taxes	(739)	74	(1,713)	1,361
Interest expense	(96)	(82)	(281)	(245)
(Loss) income before income taxes	(835)	(8)	(1,994)	1,116
Depreciation and amortization	134	130	397	387
Capital expenditures (including the effects of accruals)	255	201	647	546
Total assets	15,243	17,111	15,243	17,111	$ 17,575
Eliminations
Segment Reporting Information [Line Items]
Revenues	(25)	(99)	(302)	(396)
Cost of sales	(26)	(99)	(301)	(394)
Operating (loss) income	0	0	0	0
(Loss) income from equity investees	0	0	0	0
Loss on extinguishments of debt	0		0	0
Other non-operating (loss) income, net	0	0	0	0
(Loss) 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)	(182)	(182)	(182)
Eliminations | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Eliminations | UGI International
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Eliminations | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	19	75	232	307
Eliminations | Utilities
Segment Reporting Information [Line Items]
Revenues	8	24	69	87
Operating Segments | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	514	597	2,147	2,423
Cost of sales	251	370	1,067	1,333
Operating (loss) income	(8)	(10)	240	303
(Loss) income from equity investees	0	0	0	0
Loss on extinguishments of debt	0		0	0
Other non-operating (loss) income, net	0	0	0	0
(Loss) earnings before interest expense and income taxes	(8)	(10)	240	303
Interest expense	(40)	(41)	(122)	(120)
(Loss) income before income taxes	(48)	(51)	118	183
Depreciation and amortization	43	44	132	132
Capital expenditures (including the effects of accruals)	42	28	93	99
Total assets	3,443	4,365	3,443	4,365
Operating Segments | UGI International
Segment Reporting Information [Line Items]
Revenues	611	738	2,436	3,011
Cost of sales	418	544	1,713	2,267
Operating (loss) income	21	22	197	211
(Loss) income from equity investees	0	0	(2)	0
Loss on extinguishments of debt	0		0	0
Other non-operating (loss) income, net	1	4	21	17
(Loss) earnings before interest expense and income taxes	22	26	216	228
Interest expense	(10)	(7)	(26)	(22)
(Loss) income before income taxes	12	19	190	206
Depreciation and amortization	30	29	86	89
Capital expenditures (including the effects of accruals)	27	25	84	71
Total assets	3,179	4,410	3,179	4,410
Operating Segments | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	279	525	1,586	1,731
Revenues from external customers	260	450	1,354	1,424
Cost of sales	192	436	1,185	1,389
Operating (loss) income	40	38	249	197
(Loss) income from equity investees	1	6	4	19
Loss on extinguishments of debt	0		0	0
Other non-operating (loss) income, net	0	0	0	0
(Loss) earnings before interest expense and income taxes	41	44	253	216
Interest expense	(11)	(11)	(33)	(31)
(Loss) income before income taxes	30	33	220	185
Depreciation and amortization	22	20	65	57
Capital expenditures (including the effects of accruals)	40	9	74	25
Total assets	3,050	3,198	3,050	3,198
Operating Segments | Utilities
Segment Reporting Information [Line Items]
Revenues	278	274	1,644	1,400
Revenues from external customers	270	250	1,575	1,313
Cost of sales	118	121	873	701
Operating (loss) income	32	38	361	325
(Loss) income from equity investees	0	0	0	0
Loss on extinguishments of debt	0		0	0
Other non-operating (loss) income, net	2	2	6	7
(Loss) earnings before interest expense and income taxes	34	40	367	332
Interest expense	(20)	(15)	(62)	(47)
(Loss) income before income taxes	14	25	305	285
Depreciation and amortization	38	37	112	108
Capital expenditures (including the effects of accruals)	146	139	396	351
Total assets	5,560	5,146	5,560	5,146
Corporate & Other
Segment Reporting Information [Line Items]
Revenues from external customers	4	(2)	12	1
Cost of sales	151	(11)	1,821	(345)
Operating (loss) income	(817)	11	(2,728)	327
(Loss) income from equity investees	0	(51)	0	(51)
Loss on extinguishments of debt	(9)		(9)	(11)
Other non-operating (loss) income, net	(2)	14	(52)	17
(Loss) earnings before interest expense and income taxes	(828)	(26)	(2,789)	282
Interest expense	(15)	(8)	(38)	(25)
(Loss) income before income taxes	(843)	(34)	(2,827)	257
Depreciation and amortization	1	0	2	1
Capital expenditures (including the effects of accruals)	0	0	0	0
Total assets	193	174	193	174
Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishments of debt	(9)		(9)	0
Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Loss on extinguishments of debt	0		0	(11)
Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishments of debt	0		0	0
Intersegment revenues Corporate & Other
Segment Reporting Information [Line Items]
Revenues	$ (2)	$ 0	$ 1	$ 2

Segment Information - Reconcili

Segment Information - Reconciliation of Partnership Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			$ (1,866)	$ 372
Loss on extinguishments of debt	$ (9)	$ 0	(9)	(11)
Impairment of goodwill	(656)	0	(656)	0
Loss on disposal of U.K. energy marketing business	0	0	(215)	0
AmeriGas Propane
Segment Reporting Information [Line Items]
Impairment of goodwill	(656)
Corporate & Other
Segment Reporting Information [Line Items]
Loss on extinguishments of debt	(9)		(9)	(11)
Corporate & Other | AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishments of debt	(9)		(9)	0
Impairment of goodwill	(656)		656
Loss on disposal of U.K. energy marketing business			0
Corporate & Other | AmeriGas Propane | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
Corporate & Other | AmeriGas Propane | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(51)	(46)	(55)	(83)
Corporate & Other | AmeriGas Propane | Other operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
Corporate & Other | AmeriGas Propane | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas operations enhancement for growth project	(6)		(19)
Restructuring costs		(1)		(15)
Impairment of assets			0
Corporate & Other | AmeriGas Propane | Other non-operating income (expense), net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
Corporate & Other | AmeriGas Propane | Income (loss) from equity investees
Segment Reporting Information [Line Items]
Impairments associated with certain equity method investments		0		0
Corporate & Other | UGI International
Segment Reporting Information [Line Items]
Loss on extinguishments of debt	0		0	(11)
Impairment of goodwill	0		0
Loss on disposal of U.K. energy marketing business			(215)
Corporate & Other | UGI International | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	1	2	4	7
Corporate & Other | UGI International | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(87)	110	(1,491)	458
Corporate & Other | UGI International | Other operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(1)	6	(4)	6
Corporate & Other | UGI International | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas operations enhancement for growth project	0		0
Restructuring costs		(2)		(4)
Impairment of assets			(19)
Corporate & Other | UGI International | Other non-operating income (expense), net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(2)	14	(52)	19
Corporate & Other | UGI International | Income (loss) from equity investees
Segment Reporting Information [Line Items]
Impairments associated with certain equity method investments		0		0
Corporate & Other | Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishments of debt	0		0	0
Impairment of goodwill	0		0
Loss on disposal of U.K. energy marketing business			0
Corporate & Other | Midstream & Marketing | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	1	(4)	7	(6)
Corporate & Other | Midstream & Marketing | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(14)	(51)	(275)	(29)
Corporate & Other | Midstream & Marketing | Other operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
Corporate & Other | Midstream & Marketing | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas operations enhancement for growth project	0		0
Restructuring costs		(1)		(1)
Impairment of assets			0
Corporate & Other | Midstream & Marketing | Other non-operating income (expense), net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	$ 0	0	$ 0	0
Corporate & Other | Midstream & Marketing | Income (loss) from equity investees
Segment Reporting Information [Line Items]
Impairments associated with certain equity method investments		$ (50)		$ (50)