UGI (UGI) 10-Q 5 Aug 21 2021 Q3 Quarterly report Financial data

Cover Page

Cover Page - shares	9 Months Ended
	Jun. 30, 2021	Jul. 31, 2021
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2021
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		209,096,896
Entity Central Index Key	0000884614
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--09-30
Common Stock, without par value
Document Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	UGI
Security Exchange Name	NYSE
Corporate Units
Document Information [Line Items]
Title of 12(b) Security	Corporate Units
Trading Symbol	UGIC
Security Exchange Name	NYSE

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2021	Sep. 30, 2020	Jun. 30, 2020
Current assets:
Cash and cash equivalents	$ 545	$ 336	$ 487
Restricted cash	31	21	45
Accounts receivable (less allowances for doubtful accounts of $51, $42 and $42, respectively)	848	652	675
Accrued utility revenues	8	14	14
Income taxes receivable	128	80	0
Inventories	296	241	201
Derivative instruments	350	44	37
Prepaid expenses and other current assets	171	155	141
Total current assets	2,377	1,543	1,600
Property, plant and equipment, (less accumulated depreciation of $3,923, $3,698 and $3,600, respectively)	7,085	6,960	6,805
Goodwill	3,543	3,518	3,482
Intangible assets, net	624	677	669
Utility regulatory assets	389	395	395
Derivative instruments	129	38	38
Other assets	859	854	854
Total assets	15,006	13,985	13,843
Current liabilities:
Current maturities of long-term debt	36	53	26
Short-term borrowings	207	347	423
Accounts payable	579	475	382
Derivative instruments	67	64	109
Other current liabilities	812	816	739
Total current liabilities	1,701	1,755	1,679
Long-term debt	5,811	5,981	5,961
Deferred income taxes	919	640	613
Derivative instruments	49	59	66
Other noncurrent liabilities	1,420	1,413	1,389
Total liabilities	9,900	9,848	9,708
Commitments and contingencies (Note 9)
UGI Corporation stockholders’ equity:
Preferred stock, without par value (authorized – 5,000,000 shares; issued – 220,000, 0 and 0 shares, respectively)	213	0	0
UGI Common Stock, without par value (authorized — 450,000,000 shares; issued — 209,725,554, 209,514,044 and 209,504,994 shares, respectively)	1,388	1,416	1,413
Retained earnings	3,629	2,908	2,970
Accumulated other comprehensive loss	(105)	(147)	(205)
Treasury stock, at cost	(28)	(49)	(52)
Total UGI Corporation stockholders’ equity	5,097	4,128	4,126
Noncontrolling interests	9	9	9
Total equity	5,106	4,137	4,135
Total liabilities and equity	$ 15,006	$ 13,985	$ 13,843

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2021	Sep. 30, 2020	Jun. 30, 2020
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 51	$ 42	$ 42
Accumulated depreciation	$ 3,923	$ 3,698	$ 3,600
UGI Preferred Stock, without par value, shares authorized	5,000,000	5,000,000	5,000,000
UGI Preferred Stock, without par value, shares issued	220,000	0	0
UGI Common Stock, without par value, shares authorized	450,000,000	450,000,000	450,000,000
UGI Common Stock, without par value, shares issued	209,725,554	209,514,044	209,504,994

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Income Statement [Abstract]
Revenues	$ 1,496	$ 1,199	$ 6,009	$ 5,435
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)	516	417	2,623	2,673
Operating and administrative expenses	469	437	1,473	1,452
Impairment of assets held-for-sale	0	52	0	52
Depreciation and amortization	125	122	375	362
Other operating income, net	(5)	(3)	(26)	(17)
Costs and expenses	1,105	1,025	4,445	4,522
Operating income	391	174	1,564	913
(Loss) income from equity investees	(86)	7	(69)	22
Other non-operating income (expense), net	1	(4)	0	(4)
Interest expense	(77)	(80)	(233)	(247)
Income (loss) before income taxes	229	97	1,262	684
Income tax expense	(79)	(12)	(320)	(161)
Net income attributable to UGI Corporation	$ 150	$ 85	$ 942	$ 523
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in USD per share)	$ 0.72	$ 0.41	$ 4.51	$ 2.50
Diluted (in USD per share)	$ 0.71	$ 0.41	$ 4.48	$ 2.49
Weighted-average common shares outstanding (thousands):
Basic (in shares)	209,099	208,598	208,934	208,989
Diluted (in shares)	210,851	208,975	210,194	210,009

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Statement of Comprehensive Income [Abstract]
Net income attributable to UGI Corporation	$ 150	$ 85	$ 942	$ 523
Other comprehensive income (loss):
Net (losses) gains on derivative instruments (net of tax of $1, $3, $(1) and $15, respectively)	0	(8)	4	(38)
Reclassifications of net losses on derivative instruments (net of tax of $(1), $(1), $(5) and $(2), respectively)	5	5	14	6
Foreign currency adjustments (net of tax of $3, $4, $5 and $4, respectively)	16	28	23	42
Benefit plans (net of tax of $(1), $0, $(1) and $(1), respectively)	0	0	1	2
Other comprehensive income	21	25	42	12
Comprehensive income attributable to UGI Corporation	$ 171	$ 110	$ 984	$ 535

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Statement of Comprehensive Income [Abstract]
Net gains (losses) on derivative instruments, tax	$ 1	$ 3	$ (1)	$ 15
Tax on reclassification on derivative instruments	(1)	(1)	(5)	(2)
Foreign currency adjustments, tax	3	4	5	4
Benefit plans ,tax	$ (1)	$ 0	$ (1)	$ (1)

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income attributable to UGI Corporation	$ 942	$ 523
Adjustments to reconcile net income attributable to UGI Corporation to net cash provided by operating activities:
Depreciation and amortization	375	362
Deferred income tax expense (benefit), net	267	(5)
Provision for uncollectible accounts	25	31
Changes in unrealized gains and losses on derivative instruments	(509)	(1)
Impairment of assets held-for-sale	0	52
Loss (income) from equity investees	69	(22)
Other, net	10	(12)
Net change in:
Accounts receivable and accrued utility revenues	(213)	(70)
Income taxes receivable	(48)	0
Inventories	(55)	28
Utility deferred fuel and power costs, net of changes in unsettled derivatives	(9)	22
Accounts payable	123	(37)
Derivative instruments collateral deposits received	112	8
Other current assets	(17)	77
Other current liabilities	(25)	7
Net cash provided by operating activities	1,047	963
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(460)	(471)
Acquisitions of businesses and assets, net of cash and restricted cash acquired	(8)	0
Investments in equity method investees	(61)	0
Other, net	24	21
Net cash used by investing activities	(505)	(450)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(210)	(204)
Issuances of long-term debt, net of issuance costs	130	179
Repayments of long-term debt and finance leases	(329)	(67)
Decrease in short-term borrowings	(121)	(367)
Receivables Facility net repayments	(19)	(6)
Issuance of preferred stock, net of issuance costs	213	0
Issuances of UGI Common Stock	15	2
Repurchases of UGI Common Stock	0	(38)
Net cash used by financing activities	(321)	(501)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(2)	9
Cash, cash equivalents and restricted cash increase	219	21
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of period	576	532
Cash, cash equivalents and restricted cash at beginning of period	357	511
Cash, cash equivalents and restricted cash increase	$ 219	$ 21

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Total UGI stockholders’ equity	Preferred stock, without par value	Common stock, without par value	Retained earnings	Accumulated other comprehensive income (loss)	Treasury stock	Noncontrolling interests
Balance, beginning of period at Sep. 30, 2019			$ 0	$ 1,397	$ 2,653	$ (217)	$ (16)	$ 10
Increase (Decrease) in Stockholders' Equity
Common Stock issued in connection with employee and director plans, net of tax withheld				2
Equity-based compensation expense				15
Losses on common stock transactions in connection with employee and director plans					(3)
Net income attributable to UGI Corporation	$ 523				523
Cash dividends on UGI Common Stock ($0.35, $0.33, $1.01, and $0.980, respectively)					(204)
Net (losses) gains on derivative instruments	(38)					(38)
Reclassification of net losses on derivative instruments	6					6
Benefit plans	2					2
Foreign currency adjustments	42					42
Common Stock issued in connection with employee and director plans, net of tax withheld							5
Repurchases of UGI Common Stock							(38)
Reacquired UGI Common Stock - employee and director plans							(3)
Other				(1)	1			(1)
Balance, end of period at Jun. 30, 2020	4,135	$ 4,126	0	1,413	2,970	(205)	(52)	9
Balance, beginning of period at Mar. 31, 2020			0	1,409	2,953	(230)	(51)	9
Increase (Decrease) in Stockholders' Equity
Equity-based compensation expense				4
Net income attributable to UGI Corporation	85				85
Cash dividends on UGI Common Stock ($0.35, $0.33, $1.01, and $0.980, respectively)					(68)
Net (losses) gains on derivative instruments	(8)					(8)
Reclassification of net losses on derivative instruments	5					5
Benefit plans	0
Foreign currency adjustments	28					28
Common Stock issued in connection with employee and director plans, net of tax withheld							1
Reacquired UGI Common Stock - employee and director plans							(2)
Balance, end of period at Jun. 30, 2020	4,135	4,126	0	1,413	2,970	(205)	(52)	9
Balance, beginning of period at Sep. 30, 2020	4,137		0	1,416	2,908	(147)	(49)	9
Increase (Decrease) in Stockholders' Equity
Issuance of preferred stock			213	(45)
Common Stock issued in connection with employee and director plans, net of tax withheld				6
Equity-based compensation expense				13
Losses on common stock transactions in connection with employee and director plans					(11)
Net income attributable to UGI Corporation	942				942
Cash dividends on UGI Common Stock ($0.35, $0.33, $1.01, and $0.980, respectively)					(210)
Net (losses) gains on derivative instruments	4					4
Reclassification of net losses on derivative instruments	14					14
Benefit plans	1					1
Foreign currency adjustments	23					23
Common Stock issued in connection with employee and director plans, net of tax withheld							22
Reacquired UGI Common Stock - employee and director plans							(1)
Other				(2)
Balance, end of period at Jun. 30, 2021	5,106	5,097	213	1,388	3,629	(105)	(28)	9
Balance, beginning of period at Mar. 31, 2021			0	1,428	3,557	(126)	(40)	9
Increase (Decrease) in Stockholders' Equity
Issuance of preferred stock			213	(45)
Common Stock issued in connection with employee and director plans, net of tax withheld				3
Equity-based compensation expense				4
Losses on common stock transactions in connection with employee and director plans					(6)
Net income attributable to UGI Corporation	150				150
Cash dividends on UGI Common Stock ($0.35, $0.33, $1.01, and $0.980, respectively)					(72)
Net (losses) gains on derivative instruments	0
Reclassification of net losses on derivative instruments	5					5
Benefit plans	0
Foreign currency adjustments	16					16
Common Stock issued in connection with employee and director plans, net of tax withheld							12
Other				(2)
Balance, end of period at Jun. 30, 2021	$ 5,106	$ 5,097	$ 213	$ 1,388	$ 3,629	$ (105)	$ (28)	$ 9

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Statement of Stockholders' Equity [Abstract]
Common stock, dividends, per share, cash paid (in dollars per share)	$ 0.35	$ 0.33	$ 1.01	$ 0.980

Nature of Operations

Nature of Operations	9 Months Ended
	Jun. 30, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations	Note 1 — Nature of Operations UGI is a holding company that, through subsidiaries and affiliates, distributes, stores, transports and markets energy products and related services. In the United States, we own and operate (1) a retail propane marketing and distribution business; (2) natural gas and electric distribution utilities; and (3) an energy marketing, midstream infrastructure, storage, natural gas gathering and processing, natural gas production, electricity generation and energy services businesses. In Europe, we market and distribute propane and other LPG and market other energy products and services. We conduct a domestic propane marketing and distribution business through AmeriGas Partners. AmeriGas Partners conducts a national propane distribution business through its principal operating subsidiary, AmeriGas OLP. UGI International, through subsidiaries and affiliates, conducts (1) an LPG distribution business throughout much of Europe and (2) an energy marketing business in France, Belgium, the Netherlands and the United Kingdom. These businesses are conducted principally through our subsidiaries, UGI France, Flaga, AvantiGas, DVEP and UniverGas. Energy Services conducts, directly and through subsidiaries and affiliates, energy marketing, including renewable natural gas, midstream transmission, LNG storage, natural gas gathering and processing, natural gas 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. UGI Utilities directly owns and operates Gas Utility, a natural gas distribution utility business in eastern and central Pennsylvania and in a portion of one Maryland county. Gas Utility is subject to regulation by the PAPUC, the FERC, and, with respect to a small service territory in one Maryland county, the MDPSC. UGI Utilities also owns and operates Electric Utility, an electric distribution utility located in northeastern Pennsylvania. Electric Utility is subject to regulation by the PAPUC and the FERC. Pending Acquisition of Mountaineer Gas Company On December 29, 2020, UGI Corporation signed a definitive agreement to acquire Mountaineer, the largest natural gas distribution company in West Virginia for a preliminary purchase price of $540, which includes the assumption of approximately $140 of long-term debt. Mountaineer serves nearly 215,000 customers across 50 of the state’s 55 counties. The pending acquisition is subject to customary regulatory and other closing conditions, including approval by the WV PSC, and is expected to close in the second half of calendar year 2021. UGI currently expects to finance the pending acquisition using proceeds from the 2021 UGI Corporation Senior Credit Facility and the issuance of Equity Units. For additional information on these financing activities, see Notes 7 and 8. On January 26, 2021, UGI and Mountaineer filed a joint petition for consent and approval of the pending acquisition at the WV PSC. On July 15, 2021, UGI and Mountaineer filed, on behalf of all parties, a unanimous joint stipulation and agreement for settlement (the “Settlement”) of all issues in the proceeding that, among other provisions, requests the WV PSC to approve the pending acquisition. The Settlement was presented to the WV PSC in an evidentiary hearing on July 20, 2021. The Company cannot predict the timing or the ultimate outcome of the Settlement approval process.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Jun. 30, 2021
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, 2020, 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 2020 Annual Report. Due to the seasonal nature of our businesses, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year. Restricted Cash. Restricted cash principally represents those cash balances in our commodity futures brokerage accounts that are restricted from withdrawal. The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Condensed Consolidated Balance Sheets to the corresponding amounts reported on the Condensed Consolidated Statements of Cash Flows. June 30, June 30, September 30, 2020 September 30, 2019 Cash and cash equivalents $ 545 $ 487 $ 336 $ 447 Restricted cash 31 45 21 64 Cash, cash equivalents and restricted cash $ 576 $ 532 $ 357 $ 511 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 and common stock awards. Shares used in computing basic and diluted earnings per share are as follows: Three Months Ended Nine Months Ended 2021 2020 2021 2020 Denominator (thousands of shares): Weighted-average common shares outstanding — basic 209,099 208,598 208,934 208,989 Incremental shares issuable for stock options and awards 1,752 377 1,260 1,020 Weighted-average common shares outstanding — diluted 210,851 208,975 210,194 210,009 For the three and nine months ended June 30, 2021 and 2020, there were 2,502 and 7,083 shares, respectively, associated with outstanding stock option awards that were excluded from the computation of diluted earnings per share above because their effect was antidilutive. As described in Note 8, the Company issued $220 in Equity Units in May 2021, consisting of Convertible Preferred Stock and the 2024 Purchase Contracts. The 2024 Purchase Contracts contain conversion provisions available under certain conditions. The Company will settle such conversions by paying or delivering (i) one share of UGI’s Series B preferred stock (or, for conversions in connection with a redemption of the Convertible Preferred Stock, up to $1,000 per share in cash) per share of Convertible Preferred Stock being converted; and (ii) to the extent the conversion value exceeds the liquidation preference of the Convertible Preferred Stock, shares of UGI’s common stock. The Convertible Preferred Stock is excluded from the denominator of the diluted earnings per share calculation on the basis that the Convertible Preferred Stock will be settled in cash except to the extent that the conversion value exceeds its liquidation preference. Therefore, before any redemption or conversion, the shares of UGI’s common stock that would be required to settle the applicable conversion value in excess of the liquidation preference, if the Company elects to settle such excess in shares of UGI’s common stock, would be included in the denominator of diluted earnings per share in periods in which they are dilutive. There were no shares related to the Convertible Preferred Stock included in the diluted earnings per share calculation during the three and nine months ended June 30, 2021. 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 UGI Utilities are included in regulatory assets or liabilities because it is probable such gains or losses will be recoverable from, or refundable to, customers. From time to time, we also enter into net investment hedges. Gains and losses on net investment hedges that relate to our foreign operations are included in the cumulative translation adjustment component in AOCI until such foreign net investment is substantially sold or liquidated. Cash flows from derivative instruments, other than certain cross-currency swaps and net investment hedges, if any, are included in cash flows from operating activities on the 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. Impairment of long-lived assets held for sale. In July 2020, Energy Services, through a wholly owned subsidiary, entered into an agreement to sell its approximate 5.97% ownership interest in Conemaugh. As a result, the Company reduced the carrying amount of these assets to their fair value and classified these assets as held-for-sale within the Midstream & Marketing segment as of June 30, 2020. The Company determined the fair value of such assets fell within Level 2 of the fair value hierarchy and was based upon the agreed upon sales price. During the three and nine months ended June 30, 2020, we recognized a non-cash, pre-tax impairment charge of $52 which amount is reflected in “Impairment of assets held-for-sale” on the Condensed Consolidated Statements of Income. Use of Estimates. The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based on management’s knowledge of current events, historical experience and various other assumptions that are believed to be reasonable under the circumstances. Accordingly, actual results may be different from these estimates and assumptions. Reclassifications. Certain prior-period amounts have been reclassified to conform to the current-period presentation.

Accounting Changes

Accounting Changes	9 Months Ended
	Jun. 30, 2021
Accounting Changes and Error Corrections [Abstract]
Accounting Changes	Note 3 — Accounting Changes New Accounting Standard Adopted in Fiscal 2021 Credit Losses. Effective October 1, 2020, the Company adopted ASU 2016-13, “Measurement of Credit Losses on Financial Instruments,” including subsequent amendments, using a modified retrospective transition approach. This ASU, as subsequently amended, requires entities to estimate lifetime expected credit losses for financial instruments not measured at fair value through net income, including trade and other receivables, net investments in leases, financial receivables, debt securities, and other financial instruments, which may result in earlier recognition of credit losses. Further, the new current expected credit loss model may affect how entities estimate their allowance for losses related to receivables that are current with respect to their payment terms. The adoption of the new guidance did not have a material impact on our consolidated financial statements. Accounting Standard Not Yet Adopted Income Taxes. In December 2019, the FASB issued ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” This ASU simplifies the accounting for income taxes by eliminating certain exceptions within the existing guidance for recognizing deferred taxes for equity method investments, performing intraperiod allocations and calculating income taxes in interim periods. Further, this ASU clarifies existing guidance related to, among other things, recognizing deferred taxes for goodwill and allocated taxes to members of a consolidated group. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2021 (Fiscal 2022). Early adoption is permitted; however, the Company will adopt the new guidance effective October 1, 2021. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance. Debt and Derivatives and Hedging. In August 2020, the FASB issued ASU 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40).” The amendments in this ASU affect entities that issue convertible instruments and/or contracts indexed to and potentially settled in an entity’s own equity. This ASU reduces the number of accounting models for convertible debt instruments and convertible preferred stock, expands disclosure requirements for convertible instruments, and simplifies the related earnings per share guidance. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2022 (Fiscal 2023). Early adoption is permitted. The amendments in this ASU may be adopted using the modified or full retrospective transition methods. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the transition method and the period in which the new guidance will be adopted.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	9 Months Ended
	Jun. 30, 2021
Revenue from Contract with Customer [Abstract]
Revenue from Contract 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 2020 Annual Report for additional information on our revenues from contracts with customers. Revenue Disaggregation The following tables present our disaggregated revenues by reportable segment: Three Months Ended June 30, 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 90 $ — $ — $ — $ — $ 90 $ — Commercial & Industrial 34 — — — — 34 — Large delivery service 33 — — — — 33 — Off-system sales and capacity releases 6 (10) — — — 16 — Other 5 — — — — 5 — Total Utility 168 (10) — — — 178 — Non-Utility: LPG: Retail 800 — 424 376 — — — Wholesale 77 — 35 42 — — — Energy Marketing 311 (24) — 129 206 — — Midstream: Pipeline 45 — — — 45 — — Peaking 1 (5) — — 6 — — Other 2 — — — 2 — — Electricity Generation 1 — — — 1 — — Other 69 — 51 18 — — — Total Non-Utility 1,306 (29) 510 565 260 — — Total revenues from contracts with customers 1,474 (39) 510 565 260 178 — Other revenues (b) 22 (1) 16 7 1 3 (4) Total revenues $ 1,496 $ (40) $ 526 $ 572 $ 261 $ 181 $ (4) Three Months Ended June 30, 2020 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 103 $ — $ — $ — $ — $ 103 $ — Commercial & Industrial 30 — — — — 30 — Large delivery service 30 — — — — 30 — Off-system sales and capacity releases 5 (7) — — — 12 — Other 3 — — — — 3 — Total Utility 171 (7) — — — 178 — Non-Utility: LPG: Retail 622 — 372 250 — — — Wholesale 32 — 10 22 — — — Energy Marketing 223 (16) — 81 158 — — Midstream: Pipeline 40 — — — 40 — — Peaking (1) (4) — — 3 — — Other 3 — — — 3 — — Electricity Generation 6 — — — 6 — — Other 75 — 53 13 9 — — Total Non-Utility 1,000 (20) 435 366 219 — — Total revenues from contracts with customers 1,171 (27) 435 366 219 178 — Other revenues (b) 28 (1) 16 5 3 1 4 Total revenues $ 1,199 $ (28) $ 451 $ 371 $ 222 $ 179 $ 4 Nine Months Ended June 30, 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 498 $ — $ — $ — $ — $ 498 $ — Commercial & Industrial 190 — — — — 190 — Large delivery service 117 — — — — 117 — Off-system sales and capacity releases 43 (49) — — — 92 — Other 16 (1) — — — 17 — Total Utility 864 (50) — — — 914 — Non-Utility: LPG: Retail 3,250 — 1,829 1,421 — — — Wholesale 235 — 92 143 — — — Energy Marketing 1,205 (89) — 470 824 — — Midstream: Pipeline 138 — — — 138 — — Peaking 12 (94) — — 106 — — Other 6 — — — 6 — — Electricity Generation 8 — — — 8 — — Other 211 — 161 50 — — — Total Non-Utility 5,065 (183) 2,082 2,084 1,082 — — Total revenues from contracts with customers 5,929 (233) 2,082 2,084 1,082 914 — Other revenues (b) 80 (3) 50 22 4 9 (2) Total revenues $ 6,009 $ (236) $ 2,132 $ 2,106 $ 1,086 $ 923 $ (2) Nine Months Ended June 30, 2020 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 499 $ — $ — $ — $ — $ 499 $ — Commercial & Industrial 193 — — — — 193 — Large delivery service 113 — — — — 113 — Off-system sales and capacity releases 44 (37) — — — 81 — Other 12 (1) — — — 13 — Total Utility 861 (38) — — — 899 — Non-Utility: LPG: Retail 2,911 — 1,715 1,196 — — — Wholesale 172 — 51 121 — — — Energy Marketing 1,005 (64) — 349 720 — — Midstream: Pipeline 128 — — — 128 — — Peaking 6 (96) — — 102 — — Other 6 — — — 6 — — Electricity Generation 23 — — — 23 — — Other 237 (2) 168 43 28 — — Total Non-Utility 4,488 (162) 1,934 1,709 1,007 — — Total revenues from contracts with customers 5,349 (200) 1,934 1,709 1,007 899 — Other revenues (b) 86 (2) 49 17 10 2 10 Total revenues $ 5,435 $ (202) $ 1,983 $ 1,726 $ 1,017 $ 901 $ 10 (a) Includes intersegment revenues principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane. (b) Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, revenues from alternative revenue programs at UGI Utilities, 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 UGI 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 $109, $161 and $104 at June 30, 2021, September 30, 2020 and June 30, 2020, respectively, and are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets. Revenues recognized for the nine months ended June 30, 2021 and 2020, from the amounts included in contract liabilities at September 30, 2020 and 2019, were $137 and $122, respectively. Remaining Performance Obligations The Company excludes disclosures related to the aggregate amount of the transaction price allocated to certain performance obligations that are unsatisfied as of the end of the reporting period because these contracts have an initial expected term of one year or less, or we have a right to bill the customer in an amount that corresponds directly with the value of services provided to the customer to date. Certain contracts with customers at Midstream & Marketing and UGI Utilities contain minimum future performance obligations through 2047 and 2053, respectively. At June 30, 2021, Midstream & Marketing and UGI Utilities expect to record approximately $2.0 billion and $0.2 billion of revenues, respectively, related to the minimum future performance obligations over the remaining terms of the related contracts.

Inventories

Inventories	9 Months Ended
	Jun. 30, 2021
Inventory Disclosure [Abstract]
Inventories	Note 5 — Inventories Inventories comprise the following: June 30, September 30, June 30, Non-utility LPG and natural gas $ 187 $ 164 $ 135 Gas Utility natural gas 16 20 11 Materials, supplies and other 93 57 55 Total inventories $ 296 $ 241 $ 201

Utility Regulatory Assets and L

Utility Regulatory Assets and Liabilities and Regulatory Matters	9 Months Ended
	Jun. 30, 2021
Regulated Operations [Abstract]
Utility Regulatory Assets and Liabilities and Regulatory Matters	Note 6 — 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 2020 Annual Report. Other than removal costs, UGI Utilities currently does not recover a rate of return on its regulatory assets listed below. The following regulatory assets and liabilities associated with UGI Utilities are included on the Condensed Consolidated Balance Sheets: June 30, September 30, June 30, Regulatory assets (a): Income taxes recoverable $ 131 $ 124 $ 133 Underfunded pension and postretirement plans 166 175 169 Environmental costs 58 61 62 Removal costs, net 24 26 22 Other 17 11 13 Total regulatory assets $ 396 $ 397 $ 399 Regulatory liabilities (a): Postretirement benefit overcollections $ 12 $ 13 $ 13 Deferred fuel and power refunds 21 29 28 State tax benefits — distribution system repairs 30 28 29 PAPUC Temporary Rates Order — 7 10 Excess federal deferred income taxes 269 274 275 Other 2 2 3 Total regulatory liabilities $ 334 $ 353 $ 358 (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 Refunds. Gas Utility’s and Electric Utility’s tariffs contain clauses that permit recovery of all prudently incurred purchased gas and power costs through the application of PGC rates in the case of Gas Utility and DS tariffs in the case of Electric Utility. These clauses provide for periodic adjustments to PGC and DS rates for differences between the total amount of purchased gas and electric generation supply costs billed to customers and recoverable costs incurred. Net undercollected costs are classified as a regulatory asset and net overcollections are classified as a regulatory liability. Gas Utility uses derivative instruments to reduce volatility in the cost of gas it purchases for retail core-market customers. Realized and unrealized gains or losses on natural gas derivative instruments are included in deferred fuel and power costs or refunds. Net unrealized gains on such contracts at June 30, 2021, September 30, 2020 and June 30, 2020 were $9, $8 and $1, respectively. Other Regulatory Matters Base Rate Filings. On February 8, 2021, Electric Utility filed a rate request with the PAPUC to increase its annual base distribution revenues by $9. 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 April 9, 2021. The PAPUC entered an Order on March 11, 2021, suspending the effective date for the rate increase to allow for investigation and public hearings. On July 19, 2021, a Joint Petition for Approval of Settlement of all issues supported by all active parties was filed with the PAPUC providing for a $6 annual base distribution rate increase for Electric Utility. The Joint Petition is subject to receipt of a recommended decision by a PAPUC administrative law judge and an order of the PAPUC approving the settlement. Unless the PAPUC issues a final order prior to the end of the statutory suspension period, the initial proposed rate increase will become effective on or before November 9, 2021, subject to refund and a subsequent PAPUC order. The Company cannot predict the timing or the ultimate outcome of the rate case review process. On January 28, 2020, Gas Utility filed a request with the PAPUC to increase its annual base distribution operating revenues by $75 annually. On October 8, 2020, the PAPUC issued a final Order approving a settlement that permits Gas Utility to increase its annual base distribution rates by $20, through a phased approach, with $10 beginning January 1, 2021 and an additional $10 beginning July 1, 2021. Additionally, Gas Utility was authorized to implement a DSIC once Gas Utility total property, plant and equipment less accumulated depreciation reached $2,875. This threshold was achieved in December 2020, and Gas Utility implemented a DSIC effective April 1, 2021. The PAPUC’s final Order also includes enhanced COVID-19 customer assistance measures, including the establishment of an Emergency Relief Program for a defined set of payment troubled customers (“ERP”). Additionally, the PAPUC’s final Order permits Gas Utility to establish a regulatory asset for certain incremental expenses attributable to the ongoing COVID-19 pandemic, most notably expenses related to the ERP and uncollectible accounts expense, through the effective date of rates in the next Gas Utility base rate case, to be recovered and amortized over a 10-year period. In accordance with the terms of the PAPUC’s final Order, Gas Utility is not permitted to file a rate case prior to January 1, 2022.

Debt

Debt	9 Months Ended
	Jun. 30, 2021
Debt Disclosure [Abstract]
Debt	Note 7 — Debt 2021 UGI Corporation Senior Credit Facility. On May 4, 2021, UGI amended the existing UGI Corporation Senior Credit Facility. The 2021 UGI Corporation Senior Credit Facility (1) extends the maturity date of the previous three-year $300 term loan included in the existing UGI Corporation Senior Credit Facility, which is now due in May 2025; and (2) includes a new four-year term loan commitment, which, effective June 9, 2021, was reduced from $300 to $215, pursuant to the terms of the 2021 UGI Corporation Senior Facility. Proceeds from new borrowings under the 2021 UGI Corporation Senior Credit Facility may be used to finance a portion of the Mountaineer Acquisition and for general corporate purposes. New borrowings under the 2021 UGI Corporation Senior Credit Facility bear interest subject to our election, at either (1) the associated prime rate plus a margin or (2) an adjusted LIBOR or an alternate benchmark rate plus a margin and are due in their entirety at the maturity date. The applicable margin on the new borrowings, which is dependent upon a ratio of consolidated net indebtedness to consolidated EBITDA, as defined, or UGI’s credit ratings, ranges from 0.125% to 1.50% if the prime rate option is elected and 1.125% to 2.50% if the LIBOR option is elected. The 2021 UGI Corporation Senior Credit Facility restricts the ability of UGI to, among other things, incur additional indebtedness, make investments, incur liens, and effect mergers, consolidations and sales of assets. The 2021 UGI Corporation Senior Credit Facility also requires UGI not to exceed a ratio of consolidated net indebtedness to consolidated EBITDA, each as defined and calculated on a rolling four-quarter basis as of the last day of each fiscal quarter of 4.50 to 1.00 and raised to 4.75 to 1.00 during an Acquisition Period, as defined by the agreement. UGI is also required to maintain a ratio of consolidated EBITDA to consolidated interest expense, each as defined, as of the last day of each fiscal quarter of not less than 3.50 to 1.00, except in certain circumstances related to UGI’s credit rating. During the nine months ended June 30, 2021, the Company repaid $285 of borrowings on its five-year $300 revolving credit facility under the 2021 UGI Corporation Senior Credit Facility. A portion of these repayments were funded by the proceeds from the issuance of Equity Units discussed in Note 8. In July 2021, the Company repaid the remaining $15 of borrowings outstanding on this revolving credit facility. As a result of this repayment in July, the Company classified these repayments as “Current maturities of long-term debt” on the June 30, 2021 Condensed Consolidated Balance Sheet. The Company intends to draw upon this revolving credit facility concurrent with the closing of the pending Mountaineer Acquisition. UGI Utilities Senior Notes . On May 7, 2021, UGI Utilities entered into a Note Purchase Agreement which provides for the private placement of (1) $100 aggregate principal amount of 1.59% Senior Notes due June 15, 2026 and (2) $75 aggregate principal amount of 1.64% Senior Notes due September 15, 2026. On June 15, 2021, UGI Utilities issued $100 aggregate principal amount of 1.59% Senior Notes pursuant to the Note Purchase Agreement. The net proceeds from the issuance of the 1.59% Senior Notes were used to repay short-term borrowings. The 1.64% Senior Notes are expected to be issued in September 2021. These Senior Notes are unsecured and will rank equally with UGI Utilities’ existing outstanding senior debt. UGI Utilities expects to use the net proceeds from the issuance of the 1.64% Senior Notes to reduce short-term borrowings and for general corporate purposes. These Senior Notes include the usual and customary covenants for similar type notes including, among others, maintenance of existence, payment of taxes when due, compliance with laws and maintenance of insurance. These Senior Notes require UGI Utilities not to exceed a ratio of Consolidated Debt to Consolidated Total Capital, as defined, of 0.65 to 1.00.

Issuance of Equity Units

Issuance of Equity Units	9 Months Ended
	Jun. 30, 2021
Equity [Abstract]
Issuance of Equity Units	Note 8 — Issuance of Equity Units On May 25, 2021, the Company issued 2.2 million Equity Units with a total notional value of $220. Each Equity Unit has a stated amount of $100 and consists of 1) a 10% undivided beneficial ownership interest in one share of Convertible Preferred Stock with a liquidation preference of $1,000 per share and 2) a 2024 Purchase Contract. The Company received approximately $213 in proceeds from the issuance of the Equity Units, net of offering expenses and underwriting costs and commissions, and issued 220,000 shares of Convertible Preferred Stock, recording $213 in “Preferred stock” on the accompanying Condensed Consolidated Balance Sheet. The proceeds were used to repay borrowings on the Company’s five-year $300 revolving credit facility under the 2021 UGI Corporation Senior Credit Facility. Concurrent with the closing of the pending Mountaineer Acquisition, the Company intends to draw upon this revolving credit facility to pay a portion of the purchase price and related fees and expenses, and for general corporate purposes. Convertible Preferred Stock . Holders of the Convertible Preferred Stock will generally have no voting rights, except under the limited circumstances as described in the Equity Unit Agreements, and will be entitled to receive cumulative dividends at an initial annual rate of 0.125% when, as, and if declared by the UGI Board of Directors, payable quarterly in arrears on March 1, June 1, September 1 and December 1, commencing September 1, 2021. The Company may elect to pay such dividends in cash, shares of UGI’s common stock or a combination of cash and shares of UGI’s common stock. Unless all accumulated and unpaid dividends on the Convertible Preferred Stock for prior completed dividend periods have been declared and paid, the Company may not make any distributions on, or repurchase, any of its capital stock ranking equal or junior to the Convertible Preferred Stock as to dividends or upon liquidation, subject to certain exceptions. The Convertible Preferred Stock has no maturity date and will remain outstanding unless converted by holders or redeemed by the Company. The Company has the option to redeem all or a portion of the Convertible Preferred Stock at any time, and from time to time, on or after September 3, 2024, for cash at a redemption price equal to the liquidation preference of the Convertible Preferred Stock being redeemed plus any accumulated and unpaid dividends. Each share of Convertible Preferred Stock may be converted at the option of the holders on and after June 1, 2024, only after it has been separated from the Equity Units and, prior to June 1, 2024, only under limited circumstances in connection with a fundamental change, as defined in the Equity Unit Agreements. The Company will settle conversions by paying or delivering (i) one share of UGI’s 0.125% Series B preferred stock (or, for conversions in connection with a redemption of the Convertible Preferred Stock, up to $1,000 per share in cash plus all accumulated but unpaid dividends to, but excluding, the payment date immediately preceding the relevant conversion date) per share of Convertible Preferred Stock being converted; and (ii) to the extent the conversion value exceeds the liquidation preference of the Convertible Preferred Stock, shares of UGI’s common stock. The conversion rate is initially 19.0215 shares of UGI’s common stock per one share of Convertible Preferred Stock, which is equivalent to an initial conversion price of approximately $52.57 per share of UGI’s common stock. The Convertible Preferred Stock can be remarketed during either (i) an optional remarketing period beginning on, and including, March 1, 2024 and ending on, and including, May 13, 2024 or (ii) a final remarketing period beginning on, and including, May 23, 2024 and ending on, and including, May 30, 2024. In connection with a successful remarketing, the conversion rate and dividend rate of the Convertible Preferred Stock may be increased, and the earliest redemption date for the Convertible Preferred Stock may be changed to a later date that is on or before August 29, 2025. 2024 Purchase Contracts. The 2024 Purchase Contracts obligate the holders to pay $100 to UGI to purchase a variable number of shares of UGI’s common stock on the purchase contract settlement date, which is scheduled to occur on June 1, 2024. The number of shares of UGI’s common stock to be issued upon settlement of each 2024 Purchase Contract on the purchase contract settlement date will be equal to $100 divided by the market value per share of UGI’s common stock, which will be determined over a market value averaging period preceding the settlement date, subject to a maximum settlement rate of 2.2826 shares of UGI’s common stock per 2024 Purchase Contract, subject to adjustment. The initial maximum settlement rate of the 2024 Purchase Contracts is approximately equal to $100 divided by the last reported sale price of $43.81 per share of UGI’s common stock on May 17, 2021. Absent any fundamental changes, as defined in the Equity Unit Agreements, the holders can settle the 2024 Purchase Contracts early, subject to certain exceptions and conditions. Upon early settlement of any 2024 Purchase Contracts, other than in connection with a fundamental change, the Company will deliver the number of shares of UGI’s common stock equal to 85% of the number of shares of UGI’s common stock that would have otherwise been deliverable. The Company will pay holders of the 2024 Purchase Contracts quarterly contract adjustment payments at an annual rate of 7.125%, payable quarterly in arrears on March 1, June 1, September 1 and December 1, commencing September 1, 2021. The Company may elect to pay such contract adjustment payments in cash, shares of UGI’s common stock or a combination of cash and shares of UGI’s common stock. The Company may defer the contract adjustment payments for one or more consecutive periods but generally not beyond the purchase contract settlement date. If contract adjustment payments are deferred, the Company will be subject to certain dividend, distribution, and other restrictions related to its capital stock as defined in the Equity Unit Agreements. The present value of the quarterly contract adjustment payments liability was $45 upon issuance of the Equity Units and is recorded in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheet. Such liability reduced “UGI Common Stock” on the Condensed Consolidated Balance Sheet at inception. As each quarterly contract adjustment payment is made, the related liability is reduced and the difference between the cash payment and the present value will accrete to “Interest expense” on the Condensed Consolidated Statements of Income. This accretion was not material for the three and nine months ended June 30, 2021.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Jun. 30, 2021
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. Prior to October 1, 2020, UGI Utilities was subject to three COAs with the PADEP to address the remediation of specified former MGP sites in Pennsylvania and, in the case of one COA, the plugging of specified natural gas wells. Effective October 1, 2020, the COAs were consolidated into one agreement that supersedes the existing agreements, and which is scheduled to terminate at the end of 2031. In accordance with the consolidated COA, UGI Utilities 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 required under the consolidated COA is $5. The consolidated COA permits the transfer of the specified wells, with related costs counted towards the annual minimum expenditure. At June 30, 2021, September 30, 2020 and June 30, 2020, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the current COA and the predecessor agreements totaled $49, $53 and $55, 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 6). 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 was material for all periods presented. AmeriGas Propane AmeriGas OLP Saranac Lake. In 2008, the NYDEC notified AmeriGas OLP that the NYDEC had placed property purportedly owned by AmeriGas OLP in Saranac Lake, New York on the New York State Registry of Inactive Hazardous Waste Disposal Sites. A site characterization study performed by the NYDEC disclosed contamination related to a former MGP. AmeriGas OLP responded to the NYDEC in 2009 to dispute the contention it was a PRP as it did not operate the MGP and appeared to only own a portion of the site. In 2017, the NYDEC communicated to AmeriGas OLP that the NYDEC had previously issued three RODs related to remediation of the site totaling approximately $28 and requested additional information regarding AmeriGas OLP’s purported ownership. AmeriGas OLP renewed its challenge to designation as a PRP and identified potential defenses. The NYDEC subsequently identified a third party PRP with respect to the site. The NYDEC commenced implementation of the remediation plan in the spring of 2018. Based on our evaluation of the available information as of June 30, 2021, the Partnership has an undiscounted environmental remediation liability of $8 related to the site. Our share of the actual remediation costs could be significantly more or less than the accrued amount. Other Matters Purported Class Action Lawsuits. Between May and October of 2014, purported class action lawsuits were filed in multiple jurisdictions against the Partnership/UGI and a competitor by certain of their direct and indirect customers. The class action lawsuits allege, among other things, that the Partnership and its competitor colluded, beginning in 2008, to reduce the fill level of portable propane cylinders from 17 pounds to 15 pounds and combined to persuade their common customer, Walmart Stores, Inc., to accept that fill reduction, resulting in increased cylinder costs to retailers and end-user customers in violation of federal and certain state antitrust laws. The claims seek treble damages, injunctive relief, attorneys’ fees and costs on behalf of the putative classes. On October 16, 2014, the United States Judicial Panel on Multidistrict Litigation transferred all of these purported class action cases to the Western Missouri District Court. As the result of rulings on a series of procedural filings, including petitions filed with the Eighth Circuit and the U.S. Supreme Court, both the federal and state law claims of the direct customer plaintiffs and the state law claims of the indirect customer plaintiffs were remanded to the Western Missouri District Court. The decision of the Western Missouri District Court to dismiss the federal antitrust claims of the indirect customer plaintiffs was upheld by the Eighth Circuit. On April 15, 2019, the Western Missouri District Court ruled that it has jurisdiction over the indirect purchasers’ state law claims and that the indirect customer plaintiffs have standing to pursue those claims. On August 21, 2019, the District Court partially granted the Company’s motion for judgment on the pleadings and dismissed the claims of indirect customer plaintiffs from ten states and the District of Columbia. On October 2, 2019, the Partnership reached an agreement to resolve the claims of the direct purchaser class of plaintiffs; the agreement received final court approval on June 18, 2020. On September 18, 2020, the Partnership and counsel for the indirect purchaser plaintiffs filed a joint statement with the court that they had reached an agreement in principle to settle the claims of the remaining classes and plaintiffs; the settlement received final court approval on March 30, 2021. Although we cannot predict the final results of these pending claims and legal actions, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our financial statements. In addition to the matters described above, there are other pending claims and legal actions arising in the normal course of our businesses. Although we cannot predict the final results of these pending claims and legal actions, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our financial statements.

Defined Benefit Pension and Oth

Defined Benefit Pension and Other Postretirement Plans	9 Months Ended
	Jun. 30, 2021
Retirement Benefits [Abstract]
Defined Benefit Pension and Other Postretirement Plans	Note 10 — Defined Benefit Pension and Other Postretirement Plans The Company maintains defined benefit plans and other postretirement plans for certain current and former employees. The service cost component of our pension and other postretirement plans, net of amounts capitalized, is reflected in “Operating and administrative expenses” on the Condensed Consolidated Statements of Income. The non-service cost component, net of amounts capitalized by UGI Utilities as a regulatory asset, is reflected in “Other non-operating income (expense), net” on the Condensed Consolidated Statements of Income. Other postretirement benefit cost was not material for all periods presented. Net periodic pension cost includes the following components: Pension Benefits Three Months Ended June 30, 2021 2020 Service cost $ 3 $ 3 Interest cost 5 6 Expected return on assets (10) (10) Amortization of: Actuarial loss 4 4 Net cost $ 2 $ 3 Nine Months Ended June 30, 2021 2020 Service cost $ 9 $ 9 Interest cost 16 18 Expected return on assets (30) (29) Curtailment gain — (1) Amortization of: Actuarial loss 11 11 Net cost $ 6 $ 8

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Jun. 30, 2021
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 11 — Fair Value Measurements Recurring Fair Value Measurements The following table presents, on a gross basis, our financial assets and liabilities, including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy: Asset (Liability) Level 1 Level 2 Level 3 Total June 30, 2021: Derivative instruments: Assets: Commodity contracts $ 241 $ 396 $ — $ 637 Foreign currency contracts $ — $ 24 $ — $ 24 Liabilities: Commodity contracts $ (136) $ (9) $ — $ (145) Foreign currency contracts $ — $ (13) $ — $ (13) Interest rate contracts $ — $ (35) $ — $ (35) Non-qualified supplemental postretirement grantor trust investments (a) $ 42 $ — $ — $ 42 September 30, 2020: Derivative instruments: Assets: Commodity contracts $ 68 $ 39 $ — $ 107 Foreign currency contracts $ — $ 32 $ — $ 32 Liabilities: Commodity contracts $ (54) $ (64) $ — $ (118) Foreign currency contracts $ — $ (14) $ — $ (14) Interest rate contracts $ — $ (55) $ — $ (55) Non-qualified supplemental postretirement grantor trust investments (a) $ 42 $ — $ — $ 42 June 30, 2020: Derivative instruments: Assets: Commodity contracts $ 39 $ 29 $ — $ 68 Foreign currency contracts $ — $ 49 $ — $ 49 Liabilities: Commodity contracts $ (58) $ (114) $ — $ (172) Foreign currency contracts $ — $ (7) $ — $ (7) Interest rate contracts $ — $ (59) $ — $ (59) Non-qualified supplemental postretirement grantor trust investments (a) $ 41 $ — $ — $ 41 (a) Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans. The fair values of our Level 1 exchange-traded commodity futures and option contracts and non-exchange-traded commodity futures and forward contracts are based upon actively quoted market prices for identical assets and liabilities. The remainder of our derivative instruments are designated as Level 2. The fair values of certain non-exchange-traded commodity derivatives designated as Level 2 are based upon indicative price quotations available through brokers, industry price publications or recent market transactions and related market indicators. The fair values of our Level 2 interest rate contracts and foreign currency contracts are based upon third-party quotes or indicative values based on recent market transactions. The fair values of investments held in grantor trusts are derived from quoted market prices as substantially all of the investments in these trusts have active markets. Other Financial Instruments The carrying amounts of other financial instruments included in current assets and current liabilities (except for current maturities of long-term debt) approximate their fair values because of their short-term nature. We estimate the fair value of long-term debt by using current market rates and by discounting future cash flows using rates available for similar type debt (Level 2). The carrying amounts and estimated fair values of our long-term debt (including current maturities but excluding unamortized debt issuance costs) were as follows: June 30, 2021 September 30, 2020 June 30, 2020 Carrying amount $ 5,890 $ 6,081 $ 6,036 Estimated fair value $ 6,314 $ 6,504 $ 6,208

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	9 Months Ended
	Jun. 30, 2021
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 Gas Utility’s tariffs contain clauses that permit recovery of all prudently incurred costs of natural gas it sells to retail core-market customers, including the cost of financial instruments used to hedge purchased gas costs. As permitted and agreed to by the PAPUC pursuant to Gas Utility’s annual PGC filings, Gas Utility currently uses NYMEX natural gas futures and option contracts to reduce commodity price volatility associated with a portion of the natural gas it purchases for its retail core-market customers. See Note 6 for further information on the regulatory accounting treatment for these derivative instruments. Non-utility Operations LPG In order to manage market price risk associated with the Partnership’s fixed-price programs and to reduce the effects of short-term commodity price volatility, the Partnership uses over-the-counter derivative commodity instruments, principally price swap contracts. In addition, the Partnership and our UGI International operations also use over-the-counter price swap contracts to reduce commodity price volatility associated with a portion of their forecasted LPG purchases. Natural Gas In order to manage market price risk relating to fixed-price sales contracts for physical natural gas, Midstream & Marketing enters into NYMEX and over-the-counter natural gas futures and over-the-counter and ICE natural gas basis swap contracts. In addition, Midstream & Marketing uses NYMEX and over-the-counter futures and options contracts to economically hedge price volatility associated with the gross margin derived from the purchase and anticipated later near-term sale of natural gas storage inventories. Outside of the financial market, Midstream & Marketing also uses ICE and over-the-counter forward physical contracts. UGI International also uses natural gas futures and forward contracts to economically hedge market price risk associated with fixed-price sales contracts with its customers. Electricity In order to manage market price risk relating to fixed-price sales contracts for electricity, Midstream & Marketing enters into electricity futures and forward contracts. Midstream & Marketing also uses NYMEX and over-the-counter electricity futures contracts to economically hedge the price of a portion of its anticipated future sales of electricity from its electric generation facilities. UGI International also uses electricity futures and forward contracts to economically hedge market price risk associated with fixed-price sales and purchase contracts for electricity. Interest Rate Risk Certain of our long-term debt agreements have interest rates that are generally indexed to short-term market interest rates. In order to fix the underlying short-term market interest rates, we may enter into pay-fixed, receive-variable interest rate swap agreements and designate such swaps as cash flow hedges. As previously mentioned in Note 7, on May 4, 2021, UGI entered into the 2021 UGI Corporation Senior Credit Facility, which as amended, includes a new term loan commitment of up to $215. Borrowings on this commitment will bear interest at a rate indexed to short-term market rates. In June 2021, UGI entered into two forward starting, pay-fixed, receive-variable interest rate swap agreements, commencing in January 2022. These swaps generally fix the underlying variable interest rate on $125 of future borrowings at 0.69% through September 2024. We have designated these interest rate swaps as a cash flow hedges. The remainder of our long-term debt is typically issued at fixed rates of interest. As this long-term debt matures, we typically refinance such debt with new debt having interest rates reflecting then-current market conditions. In order to reduce market rate risk on the underlying benchmark rate of interest associated with near- to medium-term forecasted issuances of fixed-rate debt, from time to time, we enter into IRPAs. We account for IRPAs as cash flow hedges. There were no unsettled IRPAs during any of the periods presented. At June 30, 2021, the amount of pre-tax net losses associated with interest rate hedges (excluding pay-fixed, receive-variable interest rate swaps) expected to be reclassified into earnings during the next twelve months is $4. Foreign Currency Exchange Rate Risk Forward Foreign Currency Exchange Contracts In order to reduce the volatility in net income associated with our foreign operations, principally as a result of changes in the U.S. dollar exchange rate to the euro and British pound sterling, we enter into forward foreign currency exchange contracts. We layer in these foreign currency exchange contracts over a multi-year period to eventually equal approximately 90% of anticipated UGI International foreign currency earnings before income taxes. Because these contracts are not designated as hedging instruments, realized and unrealized gains and losses on these contracts are recorded in “Other non-operating income (expense), net,” on the 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 U.S. dollar value of a portion of our UGI International euro-denominated net investments. We account for these foreign currency exchange contracts as net investment hedges and all changes in the fair value of these contracts are reported in the cumulative translation adjustment component in AOCI. Our euro-denominated long-term debt has also been designated as net investment hedges of a portion of our UGI International euro-denominated net investment. We recognized pre-tax losses associated with these net investment hedges in the cumulative translation adjustment component in AOCI of $8 and $13 during the three months ended June 30, 2021 and 2020, respectively, $9 and $22 during the nine months ended June 30, 2021 and 2020, respectively. Quantitative Disclosures Related to Derivative Instruments The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at June 30, 2021, September 30, 2020 and June 30, 2020, and the final settlement dates of the Company's open derivative contracts as of June 30, 2021, excluding those derivatives that qualified for the NPNS exception: Notional Amounts Type Units Settlements Extending Through June 30, 2021 September 30, 2020 June 30, 2020 Commodity Price Risk: Regulated Utility Operations Gas Utility NYMEX natural gas futures and option contracts Dekatherms February 2022 12 22 16 Non-utility Operations LPG swaps Gallons November 2023 688 846 890 Natural gas futures, forward, basis swap, options and pipeline contracts Dekatherms July 2026 344 339 343 Electricity forward and futures contracts Kilowatt hours January 2026 4,730 4,705 4,144 Interest Rate Risk: Interest rate swaps Euro October 2022 € 300 € 300 € 300 Interest rate swaps USD September 2024 $ 1,424 $ 1,344 $ 1,347 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD October 2024 $ 504 $ 511 $ 440 Net investment hedge forward foreign exchange contracts Euro October 2024 € 173 € 173 € 173 Derivative Instrument Credit Risk We are exposed to risk of loss in the event of nonperformance by our derivative instrument counterparties. Our derivative instrument counterparties principally comprise large energy companies and major U.S. and international financial institutions. We maintain credit policies with regard to our counterparties that we believe reduce overall credit risk. These policies include evaluating and monitoring our counterparties’ financial condition, including their credit ratings, and entering into agreements with counterparties that govern credit limits or entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. Certain of these agreements call for the posting of collateral by the counterparty or by the Company in the forms of letters of credit, parental guarantees or cash. Additionally, our commodity exchange traded futures contracts generally require cash deposits in margin accounts. Restricted cash in brokerage accounts is reported in “Restricted cash” on the Condensed Consolidated Balance Sheets. Although we have concentrations of credit risk associated with derivative instruments, the maximum amount of loss we would incur if these counterparties failed to perform according to the terms of their contracts, based upon the gross fair values of the derivative instruments, was not material at June 30, 2021. Certain of the Partnership’s derivative contracts have credit-risk-related contingent features that may require the posting of additional collateral in the event of a downgrade of the Partnership’s debt rating. At June 30, 2021, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material. Offsetting Derivative Assets and Liabilities Derivative assets and liabilities are presented net by counterparty on the 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, most of our over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral generally include cash or letters of credit. Cash collateral paid by us to our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative liabilities. Cash collateral received by us from our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative assets. Certain other accounts receivable and accounts payable balances recognized on the Condensed Consolidated Balance Sheets with our derivative counterparties are not included in the table below but could reduce our net exposure to such counterparties because such balances are subject to master netting or similar arrangements. Fair Value of Derivative Instruments The following table presents the Company’s derivative assets and liabilities by type, as well as the effects of offsetting: June 30, September 30, June 30, Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 15 $ 17 $ 25 Derivatives subject to PGC and DS mechanisms: Commodity contracts 14 7 3 Derivatives not designated as hedging instruments: Commodity contracts 623 100 65 Foreign currency contracts 9 15 24 632 115 89 Total derivative assets — gross 661 139 117 Gross amounts offset in the balance sheet (77) (57) (42) Cash collateral received (105) — — Total derivative assets — net $ 479 $ 82 $ 75 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts $ (35) $ (55) $ (59) Derivatives subject to PGC and DS mechanisms: Commodity contracts (6) — (2) Derivatives not designated as hedging instruments: Commodity contracts (139) (118) (170) Foreign currency contracts (13) (14) (7) (152) (132) (177) Total derivative liabilities — gross (193) (187) (238) Gross amounts offset in the balance sheet 77 57 42 Cash collateral pledged — 7 21 Total derivative liabilities — net $ (116) $ (123) $ (175) Effects of Derivative Instruments The following tables provide information on the effects of derivative instruments on the Condensed Consolidated Statements of Income and changes in AOCI: Three Months Ended June 30,: Gain (Loss) Loss Location of Loss Reclassified from Cash Flow Hedges: 2021 2020 2021 2020 Interest rate contracts $ (1) $ (11) $ (6) $ (6) Interest expense Net Investment Hedges: Foreign currency contracts $ (1) $ (3) Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2021 2020 Location of Gain (Loss) Recognized in Income Commodity contracts $ (5) $ 6 Revenues Commodity contracts 347 127 Cost of sales Commodity contracts — 1 Operating and administrative expenses Foreign currency contracts (1) (5) Other non-operating income (expense), net Total $ 341 $ 129 Nine Months Ended June 30,: Gain (Loss) Loss Location of Loss Reclassified from Cash Flow Hedges: 2021 2020 2021 2020 Interest rate contracts $ 5 $ (53) $ (19) $ (8) Interest expense Net Investment Hedges: Foreign currency contracts $ (2) $ 7 Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2021 2020 Location of Gain (Loss) Recognized in Income Commodity contracts $ (4) $ 14 Revenues Commodity contracts 585 (112) Cost of sales Commodity contracts — 1 Operating and administrative expenses Commodity contracts 5 — Other operating income, net Foreign currency contracts (4) (5) Other non-operating income (expense), net Total $ 582 $ (102) We are also a party to a number of other contracts that have elements of a derivative instrument. However, these contracts qualify for NPNS exception accounting because they provide for the delivery of products or services in quantities that are expected to be used in the normal course of operating our business and the price in the contract is based on an underlying that is directly associated with the price of the product or service being purchased or sold. These contracts include, among others, binding purchase orders, contracts that provide for the purchase and delivery, or sale, of energy products, and service contracts that require the counterparty to provide commodity storage, transportation or capacity service to meet our normal sales commitments.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	9 Months Ended
	Jun. 30, 2021
Equity [Abstract]
Accumulated Other Comprehensive Income (Loss)	Note 13 — Accumulated Other Comprehensive Income (Loss) The tables below present changes in AOCI, net of tax: Three Months Ended June 30, 2021 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — March 31, 2021 $ (25) $ (41) $ (60) $ (126) Other comprehensive income before reclassification adjustments — — 16 16 Amounts reclassified from AOCI — 5 — 5 Other comprehensive income attributable to UGI — 5 16 21 AOCI — June 30, 2021 $ (25) $ (36) $ (44) $ (105) Three Months Ended June 30, 2020 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — March 31, 2020 $ (24) $ (54) $ (152) $ (230) Other comprehensive (loss) income before reclassification adjustments — (8) 28 20 Amounts reclassified from AOCI — 5 — 5 Other comprehensive (loss) income attributable to UGI — (3) 28 25 AOCI — June 30, 2020 $ (24) $ (57) $ (124) $ (205) Nine Months Ended June 30, 2021 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2020 $ (26) $ (54) $ (67) $ (147) Other comprehensive income before reclassification adjustments — 4 23 27 Amounts reclassified from AOCI 1 14 — 15 Other comprehensive income attributable to UGI 1 18 23 42 AOCI — June 30, 2021 $ (25) $ (36) $ (44) $ (105) Nine Months Ended June 30, 2020 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2019 $ (26) $ (25) $ (166) $ (217) Other comprehensive (loss) income before reclassification adjustments — (38) 42 4 Amounts reclassified from AOCI 2 6 — 8 Other comprehensive income (loss) attributable to UGI 2 (32) 42 12 AOCI — June 30, 2020 $ (24) $ (57) $ (124) $ (205)

Segment Information

Segment Information	9 Months Ended
	Jun. 30, 2021
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) UGI 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 2020 Annual Report. Three Months Ended June 30, 2021 Total Eliminations AmeriGas UGI International Midstream & Marketing UGI Corporate Revenues from external customers $ 1,496 $ — $ 526 $ 572 $ 232 $ 171 $ (5) Intersegment revenues $ — $ (40) (b) $ — $ — $ 29 $ 10 $ 1 Cost of sales $ 516 $ (39) (b) $ 267 $ 355 $ 196 $ 67 $ (330) Operating income $ 391 $ — $ 11 $ 40 $ 14 $ 24 $ 302 (Loss) income from equity investees (86) — — — 7 — (93) Other non-operating income (expense), net 1 — — 1 — 1 (1) Earnings before interest expense and income taxes 306 — 11 41 21 25 208 Interest expense (77) — (40) (8) (10) (14) (5) Income (loss) before income taxes $ 229 $ — $ (29) $ 33 $ 11 $ 11 $ 203 Depreciation and amortization $ 125 $ — $ 43 $ 33 $ 19 $ 29 $ 1 Capital expenditures (including the effects of accruals) $ 162 $ — $ 26 $ 21 $ 3 $ 112 $ — Three Months Ended June 30, 2020 Total Eliminations AmeriGas UGI International Midstream & Marketing UGI Corporate Revenues from external customers $ 1,199 $ — $ 451 $ 371 $ 202 $ 172 $ 3 Intersegment revenues $ — $ (28) (b) $ — $ — $ 20 $ 7 $ 1 Cost of sales $ 417 $ (28) (b) $ 178 $ 198 $ 158 $ 68 $ (157) Operating income $ 174 $ — $ 19 $ 17 $ 13 $ 21 $ 104 Income from equity investees 7 — — — 7 — — Other non-operating (expense) income, net (4) — — 4 — — (8) Earnings before interest expense and income taxes 177 — 19 21 20 21 96 Interest expense (80) — (41) (8) (11) (14) (6) Income (loss) before income taxes $ 97 $ — $ (22) $ 13 $ 9 $ 7 $ 90 Depreciation and amortization $ 122 $ — $ 45 $ 30 $ 20 $ 26 $ 1 Capital expenditures (including the effects of accruals) $ 133 $ — $ 30 $ 20 $ 15 $ 68 $ — Nine Months Ended June 30, 2021 Total Eliminations AmeriGas UGI International Midstream & Marketing UGI Corporate Revenues from external customers $ 6,009 $ — $ 2,132 $ 2,106 $ 903 $ 873 $ (5) Intersegment revenues $ — $ (236) (b) $ — $ — $ 183 $ 50 $ 3 Cost of sales $ 2,623 $ (233) (b) $ 970 $ 1,229 $ 776 $ 401 $ (520) Operating income $ 1,564 $ — $ 391 $ 322 $ 156 $ 243 $ 452 (Loss) income from equity investees (69) — — — 24 — (93) Other non-operating income (expense), net — — — 4 — 2 (6) Earnings before interest expense and income taxes 1,495 — 391 326 180 245 353 Interest expense (233) — (120) (21) (31) (42) (19) Income before income taxes $ 1,262 $ — $ 271 $ 305 $ 149 $ 203 $ 334 Depreciation and amortization $ 375 $ — $ 130 $ 100 $ 56 $ 87 $ 2 Capital expenditures (including the effects of accruals) $ 438 $ — $ 83 $ 68 $ 32 $ 255 $ — As of June 30, 2021 Total assets $ 15,006 $ (267) $ 4,381 $ 3,749 $ 2,904 $ 3,997 $ 242 Nine Months Ended June 30, 2020 Total Eliminations AmeriGas UGI International Midstream & Marketing UGI Corporate Revenues from external customers $ 5,435 $ — $ 1,983 $ 1,726 $ 855 $ 863 $ 8 Intersegment revenues $ — $ (202) (b) $ — $ — $ 162 $ 38 $ 2 Cost of sales $ 2,673 $ (201) (b) $ 792 $ 968 $ 721 $ 404 $ (11) Operating income (loss) $ 913 $ — $ 390 $ 230 $ 139 $ 229 $ (75) Income from equity investees 22 — — — 22 — — Other non-operating (expense) income, net (4) — — 17 — — (21) Earnings (loss) before interest expense and income taxes 931 — 390 247 161 229 (96) Interest expense (247) — (124) (23) (34) (41) (25) Income (loss) before income taxes $ 684 $ — $ 266 $ 224 $ 127 $ 188 $ (121) Depreciation and amortization $ 362 $ — $ 134 $ 92 $ 57 $ 78 $ 1 Capital expenditures (including the effects of accruals) $ 444 $ — $ 104 $ 62 $ 61 $ 217 $ — As of June 30, 2020 Total assets $ 13,843 $ (365) $ 4,311 $ 3,208 $ 2,740 $ 3,709 $ 240 (a) Corporate & Other includes specific items attributable to our reportable segments that are not included in the segment profit measures used by our CODM in assessing our reportable segments’ performance or allocating resources. The following table presents such pre-tax gains (losses) which have been included in Corporate & Other, and the reportable segments to which they relate: Three Months Ended June 30, 2021 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (4) Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 59 $ 226 $ 44 Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (1) $ — Business transformation expenses Operating and administrative expenses $ (11) $ (6) $ — Impairment of investment in PennEast (Loss) income from equity investees $ — $ — $ (93) Three Months Ended June 30, 2020 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ 3 Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 60 $ 78 $ 22 Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (7) $ — Business transformation expenses Operating and administrative expenses $ (3) $ (4) $ — Impairment of assets held-for-sale Impairment of assets held-for-sale $ — $ — $ (52) Nine Months Ended June 30, 2021 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (4) Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 123 $ 380 $ 16 Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (6) $ — Business transformation expenses Operating and administrative expenses $ (37) $ (12) $ — Impairment of investment in PennEast (Loss) income from equity investees $ — $ — $ (93) Nine Months Ended June 30, 2020 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ 8 Net gains (losses) on commodity derivative instruments not associated with current-period transactions Cost of sales $ 48 $ (54) $ 19 Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (20) $ — Acquisition and integration expenses associated with the CMG Acquisition Operating and administrative expenses $ — $ — $ (2) Business transformation expenses Operating and administrative expenses $ (27) $ (16) $ — Impairment of assets held-for-sale Impairment of assets held-for-sale $ — $ — $ (52) (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane.

Business Transformation Initiat

Business Transformation Initiatives	9 Months Ended
	Jun. 30, 2021
Restructuring and Related Activities [Abstract]
Business Transformation Initiatives	Note 15 — Business Transformation Initiatives AmeriGas and UGI International. Beginning in Fiscal 2019, we began executing on multi-year business transformation initiatives at our AmeriGas Propane and UGI International business segments. These initiatives are designed to improve long-term operational performance by, among other things, reducing costs and improving efficiency in the areas of sales and marketing, supply and logistics, operations, purchasing, and administration. In addition, these business transformation initiatives focus on enhancing the customer experience through, among other things, enhanced customer relationship management and an improved digital customer experience. In connection with these initiatives, we recognized expenses of $17 and $6 during the three months ended June 30, 2021 and 2020, respectively, and $49 and $43 during the nine months ended June 30, 2021 and 2020, respectively. These expenses principally comprising consulting, advisory, marketing and employee-related costs and are primarily reflected in “Operating and administrative expenses” on the Condensed Consolidated Statements of Income. Corporate Services. Beginning in Fiscal 2020, we initiated a transformation project focused on our support functions including: finance, procurement, human resources, and information technology. This initiative will standardize processes and activities across our global platform, while leveraging the use of best practices and efficiencies between our businesses. In connection with this initiative, we recognized expenses of $4 and $8 for the three and nine months ended June 30, 2021 in “Operating and administrative expenses” on the Condensed Consolidated Statement of Income.

Equity Method Investments

Equity Method Investments	9 Months Ended
	Jun. 30, 2021
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Note 16 — 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. Our equity method investments are primarily comprised of PennEast, Pennant and Pine Run. Fiscal 2021 Developments Pine Run. In February 2021, Pine Run, a company jointly owned by Stonehenge and UGI Pine Run, LLC, a wholly-owned subsidiary of Energy Services, completed the acquisition of Pine Run Midstream, LLC from an affiliate of PennEnergy and minority partners for a preliminary purchase price of $205. Pine Run Midstream, LLC operates 43 miles of dry gas gathering pipeline and compression assets in Butler and Armstrong counties in western Pennsylvania. UGI Pine Run, LLC’s 49% membership interest in Pine Run totaled $59, as of June 30, 2021 and is accounted for as an equity method investment as we have the ability to exercise significant influence, but not control, over the entity. PennEast . UGI PennEast, LLC and four other members comprising wholly owned subsidiaries of Southern Company, New Jersey Resources, South Jersey Industries, and Enbridge, Inc., each hold a 20% membership interest in PennEast. In September 2019, a panel of the U.S. Court of Appeals for the Third Circuit ruled that New Jersey’s Eleventh Amendment immunity barred PennEast from bringing an eminent domain lawsuit in federal court, under the Natural Gas Act, against New Jersey or its agencies. On February 3, 2021, the U.S. Supreme Court issued an order granting PennEast’s petition for a writ of certiorari and the case was argued on April 28, 2021. On June 29, 2021, the U.S. Supreme Court ruled in favor of PennEast, overturning the Third Circuit’s decision that blocked PennEast from exercising federal eminent domain authority over lands in which a state has property rights interests. Following the favorable Supreme Court decision, the partners of the PennEast project re-assessed the remaining legal and regulatory contingencies which must be resolved before construction can commence. Based on the significant remaining legal challenges and the expected further delays in obtaining the necessary regulatory approvals, which are preventing the commencement of construction and commercial operation of the project, the Company concluded that its investment in PennEast was impaired at June 30, 2021, and that such impairment was other-than-temporary. The estimated fair value of the Company’s investment in PennEast was measured using probability-weighted cash flows under an expected present value technique based on management's estimates and assumptions regarding the likelihood of certain outcomes (and the related timing) that would be used by market participants. These assumptions included the estimated fair value of the equipment acquired by the PennEast project (principally pipes, compressors and land) as well as the required regulatory approvals, satisfactory resolution of pending legal matters, the magnitude of construction costs, in-service dates, forecasted revenues and discount rates, as well as the probability weighting of the various scenarios associated with the PennEast project. The ultimate outcome of the PennEast construction project cannot be determined at this time.

Impact of Global Pandemic

Impact of Global Pandemic	9 Months Ended
	Jun. 30, 2021
Unusual or Infrequent Items, or Both [Abstract]
Impact of Global Pandemic	Note 17 — Impact of Global Pandemic In March 2020, the WHO declared a global pandemic attributable to the outbreak and continued spread of COVID-19 that has had a significant impact throughout the global economy. In connection with the mitigation and containment procedures recommended by the WHO, the CDC, and as imposed by federal, state, and local governmental authorities, including shelter-in-place orders, quarantines and similar restrictions, the Company implemented a variety of procedures to protect our employees, third-party business partners, and customers worldwide. The Company continues to provide essential products and services to its global customers in a safe and reliable manner, and will continue to do so in compliance with mandated restrictions presented by each of the markets it serves. The Company continues to evaluate and react to the potential effects of a prolonged disruption and the continued impact on its results of operations. These items may include, but are not limited to: the financial condition of its customers; decreased availability and demand for its products and services; realization of accounts receivable;

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Jun. 30, 2021
Accounting Policies [Abstract]
Restricted Cash	Restricted Cash.
Earnings Per Common Share	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 and common stock awards.
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 UGI Utilities are included in regulatory assets or liabilities because it is probable such gains or losses will be recoverable from, or refundable to, customers. From time to time, we also enter into net investment hedges. Gains and losses on net investment hedges that relate to our foreign operations are included in the cumulative translation adjustment component in AOCI until such foreign net investment is substantially sold or liquidated. Cash flows from derivative instruments, other than certain cross-currency swaps and net investment hedges, if any, are included in cash flows from operating activities on the Condensed Consolidated Statements of Cash Flows. Cash flows from the interest portion of our cross-currency hedges, if any, are included in cash flows from operating activities while cash flows from the currency portion of such hedges, if any, are included in cash flows from financing activities. Cash flows from net investment hedges, if any, are included in cash flows from investing activities on the Condensed Consolidated Statements of Cash Flows.
Use of Estimates	Use of Estimates. The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based on management’s knowledge of current events, historical experience and various other assumptions that are believed to be reasonable under the circumstances. Accordingly, actual results may be different from these estimates and assumptions.
Reclassifications	Reclassifications. Certain prior-period amounts have been reclassified to conform to the current-period presentation.
New Accounting Standards Adopted in Fiscal 2021 And Accounting Standard Not Yet Adopted	New Accounting Standard Adopted in Fiscal 2021 Credit Losses. Effective October 1, 2020, the Company adopted ASU 2016-13, “Measurement of Credit Losses on Financial Instruments,” including subsequent amendments, using a modified retrospective transition approach. This ASU, as subsequently amended, requires entities to estimate lifetime expected credit losses for financial instruments not measured at fair value through net income, including trade and other receivables, net investments in leases, financial receivables, debt securities, and other financial instruments, which may result in earlier recognition of credit losses. Further, the new current expected credit loss model may affect how entities estimate their allowance for losses related to receivables that are current with respect to their payment terms. The adoption of the new guidance did not have a material impact on our consolidated financial statements. Accounting Standard Not Yet Adopted Income Taxes. In December 2019, the FASB issued ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” This ASU simplifies the accounting for income taxes by eliminating certain exceptions within the existing guidance for recognizing deferred taxes for equity method investments, performing intraperiod allocations and calculating income taxes in interim periods. Further, this ASU clarifies existing guidance related to, among other things, recognizing deferred taxes for goodwill and allocated taxes to members of a consolidated group. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2021 (Fiscal 2022). Early adoption is permitted; however, the Company will adopt the new guidance effective October 1, 2021. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance. Debt and Derivatives and Hedging. In August 2020, the FASB issued ASU 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40).” The amendments in this ASU affect entities that issue convertible instruments and/or contracts indexed to and potentially settled in an entity’s own equity. This ASU reduces the number of accounting models for convertible debt instruments and convertible preferred stock, expands disclosure requirements for convertible instruments, and simplifies the related earnings per share guidance. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2022 (Fiscal 2023). Early adoption is permitted. The amendments in this ASU may be adopted using the modified or full retrospective transition methods. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the transition method and the period in which the new guidance will be adopted.
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. Our equity method investments are primarily comprised of PennEast, Pennant and Pine Run.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Jun. 30, 2021
Accounting Policies [Abstract]
Restrictions on Cash and Cash Equivalents	The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Condensed Consolidated Balance Sheets to the corresponding amounts reported on the Condensed Consolidated Statements of Cash Flows. June 30, June 30, September 30, 2020 September 30, 2019 Cash and cash equivalents $ 545 $ 487 $ 336 $ 447 Restricted cash 31 45 21 64 Cash, cash equivalents and restricted cash $ 576 $ 532 $ 357 $ 511
Schedule of Cash and Cash Equivalents	The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Condensed Consolidated Balance Sheets to the corresponding amounts reported on the Condensed Consolidated Statements of Cash Flows. June 30, June 30, September 30, 2020 September 30, 2019 Cash and cash equivalents $ 545 $ 487 $ 336 $ 447 Restricted cash 31 45 21 64 Cash, cash equivalents and restricted cash $ 576 $ 532 $ 357 $ 511
Shares Used in Computing Basic and Diluted Earnings Per Share	Shares used in computing basic and diluted earnings per share are as follows: Three Months Ended Nine Months Ended 2021 2020 2021 2020 Denominator (thousands of shares): Weighted-average common shares outstanding — basic 209,099 208,598 208,934 208,989 Incremental shares issuable for stock options and awards 1,752 377 1,260 1,020 Weighted-average common shares outstanding — diluted 210,851 208,975 210,194 210,009

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	9 Months Ended
	Jun. 30, 2021
Revenue from Contract with Customer [Abstract]
Summary of Disaggregation of Revenue	The following tables present our disaggregated revenues by reportable segment: Three Months Ended June 30, 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 90 $ — $ — $ — $ — $ 90 $ — Commercial & Industrial 34 — — — — 34 — Large delivery service 33 — — — — 33 — Off-system sales and capacity releases 6 (10) — — — 16 — Other 5 — — — — 5 — Total Utility 168 (10) — — — 178 — Non-Utility: LPG: Retail 800 — 424 376 — — — Wholesale 77 — 35 42 — — — Energy Marketing 311 (24) — 129 206 — — Midstream: Pipeline 45 — — — 45 — — Peaking 1 (5) — — 6 — — Other 2 — — — 2 — — Electricity Generation 1 — — — 1 — — Other 69 — 51 18 — — — Total Non-Utility 1,306 (29) 510 565 260 — — Total revenues from contracts with customers 1,474 (39) 510 565 260 178 — Other revenues (b) 22 (1) 16 7 1 3 (4) Total revenues $ 1,496 $ (40) $ 526 $ 572 $ 261 $ 181 $ (4) Three Months Ended June 30, 2020 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 103 $ — $ — $ — $ — $ 103 $ — Commercial & Industrial 30 — — — — 30 — Large delivery service 30 — — — — 30 — Off-system sales and capacity releases 5 (7) — — — 12 — Other 3 — — — — 3 — Total Utility 171 (7) — — — 178 — Non-Utility: LPG: Retail 622 — 372 250 — — — Wholesale 32 — 10 22 — — — Energy Marketing 223 (16) — 81 158 — — Midstream: Pipeline 40 — — — 40 — — Peaking (1) (4) — — 3 — — Other 3 — — — 3 — — Electricity Generation 6 — — — 6 — — Other 75 — 53 13 9 — — Total Non-Utility 1,000 (20) 435 366 219 — — Total revenues from contracts with customers 1,171 (27) 435 366 219 178 — Other revenues (b) 28 (1) 16 5 3 1 4 Total revenues $ 1,199 $ (28) $ 451 $ 371 $ 222 $ 179 $ 4 Nine Months Ended June 30, 2021 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 498 $ — $ — $ — $ — $ 498 $ — Commercial & Industrial 190 — — — — 190 — Large delivery service 117 — — — — 117 — Off-system sales and capacity releases 43 (49) — — — 92 — Other 16 (1) — — — 17 — Total Utility 864 (50) — — — 914 — Non-Utility: LPG: Retail 3,250 — 1,829 1,421 — — — Wholesale 235 — 92 143 — — — Energy Marketing 1,205 (89) — 470 824 — — Midstream: Pipeline 138 — — — 138 — — Peaking 12 (94) — — 106 — — Other 6 — — — 6 — — Electricity Generation 8 — — — 8 — — Other 211 — 161 50 — — — Total Non-Utility 5,065 (183) 2,082 2,084 1,082 — — Total revenues from contracts with customers 5,929 (233) 2,082 2,084 1,082 914 — Other revenues (b) 80 (3) 50 22 4 9 (2) Total revenues $ 6,009 $ (236) $ 2,132 $ 2,106 $ 1,086 $ 923 $ (2) Nine Months Ended June 30, 2020 Total Eliminations AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corporate & Other Revenues from contracts with customers: Utility: Core Market: Residential $ 499 $ — $ — $ — $ — $ 499 $ — Commercial & Industrial 193 — — — — 193 — Large delivery service 113 — — — — 113 — Off-system sales and capacity releases 44 (37) — — — 81 — Other 12 (1) — — — 13 — Total Utility 861 (38) — — — 899 — Non-Utility: LPG: Retail 2,911 — 1,715 1,196 — — — Wholesale 172 — 51 121 — — — Energy Marketing 1,005 (64) — 349 720 — — Midstream: Pipeline 128 — — — 128 — — Peaking 6 (96) — — 102 — — Other 6 — — — 6 — — Electricity Generation 23 — — — 23 — — Other 237 (2) 168 43 28 — — Total Non-Utility 4,488 (162) 1,934 1,709 1,007 — — Total revenues from contracts with customers 5,349 (200) 1,934 1,709 1,007 899 — Other revenues (b) 86 (2) 49 17 10 2 10 Total revenues $ 5,435 $ (202) $ 1,983 $ 1,726 $ 1,017 $ 901 $ 10 (a) Includes intersegment revenues principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane. (b) Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, revenues from alternative revenue programs at UGI Utilities, and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP.

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Jun. 30, 2021
Inventory Disclosure [Abstract]
Components of Inventories	Inventories comprise the following: June 30, September 30, June 30, Non-utility LPG and natural gas $ 187 $ 164 $ 135 Gas Utility natural gas 16 20 11 Materials, supplies and other 93 57 55 Total inventories $ 296 $ 241 $ 201

Utility Regulatory Assets and_2

Utility Regulatory Assets and Liabilities and Regulatory Matters (Tables)	9 Months Ended
	Jun. 30, 2021
Regulated Operations [Abstract]
Schedule of Regulatory Assets	The following regulatory assets and liabilities associated with UGI Utilities are included on the Condensed Consolidated Balance Sheets: June 30, September 30, June 30, Regulatory assets (a): Income taxes recoverable $ 131 $ 124 $ 133 Underfunded pension and postretirement plans 166 175 169 Environmental costs 58 61 62 Removal costs, net 24 26 22 Other 17 11 13 Total regulatory assets $ 396 $ 397 $ 399 Regulatory liabilities (a): Postretirement benefit overcollections $ 12 $ 13 $ 13 Deferred fuel and power refunds 21 29 28 State tax benefits — distribution system repairs 30 28 29 PAPUC Temporary Rates Order — 7 10 Excess federal deferred income taxes 269 274 275 Other 2 2 3 Total regulatory liabilities $ 334 $ 353 $ 358 (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 UGI Utilities are included on the Condensed Consolidated Balance Sheets: June 30, September 30, June 30, Regulatory assets (a): Income taxes recoverable $ 131 $ 124 $ 133 Underfunded pension and postretirement plans 166 175 169 Environmental costs 58 61 62 Removal costs, net 24 26 22 Other 17 11 13 Total regulatory assets $ 396 $ 397 $ 399 Regulatory liabilities (a): Postretirement benefit overcollections $ 12 $ 13 $ 13 Deferred fuel and power refunds 21 29 28 State tax benefits — distribution system repairs 30 28 29 PAPUC Temporary Rates Order — 7 10 Excess federal deferred income taxes 269 274 275 Other 2 2 3 Total regulatory liabilities $ 334 $ 353 $ 358 (a) Current regulatory assets are included in “Prepaid expenses and other current assets” and regulatory liabilities are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets.

Defined Benefit Pension and O_2

Defined Benefit Pension and Other Postretirement Plans (Tables)	9 Months Ended
	Jun. 30, 2021
Retirement Benefits [Abstract]
Components of Net Periodic Pension Expense and Other Postretirement Benefit Costs	Net periodic pension cost includes the following components: Pension Benefits Three Months Ended June 30, 2021 2020 Service cost $ 3 $ 3 Interest cost 5 6 Expected return on assets (10) (10) Amortization of: Actuarial loss 4 4 Net cost $ 2 $ 3 Nine Months Ended June 30, 2021 2020 Service cost $ 9 $ 9 Interest cost 16 18 Expected return on assets (30) (29) Curtailment gain — (1) Amortization of: Actuarial loss 11 11 Net cost $ 6 $ 8

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Jun. 30, 2021
Fair Value Disclosures [Abstract]
Financial Assets and Financial Liabilities that are Measured at Fair Value on a Recurring Basis	The following table presents, on a gross basis, our financial assets and liabilities, including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy: Asset (Liability) Level 1 Level 2 Level 3 Total June 30, 2021: Derivative instruments: Assets: Commodity contracts $ 241 $ 396 $ — $ 637 Foreign currency contracts $ — $ 24 $ — $ 24 Liabilities: Commodity contracts $ (136) $ (9) $ — $ (145) Foreign currency contracts $ — $ (13) $ — $ (13) Interest rate contracts $ — $ (35) $ — $ (35) Non-qualified supplemental postretirement grantor trust investments (a) $ 42 $ — $ — $ 42 September 30, 2020: Derivative instruments: Assets: Commodity contracts $ 68 $ 39 $ — $ 107 Foreign currency contracts $ — $ 32 $ — $ 32 Liabilities: Commodity contracts $ (54) $ (64) $ — $ (118) Foreign currency contracts $ — $ (14) $ — $ (14) Interest rate contracts $ — $ (55) $ — $ (55) Non-qualified supplemental postretirement grantor trust investments (a) $ 42 $ — $ — $ 42 June 30, 2020: Derivative instruments: Assets: Commodity contracts $ 39 $ 29 $ — $ 68 Foreign currency contracts $ — $ 49 $ — $ 49 Liabilities: Commodity contracts $ (58) $ (114) $ — $ (172) Foreign currency contracts $ — $ (7) $ — $ (7) Interest rate contracts $ — $ (59) $ — $ (59) Non-qualified supplemental postretirement grantor trust investments (a) $ 41 $ — $ — $ 41
Schedule of Carrying Amount and Estimated Fair Value of Long-term Debt	The carrying amounts and estimated fair values of our long-term debt (including current maturities but excluding unamortized debt issuance costs) were as follows: June 30, 2021 September 30, 2020 June 30, 2020 Carrying amount $ 5,890 $ 6,081 $ 6,036 Estimated fair value $ 6,314 $ 6,504 $ 6,208

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Jun. 30, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Notional Amounts Related to Open Derivative Contracts	The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at June 30, 2021, September 30, 2020 and June 30, 2020, and the final settlement dates of the Company's open derivative contracts as of June 30, 2021, excluding those derivatives that qualified for the NPNS exception: Notional Amounts Type Units Settlements Extending Through June 30, 2021 September 30, 2020 June 30, 2020 Commodity Price Risk: Regulated Utility Operations Gas Utility NYMEX natural gas futures and option contracts Dekatherms February 2022 12 22 16 Non-utility Operations LPG swaps Gallons November 2023 688 846 890 Natural gas futures, forward, basis swap, options and pipeline contracts Dekatherms July 2026 344 339 343 Electricity forward and futures contracts Kilowatt hours January 2026 4,730 4,705 4,144 Interest Rate Risk: Interest rate swaps Euro October 2022 € 300 € 300 € 300 Interest rate swaps USD September 2024 $ 1,424 $ 1,344 $ 1,347 Foreign Currency Exchange Rate Risk: Forward foreign currency exchange contracts USD October 2024 $ 504 $ 511 $ 440 Net investment hedge forward foreign exchange contracts Euro October 2024 € 173 € 173 € 173
Schedule of Derivative Assets, Liabilities and the Effects of Offsetting	The following table presents the Company’s derivative assets and liabilities by type, as well as the effects of offsetting: June 30, September 30, June 30, Derivative assets: Derivatives designated as hedging instruments: Foreign currency contracts $ 15 $ 17 $ 25 Derivatives subject to PGC and DS mechanisms: Commodity contracts 14 7 3 Derivatives not designated as hedging instruments: Commodity contracts 623 100 65 Foreign currency contracts 9 15 24 632 115 89 Total derivative assets — gross 661 139 117 Gross amounts offset in the balance sheet (77) (57) (42) Cash collateral received (105) — — Total derivative assets — net $ 479 $ 82 $ 75 Derivative liabilities: Derivatives designated as hedging instruments: Interest rate contracts $ (35) $ (55) $ (59) Derivatives subject to PGC and DS mechanisms: Commodity contracts (6) — (2) Derivatives not designated as hedging instruments: Commodity contracts (139) (118) (170) Foreign currency contracts (13) (14) (7) (152) (132) (177) Total derivative liabilities — gross (193) (187) (238) Gross amounts offset in the balance sheet 77 57 42 Cash collateral pledged — 7 21 Total derivative liabilities — net $ (116) $ (123) $ (175)
Effects of Derivative Instruments on Condensed Consolidated Statements of Income and Changes in AOCI and Noncontrolling Interest	The following tables provide information on the effects of derivative instruments on the Condensed Consolidated Statements of Income and changes in AOCI: Three Months Ended June 30,: Gain (Loss) Loss Location of Loss Reclassified from Cash Flow Hedges: 2021 2020 2021 2020 Interest rate contracts $ (1) $ (11) $ (6) $ (6) Interest expense Net Investment Hedges: Foreign currency contracts $ (1) $ (3) Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2021 2020 Location of Gain (Loss) Recognized in Income Commodity contracts $ (5) $ 6 Revenues Commodity contracts 347 127 Cost of sales Commodity contracts — 1 Operating and administrative expenses Foreign currency contracts (1) (5) Other non-operating income (expense), net Total $ 341 $ 129 Nine Months Ended June 30,: Gain (Loss) Loss Location of Loss Reclassified from Cash Flow Hedges: 2021 2020 2021 2020 Interest rate contracts $ 5 $ (53) $ (19) $ (8) Interest expense Net Investment Hedges: Foreign currency contracts $ (2) $ 7 Gain (Loss) Derivatives Not Designated as Hedging Instruments: 2021 2020 Location of Gain (Loss) Recognized in Income Commodity contracts $ (4) $ 14 Revenues Commodity contracts 585 (112) Cost of sales Commodity contracts — 1 Operating and administrative expenses Commodity contracts 5 — Other operating income, net Foreign currency contracts (4) (5) Other non-operating income (expense), net Total $ 582 $ (102)

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	9 Months Ended
	Jun. 30, 2021
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income	The tables below present changes in AOCI, net of tax: Three Months Ended June 30, 2021 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — March 31, 2021 $ (25) $ (41) $ (60) $ (126) Other comprehensive income before reclassification adjustments — — 16 16 Amounts reclassified from AOCI — 5 — 5 Other comprehensive income attributable to UGI — 5 16 21 AOCI — June 30, 2021 $ (25) $ (36) $ (44) $ (105) Three Months Ended June 30, 2020 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — March 31, 2020 $ (24) $ (54) $ (152) $ (230) Other comprehensive (loss) income before reclassification adjustments — (8) 28 20 Amounts reclassified from AOCI — 5 — 5 Other comprehensive (loss) income attributable to UGI — (3) 28 25 AOCI — June 30, 2020 $ (24) $ (57) $ (124) $ (205) Nine Months Ended June 30, 2021 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2020 $ (26) $ (54) $ (67) $ (147) Other comprehensive income before reclassification adjustments — 4 23 27 Amounts reclassified from AOCI 1 14 — 15 Other comprehensive income attributable to UGI 1 18 23 42 AOCI — June 30, 2021 $ (25) $ (36) $ (44) $ (105) Nine Months Ended June 30, 2020 Postretirement Benefit Plans Derivative Instruments Foreign Currency Total AOCI — September 30, 2019 $ (26) $ (25) $ (166) $ (217) Other comprehensive (loss) income before reclassification adjustments — (38) 42 4 Amounts reclassified from AOCI 2 6 — 8 Other comprehensive income (loss) attributable to UGI 2 (32) 42 12 AOCI — June 30, 2020 $ (24) $ (57) $ (124) $ (205)

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Jun. 30, 2021
Segment Reporting [Abstract]
Schedule of Segment Reporting Information	Three Months Ended June 30, 2021 Total Eliminations AmeriGas UGI International Midstream & Marketing UGI Corporate Revenues from external customers $ 1,496 $ — $ 526 $ 572 $ 232 $ 171 $ (5) Intersegment revenues $ — $ (40) (b) $ — $ — $ 29 $ 10 $ 1 Cost of sales $ 516 $ (39) (b) $ 267 $ 355 $ 196 $ 67 $ (330) Operating income $ 391 $ — $ 11 $ 40 $ 14 $ 24 $ 302 (Loss) income from equity investees (86) — — — 7 — (93) Other non-operating income (expense), net 1 — — 1 — 1 (1) Earnings before interest expense and income taxes 306 — 11 41 21 25 208 Interest expense (77) — (40) (8) (10) (14) (5) Income (loss) before income taxes $ 229 $ — $ (29) $ 33 $ 11 $ 11 $ 203 Depreciation and amortization $ 125 $ — $ 43 $ 33 $ 19 $ 29 $ 1 Capital expenditures (including the effects of accruals) $ 162 $ — $ 26 $ 21 $ 3 $ 112 $ — Three Months Ended June 30, 2020 Total Eliminations AmeriGas UGI International Midstream & Marketing UGI Corporate Revenues from external customers $ 1,199 $ — $ 451 $ 371 $ 202 $ 172 $ 3 Intersegment revenues $ — $ (28) (b) $ — $ — $ 20 $ 7 $ 1 Cost of sales $ 417 $ (28) (b) $ 178 $ 198 $ 158 $ 68 $ (157) Operating income $ 174 $ — $ 19 $ 17 $ 13 $ 21 $ 104 Income from equity investees 7 — — — 7 — — Other non-operating (expense) income, net (4) — — 4 — — (8) Earnings before interest expense and income taxes 177 — 19 21 20 21 96 Interest expense (80) — (41) (8) (11) (14) (6) Income (loss) before income taxes $ 97 $ — $ (22) $ 13 $ 9 $ 7 $ 90 Depreciation and amortization $ 122 $ — $ 45 $ 30 $ 20 $ 26 $ 1 Capital expenditures (including the effects of accruals) $ 133 $ — $ 30 $ 20 $ 15 $ 68 $ — Nine Months Ended June 30, 2021 Total Eliminations AmeriGas UGI International Midstream & Marketing UGI Corporate Revenues from external customers $ 6,009 $ — $ 2,132 $ 2,106 $ 903 $ 873 $ (5) Intersegment revenues $ — $ (236) (b) $ — $ — $ 183 $ 50 $ 3 Cost of sales $ 2,623 $ (233) (b) $ 970 $ 1,229 $ 776 $ 401 $ (520) Operating income $ 1,564 $ — $ 391 $ 322 $ 156 $ 243 $ 452 (Loss) income from equity investees (69) — — — 24 — (93) Other non-operating income (expense), net — — — 4 — 2 (6) Earnings before interest expense and income taxes 1,495 — 391 326 180 245 353 Interest expense (233) — (120) (21) (31) (42) (19) Income before income taxes $ 1,262 $ — $ 271 $ 305 $ 149 $ 203 $ 334 Depreciation and amortization $ 375 $ — $ 130 $ 100 $ 56 $ 87 $ 2 Capital expenditures (including the effects of accruals) $ 438 $ — $ 83 $ 68 $ 32 $ 255 $ — As of June 30, 2021 Total assets $ 15,006 $ (267) $ 4,381 $ 3,749 $ 2,904 $ 3,997 $ 242 Nine Months Ended June 30, 2020 Total Eliminations AmeriGas UGI International Midstream & Marketing UGI Corporate Revenues from external customers $ 5,435 $ — $ 1,983 $ 1,726 $ 855 $ 863 $ 8 Intersegment revenues $ — $ (202) (b) $ — $ — $ 162 $ 38 $ 2 Cost of sales $ 2,673 $ (201) (b) $ 792 $ 968 $ 721 $ 404 $ (11) Operating income (loss) $ 913 $ — $ 390 $ 230 $ 139 $ 229 $ (75) Income from equity investees 22 — — — 22 — — Other non-operating (expense) income, net (4) — — 17 — — (21) Earnings (loss) before interest expense and income taxes 931 — 390 247 161 229 (96) Interest expense (247) — (124) (23) (34) (41) (25) Income (loss) before income taxes $ 684 $ — $ 266 $ 224 $ 127 $ 188 $ (121) Depreciation and amortization $ 362 $ — $ 134 $ 92 $ 57 $ 78 $ 1 Capital expenditures (including the effects of accruals) $ 444 $ — $ 104 $ 62 $ 61 $ 217 $ — As of June 30, 2020 Total assets $ 13,843 $ (365) $ 4,311 $ 3,208 $ 2,740 $ 3,709 $ 240 (a) Corporate & Other includes specific items attributable to our reportable segments that are not included in the segment profit measures used by our CODM in assessing our reportable segments’ performance or allocating resources. The following table presents such pre-tax gains (losses) which have been included in Corporate & Other, and the reportable segments to which they relate: Three Months Ended June 30, 2021 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (4) Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 59 $ 226 $ 44 Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (1) $ — Business transformation expenses Operating and administrative expenses $ (11) $ (6) $ — Impairment of investment in PennEast (Loss) income from equity investees $ — $ — $ (93) Three Months Ended June 30, 2020 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ 3 Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 60 $ 78 $ 22 Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (7) $ — Business transformation expenses Operating and administrative expenses $ (3) $ (4) $ — Impairment of assets held-for-sale Impairment of assets held-for-sale $ — $ — $ (52) Nine Months Ended June 30, 2021 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net losses on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ (4) Net gains on commodity derivative instruments not associated with current-period transactions Cost of sales $ 123 $ 380 $ 16 Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (6) $ — Business transformation expenses Operating and administrative expenses $ (37) $ (12) $ — Impairment of investment in PennEast (Loss) income from equity investees $ — $ — $ (93) Nine Months Ended June 30, 2020 Location on Income Statement AmeriGas Propane UGI International Midstream & Marketing Net gains on commodity derivative instruments not associated with current-period transactions Revenues $ — $ — $ 8 Net gains (losses) on commodity derivative instruments not associated with current-period transactions Cost of sales $ 48 $ (54) $ 19 Unrealized losses on foreign currency derivative instruments Other non-operating income (expense), net $ — $ (20) $ — Acquisition and integration expenses associated with the CMG Acquisition Operating and administrative expenses $ — $ — $ (2) Business transformation expenses Operating and administrative expenses $ (27) $ (16) $ — Impairment of assets held-for-sale Impairment of assets held-for-sale $ — $ — $ (52) (b) Represents the elimination of intersegment transactions principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane.

Nature of Operations (Details)

Nature of Operations (Details) Customer in Thousands, $ in Millions	Dec. 29, 2020USD ($)countyCustomer	Jun. 30, 2021county
Mountaineer | Pending
Business Acquisition [Line Items]
Number of counties of operation | county	50
Enterprise value | $	$ 540
Assumption of debt | $	$ 140
Customers served | Customer	215
Gas Utility | MARYLAND
Business Acquisition [Line Items]
Number of counties of operation | county		1

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Schedule of Cash and Restricted Cash (Details) - USD ($) $ in Millions	Jun. 30, 2021	Sep. 30, 2020	Jun. 30, 2020	Sep. 30, 2019
Accounting Policies [Abstract]
Cash and cash equivalents	$ 545	$ 336	$ 487	$ 447
Restricted cash	31	21	45	64
Cash, cash equivalents and restricted cash	$ 576	$ 357	$ 532	$ 511

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Shares Used in Computing Basic and Diluted Earnings Per Share (Details) - shares	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Denominator:
Weighted-average common shares outstanding - basic (in shares)	209,099,000	208,598,000	208,934,000	208,989,000
Incremental shares issuable for stock options and awards (in shares)	1,752,000	377,000	1,260,000	1,020,000
Weighted-average common shares outstanding - diluted (in shares)	210,851,000	208,975,000	210,194,000	210,009,000
Antidilutive securities excluded from computation of earnings per share (in shares)	2,502	2,502	7,083	7,083

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Narrative (Details) - USD ($)	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	May 31, 2021	May 25, 2021	Jul. 21, 2020
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Shares issued on conversion settlement (in shares)					1	1
Impairment of assets held-for-sale	$ 0	$ 52,000,000	$ 0	$ 52,000,000
Conemaugh | Energy Services
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Ownership percent							5.97%
Equity Units | Preferred stock, without par value
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Notional value						$ 220,000,000
Liquidation preference (in USD per share)						$ 1,000
Convertible Preferred Stock
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Liquidation preference (in USD per share)					$ 1,000	$ 1,000

Revenue from Contracts with C_3

Revenue from Contracts with Customers - Disaggregation (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 1,474	$ 1,171	$ 5,929	$ 5,349
Other revenue	22	28	80	86
Total revenues	1,496	1,199	6,009	5,435
Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	168	171	864	861
Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	90	103	498	499
Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	34	30	190	193
Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	33	30	117	113
Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	6	5	43	44
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	5	3	16	12
Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,306	1,000	5,065	4,488
Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	800	622	3,250	2,911
Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	77	32	235	172
Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	311	223	1,205	1,005
Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	45	40	138	128
Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1	(1)	12	6
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2	3	6	6
Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1	6	8	23
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	69	75	211	237
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(39)	(27)	(233)	(200)
Other revenue	(1)	(1)	(3)	(2)
Total revenues	(40)	(28)	(236)	(202)
Eliminations | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(10)	(7)	(50)	(38)
Eliminations | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(10)	(7)	(49)	(37)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	(1)	(1)
Eliminations | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(29)	(20)	(183)	(162)
Eliminations | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(24)	(16)	(89)	(64)
Eliminations | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(5)	(4)	(94)	(96)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	(2)
Eliminations | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Eliminations | UGI International
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Eliminations | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues	29	20	183	162
Eliminations | UGI Utilities
Disaggregation of Revenue [Line Items]
Total revenues	10	7	50	38
Operating Segments | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	510	435	2,082	1,934
Other revenue	16	16	50	49
Total revenues	526	451	2,132	1,983
Operating Segments | AmeriGas Propane | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	510	435	2,082	1,934
Operating Segments | AmeriGas Propane | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	424	372	1,829	1,715
Operating Segments | AmeriGas Propane | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	35	10	92	51
Operating Segments | AmeriGas Propane | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | AmeriGas Propane | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	51	53	161	168
Operating Segments | UGI International
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	565	366	2,084	1,709
Other revenue	7	5	22	17
Total revenues	572	371	2,106	1,726
Operating Segments | UGI International | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	565	366	2,084	1,709
Operating Segments | UGI International | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	376	250	1,421	1,196
Operating Segments | UGI International | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	42	22	143	121
Operating Segments | UGI International | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	129	81	470	349
Operating Segments | UGI International | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI International | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	18	13	50	43
Operating Segments | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	260	219	1,082	1,007
Other revenue	1	3	4	10
Total revenues	261	222	1,086	1,017
Operating Segments | Midstream & Marketing | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	260	219	1,082	1,007
Operating Segments | Midstream & Marketing | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | Midstream & Marketing | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	206	158	824	720
Operating Segments | Midstream & Marketing | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	45	40	138	128
Operating Segments | Midstream & Marketing | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	6	3	106	102
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2	3	6	6
Operating Segments | Midstream & Marketing | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1	6	8	23
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	9	0	28
Operating Segments | UGI Utilities
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	178	178	914	899
Other revenue	3	1	9	2
Total revenues	181	179	923	901
Operating Segments | UGI Utilities | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	178	178	914	899
Operating Segments | UGI Utilities | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	90	103	498	499
Operating Segments | UGI Utilities | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	34	30	190	193
Operating Segments | UGI Utilities | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	33	30	117	113
Operating Segments | UGI Utilities | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	16	12	92	81
Operating Segments | UGI Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	5	3	17	13
Operating Segments | UGI Utilities | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI Utilities | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI Utilities | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI Utilities | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI Utilities | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI Utilities | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI Utilities | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Operating Segments | UGI Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Other revenue	(4)	4	(2)	10
Total revenues	(4)	4	(2)	10
Corporate & Other | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0	0	0	0
Corporate & Other | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 0	$ 0	$ 0	$ 0

Revenue from Contracts with C_4

Revenue from Contracts with Customers - Narrative (Details) - USD ($) $ in Millions	9 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Contract liabilities	$ 104		$ 109	$ 161
Contract with customer, liability, revenue recognized	$ 137	$ 122
Midstream & Marketing
Disaggregation of Revenue [Line Items]
Revenue, remaining performance obligation			2,000
UGI Utilities
Disaggregation of Revenue [Line Items]
Revenue, remaining performance obligation			$ 200

Inventories - Components of Inv

Inventories - Components of Inventories (Details) - USD ($) $ in Millions	Jun. 30, 2021	Sep. 30, 2020	Jun. 30, 2020
Inventory
Total inventories	$ 296	$ 241	$ 201
Non-utility LPG and natural gas
Inventory
Total inventories	187	164	135
Gas Utility natural gas
Inventory
Total inventories	16	20	11
Materials, supplies and other
Inventory
Total inventories	$ 93	$ 57	$ 55

Utility Regulatory Assets and_3

Utility Regulatory Assets and Liabilities and Regulatory Matters - Schedule of Regulatory Assets and Liabilities (Details) - UGI Utilities - USD ($) $ in Millions	Jun. 30, 2021	Sep. 30, 2020	Jun. 30, 2020
Regulatory Assets
Regulatory assets	$ 396	$ 397	$ 399
Regulatory Liabilities
Regulatory liabilities	334	353	358
Postretirement benefit overcollections
Regulatory Liabilities
Regulatory liabilities	12	13	13
Deferred fuel and power refunds
Regulatory Liabilities
Regulatory liabilities	21	29	28
State tax benefits — distribution system repairs
Regulatory Liabilities
Regulatory liabilities	30	28	29
PAPUC temporary rates order
Regulatory Liabilities
Regulatory liabilities	0	7	10
Excess federal deferred income taxes
Regulatory Liabilities
Regulatory liabilities	269	274	275
Other
Regulatory Liabilities
Regulatory liabilities	2	2	3
Income taxes recoverable
Regulatory Assets
Regulatory assets	131	124	133
Underfunded pension and postretirement plans
Regulatory Assets
Regulatory assets	166	175	169
Environmental costs
Regulatory Assets
Regulatory assets	58	61	62
Removal costs, net
Regulatory Assets
Regulatory assets	24	26	22
Other
Regulatory Assets
Regulatory assets	$ 17	$ 11	$ 13

Utility Regulatory Assets and_4

Utility Regulatory Assets and Liabilities and Regulatory Matters - Narrative (Details) - USD ($)	Jul. 19, 2021	Feb. 08, 2021	Oct. 08, 2020	Jan. 28, 2020	Oct. 11, 2019	Jan. 28, 2019	Jun. 30, 2021	Sep. 30, 2020	Jun. 30, 2020
PAPUC | UGI Electric
Regulatory Assets
Public utilities, requested rate increase (decrease), amount		$ 9,000,000
PAPUC | UGI Electric | Joint Petition | Subsequent Event
Regulatory Assets
Public utilities, requested rate increase (decrease), amount	$ 6,000,000
PAPUC | UGI Gas
Regulatory Assets
Public utilities, requested rate increase (decrease), amount				$ 75,000,000		$ 71,000,000
Public utilities, approved rate increase (decrease), amount			$ 20,000,000		$ 30,000,000
Property, plant and equipment, net threshold			$ 2,875,000,000
Amortization period			10 years
Tax benefit to be returned, period					5 years
Tax benefit to be returned					$ 24,000,000
Effective period					12 months
PAPUC | UGI Gas | Beginning January 1, 2021
Regulatory Assets
Public utilities, approved rate increase (decrease), amount			$ 10,000,000
PAPUC | UGI Gas | Beginning July 1, 2021
Regulatory Assets
Public utilities, approved rate increase (decrease), amount			$ 10,000,000
Gas Utility
Regulatory Assets
Fair value of unrealized gains (losses)							$ 9,000,000	$ 8,000,000	$ 1,000,000

Debt - Narrative (Details)

Debt - Narrative (Details)	Jul. 09, 2021USD ($)	May 25, 2021USD ($)	May 04, 2021	May 03, 2021USD ($)	Jun. 30, 2021USD ($)	Jun. 15, 2021USD ($)	Jun. 09, 2021USD ($)	Jun. 08, 2021USD ($)	May 07, 2021USD ($)
Term Loan | 2021 UGI Corporation Senior Credit Facility
Debt Instrument [Line Items]
Debt term (in years)			4 years	3 years
Maximum borrowing capacity				$ 300,000,000			$ 215,000,000	$ 300,000,000
Line of Credit | Revolving Credit Facility
Debt Instrument [Line Items]
Debt term (in years)		5 years			5 years
Maximum borrowing capacity		$ 300,000,000			$ 300,000,000
Repayment of debt					$ 285,000,000
Line of Credit | Revolving Credit Facility | Subsequent Event
Debt Instrument [Line Items]
Repayment of debt	$ 15,000,000
Line of Credit | 2021 UGI Corporation Senior Credit Facility
Debt Instrument [Line Items]
Ratio of consolidated net indebtedness to consolidated EBITDA			4.50
Ratio of consolidated net indebtedness to consolidated EBITDA during acquisition			4.75
Ratio of consolidated EBITDA to consolidated interest expense			3.50
Line of Credit | 2021 UGI Corporation Senior Credit Facility | Minimum | Prime Rate
Debt Instrument [Line Items]
Basis spread on variable rate			0.125%
Line of Credit | 2021 UGI Corporation Senior Credit Facility | Minimum | LIBOR
Debt Instrument [Line Items]
Basis spread on variable rate			1.125%
Line of Credit | 2021 UGI Corporation Senior Credit Facility | Maximum | Prime Rate
Debt Instrument [Line Items]
Basis spread on variable rate			1.50%
Line of Credit | 2021 UGI Corporation Senior Credit Facility | Maximum | LIBOR
Debt Instrument [Line Items]
Basis spread on variable rate			2.50%
Senior Notes | 2021 UGI Corporation Senior Credit Facility | UGI Utilities
Debt Instrument [Line Items]
Ratio of consolidated debt to consolidated total capital, maximum									0.65
Senior Notes | 1.59% Senior Notes due June 2026 | UGI Utilities
Debt Instrument [Line Items]
Aggregate principal amount						$ 100,000,000
Stated interest rate						1.59%
Senior Notes | 1.59% Senior Notes due June 2026 | UGI Utilities | Expected
Debt Instrument [Line Items]
Aggregate principal amount									$ 100,000,000
Stated interest rate									1.59%
Senior Notes | 1.64% Senior Notes due September 2026 | UGI Utilities | Expected
Debt Instrument [Line Items]
Aggregate principal amount									$ 75,000,000
Stated interest rate									1.64%

Issuance of Equity Units (Detai

Issuance of Equity Units (Details) - USD ($)	Jun. 01, 2024	May 25, 2021	Jun. 30, 2021	Jun. 30, 2021	May 31, 2021	May 17, 2021	Sep. 30, 2020	Jun. 30, 2020
Class of Stock [Line Items]
Recorded value			$ 213,000,000	$ 213,000,000			$ 0	$ 0
Shares issued on conversion settlement (in shares)		1			1
Sale price (in USD per share)						$ 43.81
Quarterly contract adjustment payments liability			45,000,000	45,000,000
Accretion of Purchase Contract Adjustment Liability			0	$ 0
Revolving Credit Facility | Line of Credit
Class of Stock [Line Items]
Debt term (in years)		5 years		5 years
Maximum borrowing capacity		$ 300,000,000	$ 300,000,000	$ 300,000,000
2024 Purchase Contracts
Class of Stock [Line Items]
Contract redemption obligation		$ 100
Maximum settlement rate		2.2826
Number of common stock deliverable percentage		85.00%
Quarterly contract adjustment payments percentage		7.125%
2024 Purchase Contracts | Forecast
Class of Stock [Line Items]
Contract redemption obligation	$ 100
Equity Units | Preferred stock, without par value
Class of Stock [Line Items]
Units and shares sold (in shares)		2,200,000
Notional value		$ 220,000,000
Stated value (in USD per share)		$ 100
Undivided beneficial ownership interest		10.00%
Liquidation preference (in USD per share)		$ 1,000
Proceeds from issuance		$ 213,000,000
Convertible Preferred Stock
Class of Stock [Line Items]
Liquidation preference (in USD per share)		$ 1,000			$ 1,000
Dividend rate		0.125%
Conversion ratio		19.0215
Stock conversion price (in USD per share)		$ 52.57
Convertible Preferred Stock | Preferred stock, without par value
Class of Stock [Line Items]
Units and shares sold (in shares)		220,000
Recorded value		$ 213,000,000

Commitments and Contingencies (

Commitments and Contingencies (Details)	9 Months Ended	12 Months Ended
	Jun. 30, 2021USD ($)subsidiary	Sep. 30, 2017USD ($)record_of_decision	Dec. 31, 2008lb	Dec. 31, 2007lb	Sep. 30, 2020USD ($)	Jun. 30, 2020USD ($)
Loss Contingencies
Environmental expenditures cap during calendar year	$ 5,000,000
Amount of propane in cylinders before reduction (in pounds) | lb				17
Amount of propane in cylinders after reduction (in pounds) | lb			15
CPG, PNG and UGI Gas COAs
Loss Contingencies
Accrual for environmental loss contingencies	$ 49,000,000				$ 53,000,000	$ 55,000,000
UGI Utilities | PNG and CPG
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 Expense and Other Postretirement Benefit Costs (Details) - Pension Benefits - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Defined Benefit Plan Disclosure
Service cost	$ 3	$ 3	$ 9	$ 9
Interest cost	5	6	16	18
Expected return on assets	(10)	(10)	(30)	(29)
Curtailment gain			0	(1)
Amortization of:
Actuarial loss	4	4	11	11
Net cost	$ 2	$ 3	$ 6	$ 8

Fair Value Measurements - Finan

Fair Value Measurements - Financial Assets and Liabilities that are Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Millions	Jun. 30, 2021	Sep. 30, 2020	Jun. 30, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	$ 661	$ 139	$ 117
Derivative instruments, Liabilities	(193)	(187)	(238)
Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	14	7	3
Derivative instruments, Liabilities	(6)	0	(2)
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	42	42	41
Recurring | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	637	107	68
Derivative instruments, Liabilities	(145)	(118)	(172)
Recurring | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	24	32	49
Derivative instruments, Liabilities	(13)	(14)	(7)
Recurring | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Liabilities	(35)	(55)	(59)
Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	42	42	41
Recurring | Level 1 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	241	68	39
Derivative instruments, Liabilities	(136)	(54)	(58)
Recurring | Level 1 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	0	0	0
Derivative instruments, Liabilities	0	0	0
Recurring | Level 1 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Liabilities	0	0	0
Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	0	0	0
Recurring | Level 2 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	396	39	29
Derivative instruments, Liabilities	(9)	(64)	(114)
Recurring | Level 2 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	24	32	49
Derivative instruments, Liabilities	(13)	(14)	(7)
Recurring | Level 2 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Liabilities	(35)	(55)	(59)
Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	0	0	0
Recurring | Level 3 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	0	0	0
Derivative instruments, Liabilities	0	0	0
Recurring | Level 3 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	0	0	0
Derivative instruments, Liabilities	0	0	0
Recurring | Level 3 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Liabilities	$ 0	$ 0	$ 0

Fair Value Measurements - (Deta

Fair Value Measurements - (Details) - USD ($) $ in Millions	Jun. 30, 2021	Sep. 30, 2020	Jun. 30, 2020
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 5,890	$ 6,081	$ 6,036
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,314	$ 6,504	$ 6,208

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Narrative (Details)	3 Months Ended		9 Months Ended
	Jun. 30, 2021USD ($)agreement	Jun. 30, 2020USD ($)	Jun. 30, 2021USD ($)agreement	Jun. 30, 2020USD ($)	Jun. 09, 2021USD ($)	Jun. 08, 2021USD ($)	May 03, 2021USD ($)	Sep. 30, 2020USD ($)
Derivative [Line Items]
AOCI, Net Investment Hedge, Gain (Loss), Reclassification, before Tax	$ (8,000,000)	$ (13,000,000)	$ (9,000,000)	$ (22,000,000)
Term Loan | 2021 UGI Corporation Senior Credit Facility
Derivative [Line Items]
Maximum borrowing capacity					$ 215,000,000	$ 300,000,000	$ 300,000,000
Forward Starting, Pay-fixed, Receive-variable Interest Rate Swap Agreement
Derivative [Line Items]
Number of receive-variable interest rate swap agreements | agreement	2		2
Forward Starting, Pay-fixed, Receive-variable Interest Rate Swap Agreement | Derivatives designated as hedging instruments:
Derivative [Line Items]
Notional amount	$ 125,000,000		$ 125,000,000
Variable interest rate	0.0069		0.0069
IRPAs
Derivative [Line Items]
Notional amount	$ 0	$ 0	$ 0	$ 0				$ 0
Pre-tax net losses associated with interest rate hedges	$ 4,000,000		$ 4,000,000
Forward Foreign Currency Exchange Contracts
Derivative [Line Items]
Derivative notional amount percent of required need coverage	90.00%		90.00%

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Schedule of Notional Amounts (Details) € in Millions, kWh in Millions, gal in Millions, DTH in Millions, $ in Millions	Jun. 30, 2021USD ($)kWhDTHgal	Jun. 30, 2021EUR (€)kWhDTHgal	Sep. 30, 2020USD ($)DTHkWhgal	Sep. 30, 2020EUR (€)DTHkWhgal	Jun. 30, 2020USD ($)DTHkWhgal	Jun. 30, 2020EUR (€)DTHkWhgal
Interest rate swaps
Derivative [Line Items]
Notional amount	$ 1,424	€ 300	$ 1,344	€ 300	$ 1,347	€ 300
Forward foreign currency exchange contracts
Derivative [Line Items]
Notional amount	$ 504	€ 173	$ 511	€ 173	$ 440	€ 173
Regulated Utility Operations | Commodity contracts | Natural Gas
Derivative [Line Items]
Notional amount (in units)	12	12	22	22	16	16
Non-utility Operations | Commodity contracts | LPG
Derivative [Line Items]
Notional amount (in units) | gal	688	688	846	846	890	890
Non-utility Operations | Commodity contracts | Electricity | Long
Derivative [Line Items]
Notional amount (in units) | kWh	4,730	4,730	4,705	4,705	4,144	4,144
Non-utility Operations | Natural gas futures, forward and pipeline contracts (in dekatherms) | Natural Gas
Derivative [Line Items]
Notional amount (in units)	344	344	339	339	343	343

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2021	Sep. 30, 2020	Jun. 30, 2020
Derivative assets:
Total derivative assets — gross	$ 661	$ 139	$ 117
Gross amounts offset in the balance sheet	(77)	(57)	(42)
Cash collateral received	(105)	0	0
Total derivative assets — net	479	82	75
Derivative liabilities:
Total derivative liabilities — gross	(193)	(187)	(238)
Gross amounts offset in the balance sheet	77	57	42
Cash collateral pledged	0	7	21
Total derivative liabilities — net	(116)	(123)	(175)
Commodity contracts
Derivative assets:
Total derivative assets — gross	14	7	3
Derivative liabilities:
Total derivative liabilities — gross	(6)	0	(2)
Derivatives designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	15	17	25
Derivatives designated as hedging instruments: | Interest rate contracts
Derivative liabilities:
Total derivative liabilities — gross	(35)	(55)	(59)
Derivatives not designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	632	115	89
Derivative liabilities:
Total derivative liabilities — gross	(152)	(132)	(177)
Derivatives not designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	9	15	24
Derivative liabilities:
Total derivative liabilities — gross	(13)	(14)	(7)
Derivatives not designated as hedging instruments: | Commodity contracts
Derivative assets:
Total derivative assets — gross	623	100	65
Derivative liabilities:
Total derivative liabilities — gross	$ (139)	$ (118)	$ (170)

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Effects of Derivative Instruments on the Condensed Consolidated Statements of Income and Changes in AOCI (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Derivatives Not Designated as Hedging Instruments
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 341	$ 129	$ 582	$ (102)
Interest rate contracts | Derivatives designated as hedging instruments: | Cash Flow Hedges
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	(1)	(11)	5	(53)
Interest rate contracts | Derivatives designated as hedging instruments: | Interest expense | Cash Flow Hedges
Derivative Instruments, Gain (Loss)
Loss Reclassified from AOCI into Income	(6)	(6)	(19)	(8)
Foreign currency contracts | Derivatives designated as hedging instruments: | Net Investment Hedging
Derivative Instruments, Gain (Loss)
Foreign currency contracts	(1)	(3)	(2)	7
Foreign currency contracts | Derivatives Not Designated as Hedging Instruments | Other non-operating income (expense), net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(1)	(5)	(4)	(5)
Commodity contracts | Derivatives Not Designated as Hedging Instruments | Revenues
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(5)	6	(4)	14
Commodity contracts | Derivatives Not Designated as Hedging Instruments | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	347	127	585	(112)
Commodity contracts | Derivatives Not Designated as Hedging Instruments | Operating and administrative expenses
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 0	$ 1	0	1
Commodity contracts | Derivatives Not Designated as Hedging Instruments | Other operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income			$ 5	$ 0

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period			$ 4,137
Other comprehensive (loss) income before reclassification adjustments	$ 16	$ 20	27	$ 4
Amounts reclassified from AOCI	5	5	15	8
Other comprehensive income attributable to UGI	21	25	42	12
Balance, end of period	5,106	4,135	5,106	4,135
Postretirement Benefit Plans
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(25)	(24)	(26)	(26)
Other comprehensive (loss) income before reclassification adjustments	0	0	0	0
Amounts reclassified from AOCI	0	0	1	2
Other comprehensive income attributable to UGI	0	0	1	2
Balance, end of period	(25)	(24)	(25)	(24)
Derivative Instruments
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(41)	(54)	(54)	(25)
Other comprehensive (loss) income before reclassification adjustments	0	(8)	4	(38)
Amounts reclassified from AOCI	5	5	14	6
Other comprehensive income attributable to UGI	5	(3)	18	(32)
Balance, end of period	(36)	(57)	(36)	(57)
Foreign Currency
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(60)	(152)	(67)	(166)
Other comprehensive (loss) income before reclassification adjustments	16	28	23	42
Amounts reclassified from AOCI	0	0	0	0
Other comprehensive income attributable to UGI	16	28	23	42
Balance, end of period	(44)	(124)	(44)	(124)
Total
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(126)	(230)	(147)	(217)
Balance, end of period	$ (105)	$ (205)	$ (105)	$ (205)

Segment Information - Narrative

Segment Information - Narrative (Details)	9 Months Ended
	Jun. 30, 2021segment
Segment Reporting [Abstract]
Number of reportable segments	4

Segment Information - Schedule

Segment Information - Schedule of Segment Reporting Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Sep. 30, 2020
Segment Reporting Information [Line Items]
Revenues	$ 1,496	$ 1,199	$ 6,009	$ 5,435
Cost of sales	516	417	2,623	2,673
Operating income (loss)	391	174	1,564	913
(Loss) income from equity investees	(86)	7	(69)	22
Other non-operating income (expense), net	1	(4)	0	(4)
Earnings (loss) before interest expense and income taxes	306	177	1,495	931
Interest expense	(77)	(80)	(233)	(247)
Income (loss) before income taxes	229	97	1,262	684
Depreciation and amortization	125	122	375	362
Capital expenditures (including the effects of accruals)	162	133	438	444
Total assets	15,006	13,843	15,006	13,843	$ 13,985
Eliminations
Segment Reporting Information [Line Items]
Revenues	(40)	(28)	(236)	(202)
Cost of sales	(39)	(28)	(233)	(201)
Operating income (loss)	0	0	0	0
(Loss) income from equity investees	0	0	0	0
Other non-operating income (expense), net	0	0	0	0
Earnings (loss) before interest expense and income taxes	0	0	0	0
Interest expense	0	0	0	0
Income (loss) before income taxes	0	0	0	0
Depreciation and amortization	0	0	0	0
Capital expenditures (including the effects of accruals)	0	0	0	0
Total assets	(267)	(365)	(267)	(365)
Eliminations | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Eliminations | UGI International
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Eliminations | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	29	20	183	162
Eliminations | UGI Utilities
Segment Reporting Information [Line Items]
Revenues	10	7	50	38
Operating Segments | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	526	451	2,132	1,983
Cost of sales	267	178	970	792
Operating income (loss)	11	19	391	390
(Loss) income from equity investees	0	0	0	0
Other non-operating income (expense), net	0	0	0	0
Earnings (loss) before interest expense and income taxes	11	19	391	390
Interest expense	(40)	(41)	(120)	(124)
Income (loss) before income taxes	(29)	(22)	271	266
Depreciation and amortization	43	45	130	134
Capital expenditures (including the effects of accruals)	26	30	83	104
Total assets	4,381	4,311	4,381	4,311
Operating Segments | UGI International
Segment Reporting Information [Line Items]
Revenues	572	371	2,106	1,726
Cost of sales	355	198	1,229	968
Operating income (loss)	40	17	322	230
(Loss) income from equity investees	0	0	0	0
Other non-operating income (expense), net	1	4	4	17
Earnings (loss) before interest expense and income taxes	41	21	326	247
Interest expense	(8)	(8)	(21)	(23)
Income (loss) before income taxes	33	13	305	224
Depreciation and amortization	33	30	100	92
Capital expenditures (including the effects of accruals)	21	20	68	62
Total assets	3,749	3,208	3,749	3,208
Operating Segments | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	261	222	1,086	1,017
Revenues, before intersegment effect	232	202	903	855
Cost of sales	196	158	776	721
Operating income (loss)	14	13	156	139
(Loss) income from equity investees	7	7	24	22
Other non-operating income (expense), net	0	0	0	0
Earnings (loss) before interest expense and income taxes	21	20	180	161
Interest expense	(10)	(11)	(31)	(34)
Income (loss) before income taxes	11	9	149	127
Depreciation and amortization	19	20	56	57
Capital expenditures (including the effects of accruals)	3	15	32	61
Total assets	2,904	2,740	2,904	2,740
Operating Segments | UGI Utilities
Segment Reporting Information [Line Items]
Revenues	181	179	923	901
Revenues, before intersegment effect	171	172	873	863
Cost of sales	67	68	401	404
Operating income (loss)	24	21	243	229
(Loss) income from equity investees	0	0	0	0
Other non-operating income (expense), net	1	0	2	0
Earnings (loss) before interest expense and income taxes	25	21	245	229
Interest expense	(14)	(14)	(42)	(41)
Income (loss) before income taxes	11	7	203	188
Depreciation and amortization	29	26	87	78
Capital expenditures (including the effects of accruals)	112	68	255	217
Total assets	3,997	3,709	3,997	3,709
Corporate & Other
Segment Reporting Information [Line Items]
Revenues, before intersegment effect	(5)	3	(5)	8
Cost of sales	(330)	(157)	(520)	(11)
Operating income (loss)	302	104	452	(75)
(Loss) income from equity investees	(93)	0	(93)	0
Other non-operating income (expense), net	(1)	(8)	(6)	(21)
Earnings (loss) before interest expense and income taxes	208	96	353	(96)
Interest expense	(5)	(6)	(19)	(25)
Income (loss) before income taxes	203	90	334	(121)
Depreciation and amortization	1	1	2	1
Capital expenditures (including the effects of accruals)	0	0	0	0
Total assets	242	240	242	240
Intersegment revenues Corporate & Other
Segment Reporting Information [Line Items]
Revenues	$ 1	$ 1	$ 3	$ 2

Segment Information - Reconcili

Segment Information - Reconciliation of Partnership Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions			$ 509	$ 1
Impairment of assets held-for-sale	$ 0	$ (52)	0	(52)
AmeriGas Propane | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
AmeriGas Propane | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	59	60	123	48
AmeriGas Propane | Other non-operating income (expense), net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
AmeriGas Propane | Operating and administrative expenses
Segment Reporting Information [Line Items]
Business transformation expenses	(11)	(3)	(37)	(27)
AmeriGas Propane | Operating and administrative expenses | CMG Acquisition
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition				0
AmeriGas Propane | Impairment of assets held-for-sale
Segment Reporting Information [Line Items]
Impairment of assets held-for-sale		0		0
AmeriGas Propane | (Loss) income from equity investees
Segment Reporting Information [Line Items]
Impairment of investment in PennEast	0		0
UGI International | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
UGI International | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	226	78	380	(54)
UGI International | Other non-operating income (expense), net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(1)	(7)	(6)	(20)
UGI International | Operating and administrative expenses
Segment Reporting Information [Line Items]
Business transformation expenses	(6)	(4)	(12)	(16)
UGI International | Operating and administrative expenses | CMG Acquisition
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition				0
UGI International | Impairment of assets held-for-sale
Segment Reporting Information [Line Items]
Impairment of assets held-for-sale		0		0
UGI International | (Loss) income from equity investees
Segment Reporting Information [Line Items]
Impairment of investment in PennEast	0		0
Midstream & Marketing | Revenues
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	(4)	3	(4)	8
Midstream & Marketing | Cost of sales
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	44	22	16	19
Midstream & Marketing | Other non-operating income (expense), net
Segment Reporting Information [Line Items]
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	0	0	0	0
Midstream & Marketing | Operating and administrative expenses
Segment Reporting Information [Line Items]
Business transformation expenses	0	0	0	0
Midstream & Marketing | Operating and administrative expenses | CMG Acquisition
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition				(2)
Midstream & Marketing | Impairment of assets held-for-sale
Segment Reporting Information [Line Items]
Impairment of assets held-for-sale		$ (52)		$ (52)
Midstream & Marketing | (Loss) income from equity investees
Segment Reporting Information [Line Items]
Impairment of investment in PennEast	$ 93		$ 93

Business Transformation Initi_2

Business Transformation Initiatives (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
AmeriGas and UGI International
Restructuring Cost and Reserve [Line Items]
Recognized expenses	$ 17	$ 6	$ 49	$ 43
Corporate Services
Restructuring Cost and Reserve [Line Items]
Recognized expenses	$ 4		$ 8

Equity Method Investments (Deta

Equity Method Investments (Details) $ in Millions	1 Months Ended
	Jun. 30, 2021USD ($)mi	Feb. 28, 2021USD ($)
PennEast
Schedule of Equity Method Investments [Line Items]
Other than temporary impairment charges	$ 93
Enbridge Inc | PennEast | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent	20.00%
UGI Penn East LLC | PennEast | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent	20.00%
Southern Company | PennEast | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent	20.00%
South Jersey Industries | PennEast | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent	20.00%
New Jersey Resources | PennEast | Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent	20.00%
Pine Run Midstream, LLC
Schedule of Equity Method Investments [Line Items]
Enterprise value		$ 205
Area of natural gas pipeline to be operated (in miles) | mi	43
Pine Run Midstream, LLC | Energy Services
Schedule of Equity Method Investments [Line Items]
Equity method investment ownership percent	49.00%
Equity method investments	$ 59