UGI (UGI) 10-Q 2 Feb 23 2023 Q1 Quarterly report Financial data

Cover Page

Cover Page - shares	3 Months Ended
	Dec. 31, 2022	Jan. 31, 2023
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Dec. 31, 2022
Document Transition Report	false
Entity File Number	1-11071
Entity Registrant Name	UGI CORPORATION
Entity Incorporation, State or Country Code	PA
Entity Tax Identification Number	23-2668356
Entity Address, Address Line One	460 North Gulph Road
Entity Address, City or Town	King of Prussia
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	19406
City Area Code	610
Local Phone Number	337-1000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		209,556,984
Entity Central Index Key	0000884614
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--09-30
Common Stock, without par value
Document Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	UGI
Security Exchange Name	NYSE
Corporate Units
Document Information [Line Items]
Title of 12(b) Security	Corporate Units
Trading Symbol	UGIC
Security Exchange Name	NYSE

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) - USD ($) $ in Millions	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 317	$ 405	$ 334
Restricted cash	227	64	24
Accounts receivable (less allowances for doubtful accounts of $69, $64 and $57, respectively)	1,578	1,127	1,461
Accrued utility revenues	147	23	95
Income taxes receivable	51	128	128
Inventories	618	665	548
Derivative instruments	238	865	578
Held for sale assets (Note 5)	0	295	0
Prepaid expenses and other current assets	280	230	263
Total current assets	3,456	3,802	3,431
Property, plant and equipment, (less accumulated depreciation of $4,344, $4,166 and $4,047, respectively)	8,176	8,040	7,597
Goodwill	3,697	3,612	3,748
Intangible assets, net	488	500	565
Utility regulatory assets	314	301	372
Derivative instruments	187	565	257
Other assets	810	755	830
Total assets	17,128	17,575	16,800
Current liabilities:
Current maturities of long-term debt	402	149	123
Short-term borrowings	991	368	579
Accounts payable	1,014	891	973
Derivative instruments	133	144	53
Held for sale liabilities (Note 5)	0	19	0
Other current liabilities	840	873	853
Total current liabilities	3,380	2,444	2,581
Long-term debt	6,323	6,483	6,416
Deferred income taxes	958	1,305	1,060
Derivative instruments	36	50	33
Other noncurrent liabilities	1,243	1,219	1,351
Total liabilities	11,940	11,501	11,441
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	214
UGI Common Stock, without par value (authorized — 450,000,000 shares; issued — 210,621,970, 210,560,494 and 210,045,726 shares, respectively)	1,482	1,483	1,402
Retained earnings	3,808	4,841	3,908
Accumulated other comprehensive loss	(231)	(380)	(156)
Treasury stock, at cost	(46)	(40)	(19)
Total UGI Corporation stockholders’ equity	5,180	6,066	5,349
Noncontrolling interests	8	8	10
Total equity	5,188	6,074	5,359
Total liabilities and equity	$ 17,128	$ 17,575	$ 16,800

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 69	$ 64	$ 57
Accumulated depreciation	$ 4,344	$ 4,166	$ 4,047
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)	210,621,970	210,560,494	210,045,726

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (unaudited) - USD ($) shares in Thousands, $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Income Statement [Abstract]
Revenues	$ 2,759	$ 2,673
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)	3,106	2,120
Operating and administrative expenses	529	514
Depreciation and amortization	131	129
Loss on disposal of U.K. energy marketing business	215	0
Other operating income, net	(18)	(22)
Costs and expenses	3,963	2,741
Operating loss	(1,204)	(68)
Income from equity investees	1	8
Loss on extinguishments of debt	0	(11)
Other non-operating (expense) income, net	(28)	10
Interest expense	(92)	(81)
Loss before income taxes	(1,323)	(142)
Income tax benefit	369	46
Net loss including noncontrolling interests	(954)	(96)
Deduct net income attributable to noncontrolling interests	0	(1)
Net loss attributable to UGI Corporation	$ (954)	$ (97)
Loss per common share attributable to UGI Corporation stockholders:
Basic (in USD per share)	$ (4.54)	$ (0.46)
Diluted (in USD per share)	$ (4.54)	$ (0.46)
Weighted-average common shares outstanding (thousands):
Basic (in shares)	209,934	209,673
Diluted (in shares)	209,934	209,673

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Statement of Comprehensive Income [Abstract]
Net loss including noncontrolling interests	$ (954)	$ (96)
Other comprehensive income (loss):
Net gains on derivative instruments (net of tax of $(1) and $(2), respectively)	3	10
Reclassifications of net (gains) losses on derivative instruments (net of tax of $2 and $(2), respectively)	(5)	4
Foreign currency adjustments (net of tax of $30 and $(4), respectively)	151	(32)
Benefit plans (net of tax of $0 and $(1), respectively)	0	2
Other comprehensive income (loss)	149	(16)
Comprehensive loss including noncontrolling interests	(805)	(112)
Deduct comprehensive income attributable to noncontrolling interests	0	(1)
Comprehensive loss attributable to UGI Corporation	$ (805)	$ (113)

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Statement of Comprehensive Income [Abstract]
Net gains on derivative instruments, tax	$ (1)	$ (2)
Reclassifications of net losses on derivative instruments, tax	2	(2)
Foreign currency adjustments, tax	30	(4)
Benefit plans, tax	$ 0	$ (1)

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net loss including noncontrolling interests	$ (954)	$ (96)
Adjustments to reconcile net loss including noncontrolling interests to net cash used by operating activities:
Depreciation and amortization	131	129
Deferred income tax benefit, net	(356)	(82)
Provision for uncollectible accounts	13	12
Changes in unrealized gains and losses on derivative instruments	1,402	397
Loss on disposal of U.K. energy marketing business	215	0
Impairment of assets	19	0
Loss on extinguishment of debt	0	11
Income from equity investees	(1)	(8)
Other, net	22	(33)
Net change in:
Accounts receivable and accrued utility revenues	(569)	(685)
Income taxes receivable	77	0
Inventories	67	(81)
Utility deferred fuel and power costs, net of changes in unsettled derivatives	(18)	(22)
Accounts payable	123	154
Derivative instruments collateral deposits paid	(343)	(260)
Other current assets	(6)	12
Other current liabilities	(62)	(42)
Net cash used by operating activities	(240)	(594)
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(210)	(186)
Acquisitions of businesses and assets, net of cash and restricted cash acquired	(9)	0
Investments in equity method investees	(40)	0
Other, net	(12)	32
Net cash used by investing activities	(271)	(154)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(76)	(72)
Issuances of long-term debt, net of issuance costs	155	614
Repayments of long-term debt and finance leases, including redemption premiums	(128)	(524)
Increase in short-term borrowings	487	212
Receivables Facility net borrowings	121	0
Payments on Purchase Contracts	(4)	(4)
Issuances of UGI Common Stock	5	8
Repurchases of UGI Common Stock	(12)	0
Net cash provided by financing activities	548	234
Effect of exchange rate changes on cash, cash equivalents and restricted cash	38	(5)
Cash, cash equivalents and restricted cash increase (decrease)	75	(519)
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of period	544	358
Cash, cash equivalents and restricted cash at beginning of period	469	877
Cash, cash equivalents and restricted cash increase (decrease)	$ 75	$ (519)

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	$ 5	$ 1,394	$ (6)	$ 4,081	$ 1	$ (140)	$ (26)	$ 9
Increase (Decrease) in Stockholders' Equity
Common Stock issued in connection with employee and director plans, net of tax withheld					5
Equity-based compensation expense					3
Other			1
Losses on common stock transactions in connection with employee and director plans							(4)
Net loss attributable to UGI Corporation	$ (97)						(97)
Cash dividends on UGI Common Stock ($0.36 and $0.35, respectively)							(72)
Net gains on derivative instruments	10								10
Reclassification of net (gains) losses on derivative instruments	4								4
Benefit plans	2								2
Foreign currency adjustments	(32)								(32)
Common Stock issued in connection with employee and director plans, net of tax withheld										7
Net loss including noncontrolling interests	(96)										1
Balance, end of period at Dec. 31, 2021	5,359	$ 5,349	214		1,402		3,908		(156)	(19)	10
Balance, beginning of period at Sep. 30, 2022	6,074		162	$ 6	1,483		4,841	$ 1	(380)	(40)	8
Increase (Decrease) in Stockholders' Equity
Common Stock issued in connection with employee and director plans, net of tax withheld					2
Equity-based compensation expense					3
Losses on common stock transactions in connection with employee and director plans							(4)
Net loss attributable to UGI Corporation	(954)						(954)
Cash dividends on UGI Common Stock ($0.36 and $0.35, respectively)							(76)
Net gains on derivative instruments	3								3
Reclassification of net (gains) losses on derivative instruments	(5)								(5)
Benefit plans	0
Foreign currency adjustments	151								151
Common Stock issued in connection with employee and director plans, net of tax withheld										6
Repurchases of UGI Common Stock										(12)
Net loss including noncontrolling interests	(954)
Balance, end of period at Dec. 31, 2022	$ 5,188	$ 5,180	$ 167		$ 1,482		$ 3,808		$ (231)	$ (46)	$ 8

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (unaudited) (Parenthetical) - $ / shares	3 Months Ended		12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Sep. 30, 2021
Statement of Stockholders' Equity [Abstract]
Accounting Standards Update [Extensible List]			Accounting Standards Update 2020-06 [Member]
Cash dividends on common stock (in USD per share)	$ 0.36	$ 0.35

Nature of Operations

Nature of Operations	3 Months Ended
	Dec. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations	Note 1 — Nature of Operations UGI is a holding company that, through subsidiaries and affiliates, distributes, stores, transports and markets energy products and related services. In the U.S., we own and operate (1) a retail propane marketing and distribution business; (2) natural gas and electric distribution utilities; and (3) energy marketing, midstream infrastructure, storage, natural gas gathering and processing, natural gas production, electricity generation and energy services businesses. In Europe, we market and distribute propane and other LPG, and market other energy products and services. We conduct a domestic propane marketing and distribution business through AmeriGas Partners. AmeriGas Partners conducts a national propane distribution business through its principal operating subsidiary, AmeriGas OLP. UGI International, through subsidiaries and affiliates, conducts (1) an LPG distribution business throughout much of Europe and (2) an energy marketing business in France, Belgium, 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 energy marketing businesses at UGI International. 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	3 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 2 — Summary of Significant Accounting Policies The accompanying condensed consolidated financial statements are unaudited and have been prepared in accordance with the rules and regulations of the SEC. They include all adjustments that we consider necessary for a fair statement of the results for the interim periods presented. Such adjustments consisted only of normal recurring items unless otherwise disclosed. The September 30, 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. December 31, December 31, Cash and cash equivalents $ 317 $ 334 Restricted cash 227 24 Cash, cash equivalents and restricted cash $ 544 $ 358 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 2022 2021 Denominator (thousands of shares): Weighted-average common shares outstanding — basic 209,934 209,673 Incremental shares issuable for stock options, common stock awards and Equity Units (a) — — Weighted-average common shares outstanding — diluted 209,934 209,673 (a) For the three months ended December 31, 2022 and 2021, 6,431 and 6,486, respectively, of such shares have been excluded as these incremental shares would be antidilutive due to the net losses for the periods presented. At December 31, 2022 and 2021, these incremental shares exclude the effects of 6,625 and 3,347 shares, respectively, associated with outstanding stock option awards 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 from equity method investees" on the Condensed Consolidated Statements of Income. Our equity method investments primarily comprise Pine Run and other equity method investments in biomass and other renewable energy projects. 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. Pine Run is accounted for as an equity method investment as we have the ability to exercise significant influence, but not control, over the entity. The carrying value of our investment in Pine Run at December 31, 2022 and 2021 was $71 and $62, respectively. At December 31, 2021, the carrying value of our investment in Pennant was $99. During Fiscal 2022, UGI through its wholly owned indirect subsidiary, Energy Services, completed the Pennant Acquisition in which Energy Services acquired the remaining 53% of the equity interests in Pennant. 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. Our other equity method investments totaled $104 and $22 at December 31, 2022 and 2021, respectively, and principally comprise of 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. With respect to the AmeriGas Propane reporting unit’s Fiscal 2022 impairment test, we determined that AmeriGas Propane’s fair value exceeded its carrying value by approximately 30%. While the Company believes that its judgments used in the quantitative assessment of AmeriGas Propane’s fair value are reasonable based upon currently available facts and circumstances, if AmeriGas Propane were not able to achieve its anticipated results and/or if its weighted average cost of capital were to increase, its fair value would be adversely affected, which may result in an impairment. There were no changes in facts and circumstances that would indicate that it is more likely than not that the fair value of the AmeriGas Propane reporting unit may not be in excess of its book value at December 31, 2022. There is approximately $2 billion of goodwill in this reporting unit as of December 31, 2022. The Company will continue to monitor its reporting units and related goodwill for any possible future non-cash impairment charges.

Accounting Changes

Accounting Changes	3 Months Ended
	Dec. 31, 2022
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 new guidance 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	3 Months Ended
	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	Note 4 — Revenue from Contracts with Customers The Company recognizes revenue when control of promised goods or services is transferred to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. See Note 4 in the Company’s 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 December 31, 2022 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 336 $ — $ — $ — $ — $ 336 $ — Commercial & Industrial 132 — — — — 132 — Large delivery service 47 — — — — 47 — Off-system sales and capacity releases 32 (33) — — — 65 — Other 10 — — — — 10 — Total Utility 557 (33) — — — 590 — Non-Utility: LPG: Retail 1,116 — 634 482 — — — Wholesale 102 — 51 51 — — — Energy Marketing 778 (77) — 318 537 — — Midstream: Pipeline 65 — — — 65 — — Peaking 17 (39) — — 56 — — Other 3 — — — 3 — — Electricity Generation 8 — — — 8 — — Other 75 — 57 18 — — — Total Non-Utility 2,164 (116) 742 869 669 — — Total revenues from contracts with customers 2,721 (149) 742 869 669 590 — Other revenues (b) 38 — 24 8 — 2 4 Total revenues $ 2,759 $ (149) $ 766 $ 877 $ 669 $ 592 $ 4 Three Months Ended December 31, 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 234 $ — $ — $ — $ — $ 234 $ — Commercial & Industrial 94 — — — — 94 — Large delivery service 43 — — — — 43 — Off-system sales and capacity releases 19 (22) — — — 41 — Other 5 (1) — — — 6 — Total Utility 395 (23) — — — 418 — Non-Utility: LPG: Retail 1,250 — 646 604 — — — Wholesale 140 — 56 84 — — — Energy Marketing 714 (55) — 333 436 — — Midstream: Pipeline 46 — — — 46 — — Peaking 6 (39) — — 45 — — Other 2 — — — 2 — — Electricity Generation 5 — — — 5 — — Other 78 — 58 20 — — — Total Non-Utility 2,241 (94) 760 1,041 534 — — Total revenues from contracts with customers 2,636 (117) 760 1,041 534 418 — Other revenues (b) 37 (1) 18 8 1 1 10 Total revenues $ 2,673 $ (118) $ 778 $ 1,049 $ 535 $ 419 $ 10 (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 and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP. Contract Balances The timing of revenue recognition may differ from the timing of invoicing to customers or cash receipts. Contract assets represent our right to consideration after the performance obligations have been satisfied when such right is conditioned on something other than the passage of time. Contract assets were not material for all periods presented. Substantially all of our receivables are unconditional rights to consideration and are included in “Accounts receivable” and, in the case of Utilities, “Accrued utility revenues” on the Condensed Consolidated Balance Sheets. Amounts billed are generally due within the following month. Contract liabilities arise when payment from a customer is received before the performance obligations have been satisfied and represent the Company’s obligations to transfer goods or services to a customer for which we have received consideration. The balances of contract liabilities were $143, $164 and $129 at December 31, 2022, September 30, 2022 and December 31, 2021, respectively, and are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets. Revenues recognized for the three months ended December 31, 2022 and 2021, from the amounts included in contract liabilities at September 30, 2022 and 2021, were $81 and $70, 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 December 31, 2022, Midstream & Marketing and Utilities expect to record approximately $2.3 billion and $0.2 billion of revenues, respectively, related to the minimum future performance obligations over the remaining terms of the related contracts.

UGI International Energy Market

UGI International Energy Marketing Businesses	3 Months Ended
	Dec. 31, 2022
Discontinued Operations and Disposal Groups [Abstract]
UGI International Energy Marketing Businesses	Note 5 — 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 three months ended December 31, 2022, 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 on the Condensed Consolidated Balance Sheet and 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 a definitive agreement during the first quarter of Fiscal 2023 as extended negotiations with the potential buyer had been discontinued. The Company continues to pursue the sale of its energy marketing business in France, as well as the wind-down of its energy marketing business located in Belgium and the Netherlands. At December 31, 2022, the sale of our energy marketing business in France was not considered probable of occurring within one year and, as such, assets and liabilities associated with this business were not classified as held for sale on the Condensed Consolidated Balance Sheet. During the three months ended December 31, 2022, the Company recorded a $19 pre-tax ($15 after-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 segment.

Inventories

Inventories	3 Months Ended
	Dec. 31, 2022
Inventory Disclosure [Abstract]
Inventories	Note 6 — Inventories Inventories comprise the following: December 31, September 30, December 31, Non-utility LPG and natural gas $ 310 $ 335 $ 352 Gas Utility natural gas 129 166 65 Energy certificates 78 70 60 Materials, supplies and other 101 94 71 Total inventories $ 618 $ 665 $ 548

Utility Regulatory Assets and L

Utility Regulatory Assets and Liabilities and Regulatory Matters	3 Months Ended
	Dec. 31, 2022
Regulated Operations [Abstract]
Utility Regulatory Assets and Liabilities and Regulatory Matters	Note 7 — Utility Regulatory Assets and Liabilities and Regulatory Matters For a description of the Company’s regulatory assets and liabilities, other than those described below, see Note 9 in the Company’s 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: December 31, September 30, December 31, Regulatory assets (a): Income taxes recoverable $ 93 $ 83 $ 145 Underfunded pension plans 114 114 106 Environmental costs 36 37 57 Deferred fuel and power costs 71 32 29 Removal costs, net 25 22 23 Other 54 52 52 Total regulatory assets $ 393 $ 340 $ 412 Regulatory liabilities (a): Postretirement benefit overcollections $ 11 $ 11 $ 13 Deferred fuel and power refunds 3 3 1 State tax benefits — distribution system repairs 39 38 33 Excess federal deferred income taxes 264 279 285 Other 3 4 14 Total regulatory liabilities $ 320 $ 335 $ 346 (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 new PGA rate increase to customers, delayed the effective date in 2022 from November 1 to December 1 and deferred $12 in under-recovery of gas cost in determining the rates to be charged to the various customer classes effective December 1, 2022. Additionally, 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 to only 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 December 31, 2022, September 30, 2022 and December 31, 2021 were $(17), $5 and $2, respectively. Other Regulatory Matters UGI Utilities. On January 27, 2023, Electric Utility filed a rate 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. However, the PAPUC typically suspends the effective date for general base rate proceedings for a period not to exceed nine months after the filing date to allow for the investigation and public hearing. 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 5-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 rate request with the PAPUC to increase its annual base distribution revenues by $9. On October 28, 2021, the PAPUC issued a final Order approving a settlement that permitted Electric Utility, effective November 9, 2021, to increase its base distribution revenues by $6.

Debt

Debt	3 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Debt	Note 8 — Debt UGI International Credit Facilities Agreement. In October 2018, UGI International entered into a five-year unsecured senior facilities agreement with a consortium of banks (the “UGI International Credit Facilities Agreement”), consisting of (1) a €300 variable-rate term loan facility and (2) a €300 multicurrency revolving credit facility. The UGI International Credit Facilities Agreement is scheduled to mature in October 2023. At December 31, 2022, the €300 ($321) variable-rate term loan is reflected in “Current maturities of long-term debt” on the Condensed Consolidated Balance Sheet. 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 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, as borrower, with a group of lenders. The Mountaineer 2023 Credit Agreement amends and restates a previous credit agreement and provides for borrowings up to $150, including a $20 sublimit for letters of credit. Mountaineer may request an increase in the amount of loan commitments to a maximum aggregate amount of $250, subject to certain terms and conditions. Borrowings under the Mountaineer 2023 Credit Agreement can be used to finance the working capital needs of Mountaineer and for general corporate purposes. The Mountaineer 2023 Credit Agreement is scheduled to expire in November 2024, with an option to extend the maturity date. 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 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.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 9 — Commitments and Contingencies Environmental Matters UGI Utilities From the late 1800s through the mid-1900s, UGI Utilities and its former subsidiaries owned and operated a number of MGPs prior to the general availability of natural gas. Some constituents of coal tars and other residues of the manufactured gas process are today considered hazardous substances under the Superfund Law and may be present on the sites of former MGPs. Between 1882 and 1953, UGI Utilities owned the stock of subsidiary gas companies in Pennsylvania and elsewhere and also operated the businesses of some gas companies under agreement. By the early 1950s, UGI Utilities divested all of its utility operations other than certain gas and electric operations. Beginning in 2006 and 2008, UGI Utilities also owned and operated two acquired subsidiaries, with similar histories of owning, and in some cases operating, MGPs in Pennsylvania. UGI Utilities is subject to a COA with the PADEP to address the remediation of specified former MGP sites in Pennsylvania, which is scheduled to terminate at the end of 2031. In accordance with the COA, UGI Utilities is required to either obtain a certain number of points per calendar year based on defined eligible environmental investigatory and/or remedial activities at the MGPs, or make expenditures for such activities in an amount equal to an annual environmental minimum expenditure threshold. The annual minimum expenditure threshold of the COA is $5. The COA permits the transfer of the specified wells, with related costs counted towards the annual minimum expenditure. At December 31, 2022, September 30, 2022 and December 31, 2021, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the current COA and the predecessor agreements totaled $54, $53 and $50, respectively. We do not expect the costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to UGI Utilities’ results of operations because UGI Utilities receives ratemaking recovery of actual environmental investigation and remediation costs associated with the sites covered by the COA. This ratemaking recognition reconciles the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. As such, UGI Utilities has recorded an associated regulatory asset for these costs because recovery of these costs from customers is probable (see Note 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 December 31, 2022, the Partnership has an undiscounted environmental remediation liability of $8 related to the site. Our share of the actual remediation costs could be significantly more or less than the accrued amount. Although we cannot predict the final results of these pending claims and legal actions, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our financial statements. In addition to the matters described above, there are other pending claims and legal actions arising in the normal course of our businesses. Although we cannot predict the final results of these pending claims and legal actions, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our financial statements.

Defined Benefit Pension and Oth

Defined Benefit Pension and Other Postretirement Plans	3 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
Defined Benefit Pension and Other Postretirement Plans	Note 10 — Defined Benefit Pension and Other Postretirement Plans The Company maintains defined benefit 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 (expense) income, net” on the Condensed Consolidated Statements of Income. Other postretirement benefit cost was not material for all periods presented. Net periodic pension cost includes the following components: Three Months Ended December 31, 2022 2021 Service cost $ 2 $ 4 Interest cost 9 6 Expected return on plan assets (11) (12) Amortization of: Actuarial (gain) loss (1) 2 Net benefit $ (1) $ —

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 11 — Fair Value Measurements Recurring Fair Value Measurements The following table presents, on a gross basis, our financial assets and liabilities, including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy: Asset (Liability) Level 1 Level 2 Level 3 Total December 31, 2022: Derivative instruments: Assets: Commodity contracts $ 345 $ 329 $ — $ 674 Foreign currency contracts $ — $ 35 $ — $ 35 Interest rate contracts $ — $ 63 $ — $ 63 Liabilities: Commodity contracts $ (297) $ (152) $ — $ (449) Foreign currency contracts $ — $ (4) $ — $ (4) Non-qualified supplemental postretirement grantor trust investments (a) $ 46 $ — $ — $ 46 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 December 31, 2021: Derivative instruments: Assets: Commodity contracts $ 411 $ 711 $ — $ 1,122 Foreign currency contracts $ — $ 29 $ — $ 29 Interest rate contracts $ — $ 5 $ — $ 5 Liabilities: Commodity contracts $ (160) $ (18) $ — $ (178) Foreign currency contracts $ — $ (7) $ — $ (7) Interest rate contracts $ — $ (17) $ — $ (17) Non-qualified supplemental postretirement grantor trust investments (a) $ 52 $ — $ — $ 52 (a) Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans. (b) Includes derivative assets and liabilities held-for-sale associated with the October 2022 sale of the U.K. energy marketing business (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 actual realized value at which these contracts will settle could vary significantly compared to the fair values reflected at September 30, 2022. The fair values of investments held in grantor trusts are derived from quoted market prices as substantially all of the investments in these trusts have active markets. Other Financial Instruments The carrying amounts of other financial instruments included in current assets and current liabilities (except for current maturities of long-term debt) approximate their fair values because of their short-term nature. We estimate the fair value of long-term debt by using current market rates and by discounting future cash flows using rates available for similar type debt (Level 2). The carrying amounts and estimated fair values of our long-term debt (including current maturities but excluding unamortized debt issuance costs) were as follows: December 31, 2022 September 30, 2022 December 31, 2021 Carrying amount $ 6,759 $ 6,665 $ 6,580 Estimated fair value $ 6,350 $ 6,189 $ 7,048

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	3 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Note 12 — Derivative Instruments and Hedging Activities We are exposed to certain market risks related to our ongoing business operations. Management uses derivative financial and commodity instruments, among other things, to manage: (1) commodity price risk; (2) interest rate risk; and (3) foreign currency exchange rate risk. Although we use derivative financial and commodity instruments to reduce market risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes. The use of derivative instruments is controlled by our risk management and credit policies, which govern, among other things, the derivative instruments we can use, counterparty credit limits and contract authorization limits. Although our commodity derivative instruments extend over a number of years, a significant portion of our commodity derivative instruments economically hedge commodity price risk during the next twelve months. For information on the accounting for our derivative instruments, see Note 2. The following summarizes the types of derivative instruments used by the Company to manage certain market risks: Commodity Price Risk Regulated Utility Operations Natural Gas 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 December 31, 2022, the amount of pre-tax net gains associated with interest rate hedges expected to be reclassified into earnings during the next twelve months is $39. Foreign Currency Exchange Rate Risk Forward Foreign Currency Exchange Contracts In order to reduce the volatility in net income associated with our foreign operations, principally as a result of changes in the USD exchange rate to the euro and British pound sterling, we enter into forward foreign currency exchange contracts. We layer in these foreign currency exchange contracts over a multi-year period to eventually equal approximately 90% of anticipated UGI International foreign currency earnings before income taxes. Because these contracts are not designated as hedging instruments, realized and unrealized gains and losses on these contracts are recorded in “Other non-operating (expense) income, net,” on the Condensed Consolidated Statements of Income. Net Investment Hedges From time to time, we also enter into certain forward foreign currency exchange contracts to reduce the volatility of the USD value of a portion of our UGI International euro-denominated net investments, including anticipated foreign currency denominated dividends. We account for these foreign currency exchange contracts as net investment hedges and all changes in the fair value of these contracts are reported in the cumulative translation adjustment component in AOCI. We use the spot rate method to measure ineffectiveness of our net investment hedges. Concurrent with the repayment of UGI International’s 3.25% Senior Notes on December 7, 2021, we settled an associated net investment hedge having a notional value of €93. Additionally, in May 2022, we restructured certain net investment hedges associated with anticipated foreign currency denominated dividends. Cash flows from these settlements are included in cash flows from investing activities on the Condensed Consolidated Statements of Cash Flows. Our euro-denominated long-term debt has also been designated as net investment hedges, representing a portion of our UGI International euro-denominated net investment. We recognized pre-tax (losses) gains associated with these net investment hedges in the cumulative translation adjustment component in AOCI of $(64) and $13 during the three months ended December 31, 2022 and 2021, respectively. Quantitative Disclosures Related to Derivative Instruments The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at December 31, 2022, September 30, 2022 and December 31, 2021, and the final settlement dates of the Company's open derivative contracts as of December 31, 2022, but excluding those derivatives that qualified for the NPNS exception: Notional Amounts Type Units Settlements Extending Through December 31, 2022 September 30, 2022 December 31, 2021 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms September 2023 15 19 14 Non-utility Operations LPG swaps Gallons September 2025 844 874 732 Natural gas futures, forward, basis swap, options and pipeline contracts (a) Dekatherms October 2027 371 363 382 Electricity forward and futures contracts Kilowatt hours December 2026 2,270 2,446 4,261 Interest Rate Risk: Interest rate swaps Euro N/A € — € 300 € 300 Interest rate swaps USD June 2026 $ 1,354 $ 1,358 $ 1,418 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD August 2025 $ 390 $ 465 $ 415 Net investment hedge forward foreign exchange contracts Euro December 2026 € 331 € 411 € 486 (a) September 30, 2022 includes amounts held-for-sale associated with the October 2022 sale of the U.K. energy marketing business (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 December 31, 2022, the maximum amount of loss, based upon the gross fair values of the derivative instruments, we would incur if these counterparties failed to perform according to the terms of their contracts was $772. 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 December 31, 2022, we had received cash collateral from derivative instrument counterparties totaling $108. 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 December 31, 2022, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material. Offsetting Derivative Assets and Liabilities Derivative assets and liabilities are presented net by counterparty on the Condensed Consolidated Balance Sheets if the right of offset exists. We offset amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against amounts recognized for derivative instruments executed with the same counterparty. Our derivative instruments include both those that are executed on an exchange through brokers and centrally cleared and over-the-counter transactions. Exchange contracts utilize a financial intermediary, exchange or clearinghouse to enter, execute or clear the transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Certain over-the-counter and exchange contracts contain contractual rights of offset through master netting arrangements, derivative clearing agreements and contract default provisions. In addition, the contracts are subject to conditional rights of offset through counterparty nonperformance, insolvency or other conditions. In general, many of our over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral generally include cash or letters of credit. Cash collateral paid by us to our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative liabilities. Cash collateral received by us from our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative assets. Certain other accounts receivable and accounts payable balances recognized on the Condensed Consolidated Balance Sheets with our derivative counterparties are not included in the table below but could reduce our net exposure to such counterparties because such balances are subject to master netting or similar arrangements. Fair Value of Derivative Instruments The following table presents the Company’s derivative assets and liabilities by type, as well as the effects of offsetting: December 31, September 30, December 31, Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 11 $ 57 $ 10 Interest rate contracts 63 66 5 74 123 15 Derivatives subject to PGC and DS mechanisms: Commodity contracts 18 31 10 Derivatives not designated as hedging instruments: Commodity contracts (a) 656 2,202 1,112 Foreign currency contracts 24 62 19 680 2,264 1,131 Total derivative assets — gross 772 2,418 1,156 Gross amounts offset in the balance sheet (239) (295) (116) Cash collateral received (108) (398) (205) Total derivative assets — net $ 425 $ 1,725 $ 835 Derivative liabilities: Derivatives designated as hedging instruments: Foreign currency contracts $ — $ — $ (3) Interest rate contracts — — (17) — — (20) Derivatives subject to PGC and DS mechanisms: Commodity contracts (35) (26) (7) Derivatives not designated as hedging instruments: Commodity contracts (a) (414) (487) (171) Foreign currency contracts (4) (2) (4) (418) (489) (175) Total derivative liabilities — gross (453) (515) (202) Gross amounts offset in the balance sheet 239 295 116 Cash collateral pledged 45 7 — Total derivative liabilities — net $ (169) $ (213) $ (86) (a) September 30, 2022 includes derivative assets and liabilities held-for-sale associated with the October 2022 sale of the U.K. energy marketing business (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 December 31,: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from Cash Flow Hedges: 2022 2021 2022 2021 Interest rate contracts $ 4 $ 12 $ 7 $ (6) Interest expense Net Investment Hedges: Foreign currency contracts $ (23) $ — Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2022 2021 Location of Gain (Loss) Recognized in Income Commodity contracts $ 4 $ 8 Revenues Commodity contracts (1,326) (273) Cost of sales Commodity contracts 3 — Other operating income, net Foreign currency contracts (32) 8 Other non-operating (expense) income, net Total $ (1,351) $ (257) We are also a party to a number of other contracts that have elements of a derivative instrument. However, these contracts qualify for NPNS exception accounting because they provide for the delivery of products or services in quantities that are expected to be used in the normal course of operating our business and the price in the contract is based on an underlying that is directly associated with the price of the product or service being purchased or sold. These contracts include, among others, binding purchase orders, contracts that provide for the purchase and delivery, or sale, of energy products, and service contracts that require the counterparty to provide commodity storage, transportation or capacity service to meet our normal sales commitments.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	3 Months Ended
	Dec. 31, 2022
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	Note 13 — Accumulated Other Comprehensive Income (Loss) The tables below present changes in AOCI, net of tax: Three Months Ended December 31, 2022 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2022 $ 14 $ 37 $ (431) $ (380) Other comprehensive income before reclassification adjustments — 3 151 154 Amounts reclassified from AOCI — (5) — (5) Other comprehensive (loss) income attributable to UGI — (2) 151 149 AOCI — December 31, 2022 $ 14 $ 35 $ (280) $ (231) Three Months Ended December 31, 2021 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2021 $ (17) $ (33) $ (90) $ (140) Other comprehensive income (loss) before reclassification adjustments — 10 (32) (22) Amounts reclassified from AOCI 2 4 — 6 Other comprehensive income (loss) attributable to UGI 2 14 (32) (16) AOCI — December 31, 2021 $ (15) $ (19) $ (122) $ (156)

Segment Information

Segment Information	3 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Segment Information	Note 14 — Segment Information Our operations comprise four reportable segments generally based upon products or services sold, geographic location and regulatory environment: (1) AmeriGas Propane; (2) UGI International; (3) Midstream & Marketing; and (4) Utilities. Corporate & Other includes certain items that are excluded from our CODM’s assessment of segment performance (see below for further details on these items). Corporate & Other also includes the net expenses of UGI’s captive general liability insurance company, UGI’s corporate headquarters facility and UGI’s unallocated corporate and general expenses as well as interest expense on UGI debt that is not allocated. Corporate & Other assets principally comprise cash and cash equivalents of UGI and its captive insurance company, and UGI corporate headquarters’ assets. The accounting policies of our reportable segments are the same as those described in Note 2, “Summary of Significant Accounting Policies,” in the Company’s 2022 Annual Report. Three Months Ended December 31, 2022 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 2,759 $ — $ 766 $ 877 $ 554 $ 559 $ 3 Intersegment revenues $ — $ (149) (b) $ — $ — $ 115 $ 33 $ 1 Cost of sales $ 3,106 $ (149) (b) $ 386 $ 662 $ 514 $ 329 $ 1,364 Operating (loss) income $ (1,204) $ 1 $ 110 $ 56 $ 106 $ 126 $ (1,603) Income from equity investees 1 — — — 1 — — Other non-operating (loss) income, net (28) — — 10 — 2 (40) (Loss) earnings before interest expense and income taxes (1,231) 1 110 66 107 128 (1,643) Interest expense (92) — (43) (7) (11) (21) (10) (Loss) income before income taxes $ (1,323) $ 1 $ 67 $ 59 $ 96 $ 107 $ (1,653) Depreciation and amortization $ 131 $ — $ 44 $ 28 $ 21 $ 37 $ 1 Capital expenditures (including the effects of accruals) $ 178 $ — $ 23 $ 27 $ 11 $ 117 $ — As of December 31, 2022 Total assets $ 17,128 $ (252) $ 4,331 $ 3,889 $ 3,298 $ 5,680 $ 182 Three Months Ended December 31, 2021 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 2,673 $ — $ 778 $ 1,049 $ 441 $ 396 $ 9 Intersegment revenues $ — $ (118) (b) $ — $ — $ 94 $ 23 $ 1 Cost of sales $ 2,120 $ (117) (b) $ 418 $ 793 $ 413 $ 200 $ 413 Operating (loss) income $ (68) $ — $ 86 $ 78 $ 74 $ 96 $ (402) Income from equity investees 8 — — — 8 — — Loss on extinguishments of debt (11) — — — — — (11) Other non-operating income, net 10 — — 4 — 2 4 (Loss) earnings before interest expense and income taxes (61) — 86 82 82 98 (409) Interest expense (81) — (41) (7) (10) (16) (7) (Loss) income before income taxes $ (142) $ — $ 45 $ 75 $ 72 $ 82 $ (416) Depreciation and amortization $ 129 $ — $ 44 $ 31 $ 19 $ 35 $ — Capital expenditures (including the effects of accruals) $ 175 $ — $ 35 $ 23 $ 6 $ 111 $ — As of December 31, 2021 Total assets $ 16,800 $ (269) $ 4,614 $ 4,197 $ 2,999 $ 5,071 $ 188 (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 December 31, 2022 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 2 $ 2 Net losses on commodity derivative instruments not associated with current-period transactions Cost of sales $ (12) $ (1,169) $ (183) Net gains on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ (2) $ — Unrealized losses on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ (40) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ (7) $ — $ — 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) $ — Three Months Ended December 31, 2021 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 3 $ 7 Net losses on commodity derivative instruments not associated with current-period transactions Cost of sales $ (69) $ (212) $ (132) Unrealized gain on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 6 $ — Loss on extinguishment of debt Loss on extinguishment of debt $ — $ (11) $ — (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, Utilities and AmeriGas Propane.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Dec. 31, 2022
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 from equity method investees" on the Condensed Consolidated Statements of Income. Our equity method investments primarily comprise Pine Run and other equity method investments in biomass and other renewable energy projects.
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.
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.
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 new guidance 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)	3 Months Ended
	Dec. 31, 2022
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. December 31, December 31, Cash and cash equivalents $ 317 $ 334 Restricted cash 227 24 Cash, cash equivalents and restricted cash $ 544 $ 358
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. December 31, December 31, Cash and cash equivalents $ 317 $ 334 Restricted cash 227 24 Cash, cash equivalents and restricted cash $ 544 $ 358
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 2022 2021 Denominator (thousands of shares): Weighted-average common shares outstanding — basic 209,934 209,673 Incremental shares issuable for stock options, common stock awards and Equity Units (a) — — Weighted-average common shares outstanding — diluted 209,934 209,673 (a) For the three months ended December 31, 2022 and 2021, 6,431 and 6,486, respectively, of such shares have been excluded as these incremental shares would be antidilutive due to the net losses for the periods presented. At December 31, 2022 and 2021, these incremental shares exclude the effects of 6,625 and 3,347 shares, respectively, associated with outstanding stock option awards because their effect was antidilutive.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	3 Months Ended
	Dec. 31, 2022
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 December 31, 2022 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 336 $ — $ — $ — $ — $ 336 $ — Commercial & Industrial 132 — — — — 132 — Large delivery service 47 — — — — 47 — Off-system sales and capacity releases 32 (33) — — — 65 — Other 10 — — — — 10 — Total Utility 557 (33) — — — 590 — Non-Utility: LPG: Retail 1,116 — 634 482 — — — Wholesale 102 — 51 51 — — — Energy Marketing 778 (77) — 318 537 — — Midstream: Pipeline 65 — — — 65 — — Peaking 17 (39) — — 56 — — Other 3 — — — 3 — — Electricity Generation 8 — — — 8 — — Other 75 — 57 18 — — — Total Non-Utility 2,164 (116) 742 869 669 — — Total revenues from contracts with customers 2,721 (149) 742 869 669 590 — Other revenues (b) 38 — 24 8 — 2 4 Total revenues $ 2,759 $ (149) $ 766 $ 877 $ 669 $ 592 $ 4 Three Months Ended December 31, 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 234 $ — $ — $ — $ — $ 234 $ — Commercial & Industrial 94 — — — — 94 — Large delivery service 43 — — — — 43 — Off-system sales and capacity releases 19 (22) — — — 41 — Other 5 (1) — — — 6 — Total Utility 395 (23) — — — 418 — Non-Utility: LPG: Retail 1,250 — 646 604 — — — Wholesale 140 — 56 84 — — — Energy Marketing 714 (55) — 333 436 — — Midstream: Pipeline 46 — — — 46 — — Peaking 6 (39) — — 45 — — Other 2 — — — 2 — — Electricity Generation 5 — — — 5 — — Other 78 — 58 20 — — — Total Non-Utility 2,241 (94) 760 1,041 534 — — Total revenues from contracts with customers 2,636 (117) 760 1,041 534 418 — Other revenues (b) 37 (1) 18 8 1 1 10 Total revenues $ 2,673 $ (118) $ 778 $ 1,049 $ 535 $ 419 $ 10 (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 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)	3 Months Ended
	Dec. 31, 2022
Inventory Disclosure [Abstract]
Schedule of Components of Inventories	Inventories comprise the following: December 31, September 30, December 31, Non-utility LPG and natural gas $ 310 $ 335 $ 352 Gas Utility natural gas 129 166 65 Energy certificates 78 70 60 Materials, supplies and other 101 94 71 Total inventories $ 618 $ 665 $ 548

Utility Regulatory Assets and_2

Utility Regulatory Assets and Liabilities and Regulatory Matters (Tables)	3 Months Ended
	Dec. 31, 2022
Regulated Operations [Abstract]
Schedule of Regulatory Assets	The following regulatory assets and liabilities associated with Utilities are included on the Condensed Consolidated Balance Sheets: December 31, September 30, December 31, Regulatory assets (a): Income taxes recoverable $ 93 $ 83 $ 145 Underfunded pension plans 114 114 106 Environmental costs 36 37 57 Deferred fuel and power costs 71 32 29 Removal costs, net 25 22 23 Other 54 52 52 Total regulatory assets $ 393 $ 340 $ 412 Regulatory liabilities (a): Postretirement benefit overcollections $ 11 $ 11 $ 13 Deferred fuel and power refunds 3 3 1 State tax benefits — distribution system repairs 39 38 33 Excess federal deferred income taxes 264 279 285 Other 3 4 14 Total regulatory liabilities $ 320 $ 335 $ 346 (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: December 31, September 30, December 31, Regulatory assets (a): Income taxes recoverable $ 93 $ 83 $ 145 Underfunded pension plans 114 114 106 Environmental costs 36 37 57 Deferred fuel and power costs 71 32 29 Removal costs, net 25 22 23 Other 54 52 52 Total regulatory assets $ 393 $ 340 $ 412 Regulatory liabilities (a): Postretirement benefit overcollections $ 11 $ 11 $ 13 Deferred fuel and power refunds 3 3 1 State tax benefits — distribution system repairs 39 38 33 Excess federal deferred income taxes 264 279 285 Other 3 4 14 Total regulatory liabilities $ 320 $ 335 $ 346 (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)	3 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
Schedule of Components of Net Periodic Pension Cost	Net periodic pension cost includes the following components: Three Months Ended December 31, 2022 2021 Service cost $ 2 $ 4 Interest cost 9 6 Expected return on plan assets (11) (12) Amortization of: Actuarial (gain) loss (1) 2 Net benefit $ (1) $ —

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Dec. 31, 2022
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 December 31, 2022: Derivative instruments: Assets: Commodity contracts $ 345 $ 329 $ — $ 674 Foreign currency contracts $ — $ 35 $ — $ 35 Interest rate contracts $ — $ 63 $ — $ 63 Liabilities: Commodity contracts $ (297) $ (152) $ — $ (449) Foreign currency contracts $ — $ (4) $ — $ (4) Non-qualified supplemental postretirement grantor trust investments (a) $ 46 $ — $ — $ 46 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 December 31, 2021: Derivative instruments: Assets: Commodity contracts $ 411 $ 711 $ — $ 1,122 Foreign currency contracts $ — $ 29 $ — $ 29 Interest rate contracts $ — $ 5 $ — $ 5 Liabilities: Commodity contracts $ (160) $ (18) $ — $ (178) Foreign currency contracts $ — $ (7) $ — $ (7) Interest rate contracts $ — $ (17) $ — $ (17) Non-qualified supplemental postretirement grantor trust investments (a) $ 52 $ — $ — $ 52 (a) Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans. (b) Includes derivative assets and liabilities held-for-sale associated with the October 2022 sale of the U.K. energy marketing business (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: December 31, 2022 September 30, 2022 December 31, 2021 Carrying amount $ 6,759 $ 6,665 $ 6,580 Estimated fair value $ 6,350 $ 6,189 $ 7,048

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Notional Amounts Related to Open Derivative Contracts	The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at December 31, 2022, September 30, 2022 and December 31, 2021, and the final settlement dates of the Company's open derivative contracts as of December 31, 2022, but excluding those derivatives that qualified for the NPNS exception: Notional Amounts Type Units Settlements Extending Through December 31, 2022 September 30, 2022 December 31, 2021 Commodity Price Risk: Regulated Utility Operations PA Gas Utility NYMEX natural gas futures and option contracts Dekatherms September 2023 15 19 14 Non-utility Operations LPG swaps Gallons September 2025 844 874 732 Natural gas futures, forward, basis swap, options and pipeline contracts (a) Dekatherms October 2027 371 363 382 Electricity forward and futures contracts Kilowatt hours December 2026 2,270 2,446 4,261 Interest Rate Risk: Interest rate swaps Euro N/A € — € 300 € 300 Interest rate swaps USD June 2026 $ 1,354 $ 1,358 $ 1,418 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD August 2025 $ 390 $ 465 $ 415 Net investment hedge forward foreign exchange contracts Euro December 2026 € 331 € 411 € 486 (a) September 30, 2022 includes amounts held-for-sale associated with the October 2022 sale of the U.K. energy marketing business (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: December 31, September 30, December 31, Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 11 $ 57 $ 10 Interest rate contracts 63 66 5 74 123 15 Derivatives subject to PGC and DS mechanisms: Commodity contracts 18 31 10 Derivatives not designated as hedging instruments: Commodity contracts (a) 656 2,202 1,112 Foreign currency contracts 24 62 19 680 2,264 1,131 Total derivative assets — gross 772 2,418 1,156 Gross amounts offset in the balance sheet (239) (295) (116) Cash collateral received (108) (398) (205) Total derivative assets — net $ 425 $ 1,725 $ 835 Derivative liabilities: Derivatives designated as hedging instruments: Foreign currency contracts $ — $ — $ (3) Interest rate contracts — — (17) — — (20) Derivatives subject to PGC and DS mechanisms: Commodity contracts (35) (26) (7) Derivatives not designated as hedging instruments: Commodity contracts (a) (414) (487) (171) Foreign currency contracts (4) (2) (4) (418) (489) (175) Total derivative liabilities — gross (453) (515) (202) Gross amounts offset in the balance sheet 239 295 116 Cash collateral pledged 45 7 — Total derivative liabilities — net $ (169) $ (213) $ (86) (a) September 30, 2022 includes derivative assets and liabilities held-for-sale associated with the October 2022 sale of the U.K. energy marketing business (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 December 31,: Gain (Loss) Gain (Loss) Location of Gain (Loss) Reclassified from Cash Flow Hedges: 2022 2021 2022 2021 Interest rate contracts $ 4 $ 12 $ 7 $ (6) Interest expense Net Investment Hedges: Foreign currency contracts $ (23) $ — Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2022 2021 Location of Gain (Loss) Recognized in Income Commodity contracts $ 4 $ 8 Revenues Commodity contracts (1,326) (273) Cost of sales Commodity contracts 3 — Other operating income, net Foreign currency contracts (32) 8 Other non-operating (expense) income, net Total $ (1,351) $ (257)

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	3 Months Ended
	Dec. 31, 2022
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income	The tables below present changes in AOCI, net of tax: Three Months Ended December 31, 2022 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2022 $ 14 $ 37 $ (431) $ (380) Other comprehensive income before reclassification adjustments — 3 151 154 Amounts reclassified from AOCI — (5) — (5) Other comprehensive (loss) income attributable to UGI — (2) 151 149 AOCI — December 31, 2022 $ 14 $ 35 $ (280) $ (231) Three Months Ended December 31, 2021 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2021 $ (17) $ (33) $ (90) $ (140) Other comprehensive income (loss) before reclassification adjustments — 10 (32) (22) Amounts reclassified from AOCI 2 4 — 6 Other comprehensive income (loss) attributable to UGI 2 14 (32) (16) AOCI — December 31, 2021 $ (15) $ (19) $ (122) $ (156)

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Schedule of Segment Reporting Information	Three Months Ended December 31, 2022 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 2,759 $ — $ 766 $ 877 $ 554 $ 559 $ 3 Intersegment revenues $ — $ (149) (b) $ — $ — $ 115 $ 33 $ 1 Cost of sales $ 3,106 $ (149) (b) $ 386 $ 662 $ 514 $ 329 $ 1,364 Operating (loss) income $ (1,204) $ 1 $ 110 $ 56 $ 106 $ 126 $ (1,603) Income from equity investees 1 — — — 1 — — Other non-operating (loss) income, net (28) — — 10 — 2 (40) (Loss) earnings before interest expense and income taxes (1,231) 1 110 66 107 128 (1,643) Interest expense (92) — (43) (7) (11) (21) (10) (Loss) income before income taxes $ (1,323) $ 1 $ 67 $ 59 $ 96 $ 107 $ (1,653) Depreciation and amortization $ 131 $ — $ 44 $ 28 $ 21 $ 37 $ 1 Capital expenditures (including the effects of accruals) $ 178 $ — $ 23 $ 27 $ 11 $ 117 $ — As of December 31, 2022 Total assets $ 17,128 $ (252) $ 4,331 $ 3,889 $ 3,298 $ 5,680 $ 182 Three Months Ended December 31, 2021 Total Eliminations AmeriGas UGI International Midstream & Marketing Utilities Corporate Revenues from external customers $ 2,673 $ — $ 778 $ 1,049 $ 441 $ 396 $ 9 Intersegment revenues $ — $ (118) (b) $ — $ — $ 94 $ 23 $ 1 Cost of sales $ 2,120 $ (117) (b) $ 418 $ 793 $ 413 $ 200 $ 413 Operating (loss) income $ (68) $ — $ 86 $ 78 $ 74 $ 96 $ (402) Income from equity investees 8 — — — 8 — — Loss on extinguishments of debt (11) — — — — — (11) Other non-operating income, net 10 — — 4 — 2 4 (Loss) earnings before interest expense and income taxes (61) — 86 82 82 98 (409) Interest expense (81) — (41) (7) (10) (16) (7) (Loss) income before income taxes $ (142) $ — $ 45 $ 75 $ 72 $ 82 $ (416) Depreciation and amortization $ 129 $ — $ 44 $ 31 $ 19 $ 35 $ — Capital expenditures (including the effects of accruals) $ 175 $ — $ 35 $ 23 $ 6 $ 111 $ — As of December 31, 2021 Total assets $ 16,800 $ (269) $ 4,614 $ 4,197 $ 2,999 $ 5,071 $ 188 (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 December 31, 2022 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 2 $ 2 Net losses on commodity derivative instruments not associated with current-period transactions Cost of sales $ (12) $ (1,169) $ (183) Net gains on commodity derivative instruments not associated with current-period transactions Other operating income, net $ — $ (2) $ — Unrealized losses on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ (40) $ — AmeriGas operations enhancement for growth project Operating and administrative expenses $ (7) $ — $ — 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) $ — Three Months Ended December 31, 2021 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ 3 $ 7 Net losses on commodity derivative instruments not associated with current-period transactions Cost of sales $ (69) $ (212) $ (132) Unrealized gain on foreign currency derivative instruments Other non-operating (expense) income, net $ — $ 6 $ — Loss on extinguishment of debt Loss on extinguishment of debt $ — $ (11) $ — (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	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021	Sep. 30, 2021
Accounting Policies [Abstract]
Cash and cash equivalents	$ 317	$ 405	$ 334
Restricted cash	227	64	24
Cash, cash equivalents and restricted cash	$ 544	$ 469	$ 358	$ 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
	Dec. 31, 2022	Dec. 31, 2021
Denominator (thousands of shares):
Weighted-average common shares outstanding - basic (in shares)	209,934	209,673
Incremental shares issuable for stock options, common stock awards and Equity Units (in shares)	0	0
Weighted-average common shares outstanding - diluted (in shares)	209,934	209,673
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	6,431	6,486
Stock options
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	6,625	3,347

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Sep. 30, 2022
Schedule of Equity Method Investments [Line Items]
Goodwill	$ 3,697	$ 3,748	$ 3,612
AmeriGas Propane
Schedule of Equity Method Investments [Line Items]
Percentage of fair value exceeding carrying value	30%
Goodwill	$ 2,000
Pennant | Energy Services
Schedule of Equity Method Investments [Line Items]
Equity interest acquired	53%
Purchase price	$ 61
Pine Run Midstream, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent	49%
Equity method investments	$ 71	62
Pennant
Schedule of Equity Method Investments [Line Items]
Equity method investments		99
Other Equity Investments
Schedule of Equity Method Investments [Line Items]
Loss on extinguishment of debt	$ 104	$ 22

Accounting Changes (Details)

Accounting Changes (Details) - USD ($) $ in Millions	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021	Sep. 30, 2021
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Beneficial conversion feature	$ 5,188	$ 6,074	$ 5,359
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	162	214	$ 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
Retained Earnings
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Beneficial conversion feature	$ 3,808	4,841	$ 3,908	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

Revenue from Contracts with C_3

Revenue from Contracts with Customers - Disaggregated Revenues by Reportable Segment (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 2,721	$ 2,636
Other revenues	38	37
Total revenues	2,759	2,673
Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	557	395
Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	336	234
Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	132	94
Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	47	43
Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	32	19
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	10	5
Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2,164	2,241
Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,116	1,250
Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	102	140
Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	778	714
Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	65	46
Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	17	6
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	3	2
Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	8	5
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	75	78
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(149)	(117)
Other revenues	0	(1)
Total revenues	(149)	(118)
Eliminations | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(33)	(23)
Eliminations | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(33)	(22)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	(1)
Eliminations | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(116)	(94)
Eliminations | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(77)	(55)
Eliminations | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(39)	(39)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Eliminations | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues	0	0
Eliminations | UGI International
Disaggregation of Revenue [Line Items]
Total revenues	0	0
Eliminations | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues	115	94
Eliminations | Utilities
Disaggregation of Revenue [Line Items]
Total revenues	33	23
Operating Segments | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	742	760
Other revenues	24	18
Total revenues	766	778
Operating Segments | AmeriGas Propane | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	742	760
Operating Segments | AmeriGas Propane | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	634	646
Operating Segments | AmeriGas Propane | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	51	56
Operating Segments | AmeriGas Propane | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	57	58
Operating Segments | UGI International
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	869	1,041
Other revenues	8	8
Total revenues	877	1,049
Operating Segments | UGI International | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | UGI International | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | UGI International | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | UGI International | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | UGI International | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | UGI International | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	869	1,041
Operating Segments | UGI International | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	482	604
Operating Segments | UGI International | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	51	84
Operating Segments | UGI International | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	318	333
Operating Segments | UGI International | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | UGI International | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | UGI International | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	18	20
Operating Segments | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	669	534
Other revenues	0	1
Total revenues	669	535
Operating Segments | Midstream & Marketing | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Midstream & Marketing | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Midstream & Marketing | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Midstream & Marketing | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Midstream & Marketing | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Midstream & Marketing | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	669	534
Operating Segments | Midstream & Marketing | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Midstream & Marketing | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Midstream & Marketing | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	537	436
Operating Segments | Midstream & Marketing | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	65	46
Operating Segments | Midstream & Marketing | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	56	45
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	3	2
Operating Segments | Midstream & Marketing | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	8	5
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Utilities
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	590	418
Other revenues	2	1
Total revenues	592	419
Operating Segments | Utilities | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	590	418
Operating Segments | Utilities | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	336	234
Operating Segments | Utilities | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	132	94
Operating Segments | Utilities | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	47	43
Operating Segments | Utilities | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	65	41
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	10	6
Operating Segments | Utilities | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Utilities | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Utilities | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Utilities | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Utilities | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Utilities | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Utilities | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Operating Segments | Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Other revenues	4	10
Total revenues	4	10
Corporate & Other | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 0	$ 0

Revenue from Contracts with C_4

Revenue from Contracts with Customers - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Sep. 30, 2022
Disaggregation of Revenue [Line Items]
Contract liabilities	$ 143	$ 129	$ 164
Revenue recognized	81	$ 70
Midstream & Marketing
Disaggregation of Revenue [Line Items]
Expected revenue	2,300
Utilities
Disaggregation of Revenue [Line Items]
Expected revenue	$ 200

UGI International Energy Mark_2

UGI International Energy Marketing Businesses (Details) - Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Oct. 21, 2022	Sep. 30, 2022
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
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
After tax impairment charges	$ 15

Inventories - Components of Inv

Inventories - Components of Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Inventory
Total inventories	$ 618	$ 665	$ 548
Non-utility LPG and natural gas
Inventory
Total inventories	310	335	352
Gas Utility natural gas
Inventory
Total inventories	129	166	65
Energy certificates
Inventory
Total inventories	78	70	60
Materials, supplies and other
Inventory
Total inventories	$ 101	$ 94	$ 71

Utility Regulatory Assets and_3

Utility Regulatory Assets and Liabilities and Regulatory Matters - Schedule of Regulatory Assets and Liabilities (Details) - Utilities - USD ($) $ in Millions	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Regulatory Assets
Regulatory assets	$ 393	$ 340	$ 412
Regulatory Liabilities
Regulatory liabilities	320	335	346
Postretirement benefit overcollections
Regulatory Liabilities
Regulatory liabilities	11	11	13
Deferred fuel and power refunds
Regulatory Liabilities
Regulatory liabilities	3	3	1
State tax benefits — distribution system repairs
Regulatory Liabilities
Regulatory liabilities	39	38	33
Excess federal deferred income taxes
Regulatory Liabilities
Regulatory liabilities	264	279	285
Other
Regulatory Liabilities
Regulatory liabilities	3	4	14
Income taxes recoverable
Regulatory Assets
Regulatory assets	93	83	145
Underfunded pension plans
Regulatory Assets
Regulatory assets	114	114	106
Environmental costs
Regulatory Assets
Regulatory assets	36	37	57
Deferred fuel and power costs
Regulatory Assets
Regulatory assets	71	32	29
Removal costs, net
Regulatory Assets
Regulatory assets	25	22	23
Other
Regulatory Assets
Regulatory assets	$ 54	$ 52	$ 52

Utility Regulatory Assets and_4

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

3 Months Ended

12 Months Ended

Jan. 27, 2023

Nov. 16, 2022

Nov. 01, 2022

Sep. 15, 2022

Jul. 29, 2022

Jan. 28, 2022

Nov. 09, 2021

Feb. 08, 2021

Dec. 31, 2022

Dec. 31, 2021

Sep. 30, 2022

Dec. 01, 2022

Regulatory Assets

Net unrealized gains

$ (1,402,000)

$ (397,000)

WVPSC

Regulatory Assets

Under-recovery of gas cost

$ 12,000

Gas Utility

Regulatory Assets

Net unrealized gains

$ (17,000)

$ 2,000

$ 5,000

Gas Utility | PAPUC

Regulatory Assets

Requested rate increase

$ 83,000

Gas Utility | PAPUC | Joint Petition

Regulatory Assets

Requested rate increase

$ 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

38,000

Gas Utility | PAPUC | Beginning October 1, 2023

Regulatory Assets

Requested rate increase

$ 11,000

Gas Utility | PAPUC | Weather Normalization Adjustment Rider

Regulatory Assets

Rate period

5 years

Approved rate

3%

Utilities | PAPUC

Regulatory Assets

Requested rate increase

$ 9,000

Approved rate increase

$ 6,000

Utilities | PAPUC | Subsequent event

Regulatory Assets

Requested rate increase

$ 11,000

Mountaineer | WVPSC | Over 2023 - 2027

Regulatory Assets

Requested rate increase

$ 354,000

Mountaineer | WVPSC | Calendar Year 2023

Regulatory Assets

Requested rate increase

$ 64,000

Mountaineer | WVPSC | 2023 IREP

Regulatory Assets

Requested rate increase

$ 22,000

Mountaineer | WVPSC | 2021 IREP

Regulatory Assets

Requested rate increase

$ 1,000

Debt (Details)

Debt (Details) - Line of Credit		1 Months Ended
	Oct. 20, 2022 USD ($)	Oct. 31, 2018 EUR (€)	Dec. 31, 2022 EUR (€)	Dec. 31, 2022 USD ($)	Dec. 13, 2022 USD ($)
UGI International Credit Facilities Agreement | Unsecured Debt
Debt Instrument [Line Items]
Debt term		5 years
Maximum borrowing capacity | €		€ 300,000,000
Line of Credit, Current			€ 300,000,000	$ 321,000,000
UGI Utilities Credit Agreement | Utilities | Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity					$ 425,000,000
UGI Utilities Credit Agreement | Utilities | Revolving Credit Facility | SOFR
Debt Instrument [Line Items]
Basis spread on variable rate	0.10%
Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 150,000,000
Option to increase capacity	$ 250,000,000
Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | SOFR
Debt Instrument [Line Items]
Basis spread on variable rate	1%
Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | SOFR | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate	1%
Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | SOFR | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate	2.25%
Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | Federal Funds Rate
Debt Instrument [Line Items]
Basis spread on variable rate	0.50%
Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | Base Rate Margin | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate	0%
Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | Base Rate Margin | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate	1.25%
Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | One-Month Interest Period (SOFR)
Debt Instrument [Line Items]
Basis spread on variable rate	0.10%
Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | Three-Month Interest Period (SOFR)
Debt Instrument [Line Items]
Basis spread on variable rate	0.15%
Mountaineer Credit Agreement | Mountaineer | Revolving Credit Facility | Six-Month Interest Period (SOFR)
Debt Instrument [Line Items]
Basis spread on variable rate	0.25%
Mountaineer Credit Agreement | Mountaineer | Letters of Credit
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 20,000,000

Commitments and Contingencies (

Commitments and Contingencies (Details)	3 Months Ended	12 Months Ended
	Dec. 31, 2022 USD ($) subsidiary	Sep. 30, 2017 USD ($) record_of_decision	Sep. 30, 2022 USD ($)	Dec. 31, 2021 USD ($)
Loss Contingencies
Environmental expenditures cap during calendar year	$ 5,000,000
CPG, PNG and UGI Gas COAs
Loss Contingencies
Accrual for environmental loss contingencies	$ 54,000,000		$ 53,000,000	$ 50,000,000
Utilities
Loss Contingencies
Number of subsidiaries acquired with similar histories | subsidiary	2
AmeriGas OLP | Saranac Lake, New York | NYDEC ROD
Loss Contingencies
Accrual for environmental loss contingencies	$ 8,000,000
Loss contingency, number of remediation plans | record_of_decision		3
Estimated remediation plan cost		$ 28,000,000

Defined Benefit Pension and O_3

Defined Benefit Pension and Other Postretirement Plans - Components of Net Periodic Pension Cost (Details) - Pension Plan - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure
Service cost	$ 2	$ 4
Interest cost	9	6
Expected return on plan assets	(11)	(12)
Amortization of:
Actuarial (gain) loss	(1)	2
Net benefit	$ (1)	$ 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	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	$ 772	$ 2,418	$ 1,156
Liabilities:	(453)	(515)	(202)
Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	18	31	10
Liabilities:	(35)	(26)	(7)
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	46	43	52
Recurring | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	674	2,233	1,122
Liabilities:	(449)	(513)	(178)
Recurring | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	35	119	29
Liabilities:	(4)	(2)	(7)
Recurring | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	63	66	5
Liabilities:			(17)
Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	46	43	52
Recurring | Level 1 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	345	938	411
Liabilities:	(297)	(377)	(160)
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:	329	1,268	711
Liabilities:	(152)	(136)	(18)
Recurring | Level 2 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	35	119	29
Liabilities:	(4)	(2)	(7)
Recurring | Level 2 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Assets:	63	66	5
Liabilities:			(17)
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) - Level 3 - Commodity contracts $ in Millions	Dec. 31, 2022 USD ($)
Minimum
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value	$ 7
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	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,759	$ 6,665	$ 6,580
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,350	$ 6,189	$ 7,048

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Narrative (Details)	3 Months Ended
	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2022 EUR (€)	Sep. 30, 2022 USD ($)	Sep. 30, 2022 EUR (€)	Dec. 31, 2021 EUR (€)	Dec. 07, 2021 EUR (€)
Derivative [Line Items]
Pre-tax (losses) gains associated with net investment hedges	$ (64,000,000)	$ 13,000,000
Maximum amount of loss	772,000,000
Cash collateral received	(108,000,000)	(205,000,000)		$ (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
Pre-tax net gains associated with interest rate hedges	$ 39,000,000
Forward foreign currency exchange contracts
Derivative [Line Items]
Derivative notional amount percent of required need coverage	90%		90%
Foreign currency contracts
Derivative [Line Items]
Notional amount	$ 390,000,000	$ 415,000,000	€ 331,000,000	$ 465,000,000	€ 411,000,000	€ 486,000,000
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	Dec. 31, 2022 USD ($) DTH gal kWh	Dec. 31, 2022 EUR (€) DTH gal kWh	Sep. 30, 2022 USD ($) DTH gal kWh	Sep. 30, 2022 EUR (€) DTH gal kWh	Dec. 31, 2021 USD ($) DTH kWh gal	Dec. 31, 2021 EUR (€) DTH kWh gal
Commodity contracts | Regulated Utility Operations | Natural Gas
Derivative [Line Items]
Notional amount (in units)	15	15	19	19	14	14
Commodity contracts | Non-utility Operations | LPG swaps
Derivative [Line Items]
Notional amount (in units) | gal	844	844	874	874	732	732
Commodity contracts | Non-utility Operations | Electricity forward and futures contracts
Derivative [Line Items]
Notional amount (in units) | kWh	2,270	2,270	2,446	2,446	4,261	4,261
Natural gas futures, forward and pipeline contracts (in dekatherms) | Non-utility Operations | Natural Gas
Derivative [Line Items]
Notional amount (in units)	371	371	363	363	382	382
Interest rate swaps
Derivative [Line Items]
Notional amount	$ 1,354	€ 0	$ 1,358	€ 300	$ 1,418	€ 300
Forward foreign currency exchange contracts
Derivative [Line Items]
Notional amount	$ 390	€ 331	$ 465	€ 411	$ 415	€ 486

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Derivative assets:
Total derivative assets — gross	$ 772	$ 2,418	$ 1,156
Gross amounts offset in the balance sheet	(239)	(295)	(116)
Cash collateral received	(108)	(398)	(205)
Total derivative assets — net	425	1,725	835
Derivative liabilities:
Total derivative liabilities — gross	(453)	(515)	(202)
Gross amounts offset in the balance sheet	239	295	116
Cash collateral pledged	45	7	0
Total derivative liabilities — net	(169)	(213)	(86)
Commodity contracts
Derivative assets:
Total derivative assets — gross	18	31	10
Derivative liabilities:
Total derivative liabilities — gross	(35)	(26)	(7)
Derivatives designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	74	123	15
Derivative liabilities:
Total derivative liabilities — gross	0	0	(20)
Derivatives designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	11	57	10
Derivative liabilities:
Total derivative liabilities — gross	0	0	(3)
Derivatives designated as hedging instruments: | Interest rate contracts
Derivative assets:
Total derivative assets — gross	63	66	5
Derivative liabilities:
Total derivative liabilities — gross	0	0	(17)
Derivatives not designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	680	2,264	1,131
Derivative liabilities:
Total derivative liabilities — gross	(418)	(489)	(175)
Derivatives not designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	24	62	19
Derivative liabilities:
Total derivative liabilities — gross	(4)	(2)	(4)
Derivatives not designated as hedging instruments: | Commodity contracts
Derivative assets:
Total derivative assets — gross	656	2,202	1,112
Derivative liabilities:
Total derivative liabilities — gross	$ (414)	$ (487)	$ (171)

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
	Dec. 31, 2022	Dec. 31, 2021
Derivatives not designated as hedging instruments:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ (1,351)	$ (257)
Interest rate contracts | Derivatives designated as hedging instruments: | Cash Flow Hedges:
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	4	12
Interest rate contracts | Derivatives designated as hedging instruments: | Interest expense | Cash Flow Hedges:
Derivative Instruments, Gain (Loss)
Gain (Loss) Reclassified from AOCI into Income	7	(6)
Commodity contracts | Derivatives not designated as hedging instruments: | Revenues
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	4	8
Commodity contracts | Derivatives not designated as hedging instruments: | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(1,326)	(273)
Commodity contracts | Derivatives not designated as hedging instruments: | Other operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	3	0
Foreign currency contracts | Derivatives designated as hedging instruments: | Net Investment Hedges:
Derivative Instruments, Gain (Loss)
Foreign currency contracts	(23)	0
Foreign currency contracts | Derivatives not designated as hedging instruments: | Other non-operating (expense) income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ (32)	$ 8

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	$ 6,074
Other comprehensive income before reclassification adjustments	154	$ (22)
Amounts reclassified from AOCI	(5)	6
Other comprehensive (loss) income attributable to UGI	149	(16)
Balance, end of period	5,188	5,359
Total
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(380)	(140)
Balance, end of period	(231)	(156)
Postretirement Benefit Plans
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	14	(17)
Other comprehensive income before reclassification adjustments	0	0
Amounts reclassified from AOCI	0	2
Other comprehensive (loss) income attributable to UGI	0	2
Balance, end of period	14	(15)
Derivative Instruments
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	37	(33)
Other comprehensive income before reclassification adjustments	3	10
Amounts reclassified from AOCI	(5)	4
Other comprehensive (loss) income attributable to UGI	(2)	14
Balance, end of period	35	(19)
Foreign Currency
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(431)	(90)
Other comprehensive income before reclassification adjustments	151	(32)
Amounts reclassified from AOCI	0	0
Other comprehensive (loss) income attributable to UGI	151	(32)
Balance, end of period	$ (280)	$ (122)

Segment Information - Narrative

Segment Information - Narrative (Details)	3 Months Ended
	Dec. 31, 2022 segment
Segment Reporting [Abstract]
Number of reportable segments	4

Segment Information - Schedule

Segment Information - Schedule of Segment Reporting Information (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Sep. 30, 2022
Segment Reporting Information [Line Items]
Revenues	$ 2,759	$ 2,673
Cost of sales	3,106	2,120
Operating (loss) income	(1,204)	(68)
Income from equity investees	1	8
Loss on extinguishments of debt	0	(11)
Other non-operating (loss) income, net	(28)	10
(Loss) earnings before interest expense and income taxes	(1,231)	(61)
Interest expense	(92)	(81)
Loss before income taxes	(1,323)	(142)
Depreciation and amortization	131	129
Capital expenditures (including the effects of accruals)	178	175
Total assets	17,128	16,800	$ 17,575
AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishments of debt		0
UGI International
Segment Reporting Information [Line Items]
Loss on extinguishments of debt		(11)
Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishments of debt		0
Eliminations
Segment Reporting Information [Line Items]
Revenues	(149)	(118)
Cost of sales	(149)	(117)
Operating (loss) income	1	0
Income from equity investees	0	0
Loss on extinguishments of debt		0
Other non-operating (loss) income, net	0	0
(Loss) earnings before interest expense and income taxes	1	0
Interest expense	0	0
Loss before income taxes	1	0
Depreciation and amortization	0	0
Capital expenditures (including the effects of accruals)	0	0
Total assets	(252)	(269)
Eliminations | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	0	0
Eliminations | UGI International
Segment Reporting Information [Line Items]
Revenues	0	0
Eliminations | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	115	94
Eliminations | Utilities
Segment Reporting Information [Line Items]
Revenues	33	23
Operating Segments | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	766	778
Cost of sales	386	418
Operating (loss) income	110	86
Income from equity investees	0	0
Loss on extinguishments of debt		0
Other non-operating (loss) income, net	0	0
(Loss) earnings before interest expense and income taxes	110	86
Interest expense	(43)	(41)
Loss before income taxes	67	45
Depreciation and amortization	44	44
Capital expenditures (including the effects of accruals)	23	35
Total assets	4,331	4,614
Operating Segments | UGI International
Segment Reporting Information [Line Items]
Revenues	877	1,049
Cost of sales	662	793
Operating (loss) income	56	78
Income from equity investees	0	0
Loss on extinguishments of debt		0
Other non-operating (loss) income, net	10	4
(Loss) earnings before interest expense and income taxes	66	82
Interest expense	(7)	(7)
Loss before income taxes	59	75
Depreciation and amortization	28	31
Capital expenditures (including the effects of accruals)	27	23
Total assets	3,889	4,197
Operating Segments | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	669	535
Revenues from external customers	554	441
Cost of sales	514	413
Operating (loss) income	106	74
Income from equity investees	1	8
Loss on extinguishments of debt		0
Other non-operating (loss) income, net	0	0
(Loss) earnings before interest expense and income taxes	107	82
Interest expense	(11)	(10)
Loss before income taxes	96	72
Depreciation and amortization	21	19
Capital expenditures (including the effects of accruals)	11	6
Total assets	3,298	2,999
Operating Segments | Utilities
Segment Reporting Information [Line Items]
Revenues	592	419
Revenues from external customers	559	396
Cost of sales	329	200
Operating (loss) income	126	96
Income from equity investees	0	0
Loss on extinguishments of debt		0
Other non-operating (loss) income, net	2	2
(Loss) earnings before interest expense and income taxes	128	98
Interest expense	(21)	(16)
Loss before income taxes	107	82
Depreciation and amortization	37	35
Capital expenditures (including the effects of accruals)	117	111
Total assets	5,680	5,071
Corporate & Other
Segment Reporting Information [Line Items]
Revenues from external customers	3	9
Cost of sales	1,364	413
Operating (loss) income	(1,603)	(402)
Income from equity investees	0	0
Loss on extinguishments of debt		(11)
Other non-operating (loss) income, net	(40)	4
(Loss) earnings before interest expense and income taxes	(1,643)	(409)
Interest expense	(10)	(7)
Loss before income taxes	(1,653)	(416)
Depreciation and amortization	1	0
Capital expenditures (including the effects of accruals)	0	0
Total assets	182	188
Intersegment revenues Corporate & Other
Segment Reporting Information [Line Items]
Revenues	$ 1	$ 1

Segment Information - Reconcili

Segment Information - Reconciliation of Partnership Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	$ (1,402)	$ (397)
Impairment of assets	(19)	0
Loss on extinguishments of debt	0	(11)
AmeriGas Propane
Segment Reporting Information [Line Items]
Loss on extinguishments of debt		0
AmeriGas Propane | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0
AmeriGas Propane | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(12)	(69)
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
AmeriGas Propane | Other non-operating (expense) income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0
AmeriGas Propane | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas operations enhancement for growth project	(7)
Impairment of assets	0
AmeriGas Propane | Loss on disposal of U.K. energy marketing business
Segment Reporting Information [Line Items]
Loss on disposal of U.K. energy marketing business	0
UGI International
Segment Reporting Information [Line Items]
Loss on extinguishments of debt		(11)
UGI International | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	2	3
UGI International | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(1,169)	(212)
UGI International | Other operating income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(2)
UGI International | Other non-operating (expense) income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(40)	6
UGI International | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas operations enhancement for growth project	0
Impairment of assets	(19)
UGI International | Loss on disposal of U.K. energy marketing business
Segment Reporting Information [Line Items]
Loss on disposal of U.K. energy marketing business	(215)
Midstream & Marketing
Segment Reporting Information [Line Items]
Loss on extinguishments of debt		0
Midstream & Marketing | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	2	7
Midstream & Marketing | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(183)	(132)
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
Midstream & Marketing | Other non-operating (expense) income, net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	$ 0
Midstream & Marketing | Operating and administrative expenses
Segment Reporting Information [Line Items]
AmeriGas operations enhancement for growth project	0
Impairment of assets	0
Midstream & Marketing | Loss on disposal of U.K. energy marketing business
Segment Reporting Information [Line Items]
Loss on disposal of U.K. energy marketing business	$ 0