10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended December 31, 2020

OR

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from  ________ to ________            

Commission file number 1-11071

UGI CORPORATION

(Exact name of registrant as specified in its charter)

Pennsylvania	23-2668356
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

460 North Gulph Road, King of Prussia, PA 19406

(Address of Principal Executive Offices) (Zip Code)

(610) 337-1000

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class:	Trading Symbol(s):	Name of each exchange on which registered:
Common Stock, without par value	UGI	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  ý    No  ¨

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý    No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	ý	Accelerated filer	☐	Non-accelerated filer	☐
Smaller reporting company	☐	Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ☐    No  ý

At January 31, 2021, there were 208,553,861 shares of UGI Corporation Common Stock, without par value, outstanding.

UGI CORPORATION AND SUBSIDIARIES

TABLE OF CONTENTS

	Page
Glossary of Terms and Abbreviations	1
Part I Financial Information
Item 1. Financial Statements (unaudited)
Condensed Consolidated Balance Sheets as of December 31, 2020, September 30, 2020 and December 31, 2019	5
Condensed Consolidated Statements of Income for the three months ended December 31, 2020 and 2019	6
Condensed Consolidated Statements of Comprehensive Income for the three months ended December 31, 2020 and 2019	7
Condensed Consolidated Statements of Cash Flows for the three months ended December 31, 2020 and 2019	8
Condensed Consolidated Statements of Changes in Equity for the three months ended December 31, 2020 and 2019	9
Notes to Condensed Consolidated Financial Statements	10
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	31
Item 3. Quantitative and Qualitative Disclosures About Market Risk	44
Item 4. Controls and Procedures	46
Part II Other Information
Item 1A. Risk Factors	47
Item 6. Exhibits	47
Signatures	49

i

GLOSSARY OF TERMS AND ABBREVIATIONS

Terms and abbreviations used in this Form 10-Q are defined below:

UGI Corporation and Related Entities

AmeriGas OLP - AmeriGas Propane, L.P., the principal operating subsidiary of AmeriGas Partners

AmeriGas Partners - AmeriGas Partners, L.P., a Delaware limited partnership and an indirect wholly-owned subsidiary of UGI; also referred to as the “Partnership”

AmeriGas Propane - Reportable segment comprising AmeriGas Propane, Inc. and its subsidiaries, including AmeriGas Partners and AmeriGas OLP

AmeriGas Propane, Inc. - A wholly owned second-tier subsidiary of UGI and the general partner of AmeriGas Partners; also referred to as the “General Partner”

AvantiGas - AvantiGas Limited, an indirect wholly owned subsidiary of UGI International, LLC

Company - UGI and its consolidated subsidiaries collectively

DVEP - DVEP Investeringen B.V., an indirect wholly owned subsidiary of UGI International, LLC

Electric Utility - UGI Utilities’ regulated electric distribution utility

Energy Services - UGI Energy Services, LLC, a wholly owned second-tier subsidiary of UGI

ESFC - Energy Services Funding Corporation, a wholly owned subsidiary of Energy Services

Flaga - Flaga GmbH, an indirect wholly owned subsidiary of UGI International, LLC

Gas Utility - UGI Utilities’ regulated natural gas distribution business, comprising the natural gas utility businesses owned and operated by UGI Utilities

General Partner - AmeriGas Propane, Inc., the general partner of AmeriGas Partners

HVAC - UGI HVAC Enterprises, Inc., a wholly owned second-tier subsidiary of UGI, which was sold in September 2020

Midstream & Marketing - Reportable segment comprising Energy Services, UGID and, prior to its sale in September 2020, HVAC

Partnership - AmeriGas Partners and its consolidated subsidiaries, including AmeriGas OLP

Pennant - Pennant Midstream, LLC, a Delaware limited liability corporation

PennEast - PennEast Pipeline Company, LLC

UGI - UGI Corporation

UGI Appalachia - UGI Appalachia, LLC, a wholly owned subsidiary of Energy Services

UGI France - UGI France SAS (a Société par actions simplifiée), an indirect wholly owned subsidiary of UGI International, LLC

UGI International - Reportable segment principally comprising UGI’s foreign operations

UGI International, LLC - UGI International, LLC, a wholly owned second-tier subsidiary of UGI

UGI PennEast, LLC - A wholly owned subsidiary of Energy Services that holds a 20% membership interest in PennEast

UGI Utilities - UGI Utilities, Inc., a wholly owned subsidiary of UGI. Also a reportable segment of UGI comprising UGI Utilities, Inc. and its subsidiaries

1

UGID - UGI Development Company, a wholly owned subsidiary of Energy Services

UniverGas - UniverGas Italia S.r.l, an indirect wholly owned subsidiary of UGI International, LLC

Other Terms and Abbreviations

2019 three-month period - Three months ended December 31, 2019

2020 Annual Report - UGI Annual Report on Form 10-K for the fiscal year ended September 30, 2020

2020 three-month period - Three months ended December 31, 2020

AFUDC - Allowance for Funds Used During Construction

AOCI - Accumulated Other Comprehensive Income (Loss)

ASC - Accounting Standards Codification

ASC 606 - ASC 606, “Revenue from Contracts with Customers”

ASU - Accounting Standards Update

Bcf - Billions of cubic feet

BIE - Pennsylvania Public Utility Commission Bureau of Investigation and Enforcement

CARES Act - Coronavirus Aid, Relief, and Economic Security Act

CDC - Centers for Disease Control and Prevention

CMG Acquisition - Acquisition of Columbia Midstream Group, LLC and Columbia Pennant, LLC on August 1, 2019 pursuant to the CMG Acquisition Agreements

CMG Acquisition Agreements - Agreements related to the CMG Acquisition comprising (1) a purchase and sale agreement related to the CMG acquisition, dated July 2, 2019, by and among Columbia Midstream & Minerals Group, LLC, Energy Services, UGI and TransCanada PipeLine USA Ltd., and (2) a purchase and sale agreement related to the Columbia Pennant, LLC acquisition, dated July 2, 2019, by and among Columbia Midstream & Minerals Group, LLC, Energy Services, and TransCanada PipeLine USA Ltd.

COA - Consent Order and Agreement

CODM - Chief Operating Decision Maker as defined in ASC 280, “Segment Reporting”

Common Stock - shares of UGI common stock

COVID-19 - A novel strain of coronavirus disease discovered in 2019

DS - Default service

DSIC - Distribution System Improvement Charge

Eighth Circuit - United States Court of Appeals for the Eighth Circuit

Exchange Act - Securities Exchange Act of 1934, as amended

FASB - Financial Accounting Standards Board

FDIC - Federal Deposit Insurance Corporation

FERC - Federal Energy Regulatory Commission

Fiscal 2019 - The fiscal year ended September 30, 2019

2

Fiscal 2020 - The fiscal year ended September 30, 2020

Fiscal 2021 - The fiscal year ending September 30, 2021

Fiscal 2022 - The fiscal year ending September 30, 2022

GAAP - U.S. generally accepted accounting principles

GILTI - Global Intangible Low Taxed Income

Gwh - Millions of kilowatt hours

Hunlock - Hunlock Station, a 130-megawatt natural gas-fueled electricity generating station located near Wilkes-Barre, Pennsylvania

ICE - Intercontinental Exchange

IRC - Internal Revenue Code

IRPA - Interest rate protection agreement

IRS - Internal Revenue Services

IT - Information technology

LNG - Liquefied natural gas

LPG - Liquefied petroleum gas

MDPSC - Maryland Public Service Commission

MGP - Manufactured gas plant

Mountaineer - Mountaineer Gas Company a natural gas distribution company in West Virginia

Mountaineer Acquisition - Pending acquisition of Mountaintop Energy Holdings LLC, indirect parent of Mountaineer, pursuant to a definitive agreement signed on December 29, 2020

NOAA - National Oceanic and Atmospheric Administration

NOL - Net operating loss

NPNS - Normal purchase and normal sale

NYDEC - New York State Department of Environmental Conservation

NYMEX - New York Mercantile Exchange

PADEP - Pennsylvania Department of Environmental Protection

PAPUC - Pennsylvania Public Utility Commission

PGC - Purchased gas costs

PRP - Potentially Responsible Party

Receivables Facility - A receivables purchase facility of Energy Services with an issuer of receivables-backed commercial paper

Retail core-market - Comprises firm residential, commercial and industrial customers to whom UGI Utilities has a statutory obligation to provide service that purchase their natural gas from Gas Utility

ROD - Record of Decision

3

SCAA - Storage Contract Administrative Agreements

SEC - U.S. Securities and Exchange Commission

TCJA - Tax Cuts and Jobs Act

Temporary Rates Order - Order issued by the PAPUC on March 15, 2018, that converted PAPUC approved rates of a defined group of large Pennsylvania public utilities into temporary rates for a period of not more than 12 months while the PAPUC reviewed effects of the TCJA

USD - U.S. dollar

Western Missouri District Court - The United States District Court for the Western District of Missouri

WHO - World Health Organization

4

UGI CORPORATION AND SUBSIDIARIES

PART I FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

CONDENSED CONSOLIDATED BALANCE SHEETS

(unaudited)

(Millions of dollars)

	December 31, 2020		September 30, 2020		December 31, 2019
ASSETS
Current assets:
Cash and cash equivalents	$	416	$	336	$	333
Restricted cash	30		21		96
Accounts receivable (less allowances for doubtful accounts of $46, $42 and $36, respectively)	1,030		652		1,011
Accrued utility revenues	61		14		80
Income taxes receivable	85		80		—
Inventories	279		241		248
Derivative instruments	94		44		28
Prepaid expenses and other current assets	185		155		151
Total current assets	2,180		1,543		1,947
Property, plant and equipment, (less accumulated depreciation of $3,822, $3,698 and $3,490, respectively)	7,054		6,960		6,784
Goodwill	3,564		3,518		3,483
Intangible assets, net	667		677		703
Utility regulatory assets	392		395		386
Derivative instruments	37		38		32
Other assets	831		854		951
Total assets	$	14,725	$	13,985	$	14,286
LIABILITIES AND EQUITY
Current liabilities:
Current maturities of long-term debt	$	21	$	53	$	28
Short-term borrowings	568		347		870
Accounts payable	637		475		598
Derivative instruments	43		64		113
Other current liabilities	828		816		782
Total current liabilities	2,097		1,755		2,391
Long-term debt	6,012		5,981		5,828
Deferred income taxes	693		640		563
Derivative instruments	56		59		47
Other noncurrent liabilities	1,421		1,413		1,452
Total liabilities	10,279		9,848		10,281
Commitments and contingencies (Note 7)
Equity:
UGI Corporation stockholders’ equity:
UGI Common Stock, without par value (authorized — 450,000,000 shares; issued — 209,545,847, 209,514,044 and 209,310,342 shares, respectively)	1,419		1,416		1,398
Retained earnings	3,139		2,908		2,798
Accumulated other comprehensive loss	(79)		(147)		(163)
Treasury stock, at cost	(42)		(49)		(37)
Total UGI Corporation stockholders’ equity	4,437		4,128		3,996
Noncontrolling interests	9		9		9
Total equity	4,446		4,137		4,005
Total liabilities and equity	$	14,725	$	13,985	$	14,286

See accompanying notes to condensed consolidated financial statements.

5

UGI CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(unaudited)

(Millions of dollars, except per share amounts)

	Three Months Ended December 31,
	2020		2019
Revenues	$	1,932	$	2,007
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)	833		1,008
Operating and administrative expenses	489		511
Depreciation and amortization	124		119
Other operating income, net	(16)		(8)
	1,430		1,630
Operating income	502		377
Income from equity investees	7		7
Other non-operating expense, net	(19)		(12)
Interest expense	(78)		(84)
Income before income taxes	412		288
Income tax expense	(109)		(76)
Net income attributable to UGI Corporation	$	303	$	212
Earnings per common share attributable to UGI Corporation stockholders:
Basic	$	1.45	$	1.01
Diluted	$	1.44	$	1.00
Weighted-average common shares outstanding (thousands):
Basic	208,774		209,439
Diluted	209,640		211,258

See accompanying notes to condensed consolidated financial statements.

6

UGI CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(unaudited)

(Millions of dollars)

	Three Months Ended December 31,
	2020		2019
Net income attributable to UGI Corporation	$	303	$	212
Other comprehensive income:
Net gains on derivative instruments (net of tax of $0 and $(2), respectively)	—		6
Reclassifications of net losses on derivative instruments (net of tax of $(2) and $0, respectively)	5		1
Foreign currency adjustments (net of tax of $12 and $7, respectively)	63		47
Other comprehensive income	68		54
Comprehensive income attributable to UGI Corporation	$	371	$	266

See accompanying notes to condensed consolidated financial statements.

7

UGI CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited)

(Millions of dollars)

	Three Months Ended December 31,
	2020		2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income attributable to UGI Corporation	$	303	$	212
Adjustments to reconcile net income attributable to UGI Corporation to net cash provided by operating activities:
Depreciation and amortization	124		119
Deferred income tax expense, net	25		5
Provision for uncollectible accounts	8		8
Changes in unrealized gains and losses on derivative instruments	(96)		27
Income from equity investees	(7)		(7)
Other, net	12		(8)
Net change in:
Accounts receivable and accrued utility revenues	(415)		(432)
Inventories	(34)		(16)
Utility deferred fuel and power costs, net of changes in unsettled derivatives	4		5
Accounts payable	187		183
Derivative instruments collateral deposits received	13		20
Other current assets	(43)		(8)
Other current liabilities	70		10
Net cash provided by operating activities	151		118
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(187)		(182)
Acquisitions of businesses and assets, net of cash and restricted cash acquired	(12)		—
Other, net	10		6
Net cash used by investing activities	(189)		(176)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(69)		(68)
Issuances of long-term debt, net of issuance costs	—		15
Repayments of long-term debt and finance leases	(36)		(31)
Increase in short-term borrowings	165		51
Receivables Facility net borrowings	56		22
Issuances of UGI Common Stock	4		1
Repurchases of UGI Common Stock	—		(23)
Net cash provided (used) by financing activities	120		(33)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	7		9
Cash, cash equivalents and restricted cash increase (decrease)	$	89	$	(82)
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of period	$	446	$	429
Cash, cash equivalents and restricted cash at beginning of period	357		511
Cash, cash equivalents and restricted cash increase (decrease)	$	89	$	(82)

See accompanying notes to condensed consolidated financial statements.

8

UGI CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(unaudited)

(Millions of dollars, except per share amounts)

	Three Months Ended December 31,
	2020		2019
Common stock, without par value
Balance, beginning of period	$	1,416	$	1,397
Common Stock issued in connection with employee and director plans, net of tax withheld	1		—
Equity-based compensation expense	2		2
Other	—		(1)
Balance, end of period	$	1,419	$	1,398
Retained earnings
Balance, beginning of period	$	2,908	$	2,653
Losses on common stock transactions in connection with employee and director plans	(3)		—
Net income attributable to UGI Corporation	303		212
Cash dividends on UGI Common Stock ($0.33, and $0.325, respectively)	(69)		(68)
Other	—		1
Balance, end of period	$	3,139	$	2,798
Accumulated other comprehensive income (loss)
Balance, beginning of period	$	(147)	$	(217)
Net gains on derivative instruments	—		6
Reclassification of net losses on derivative instruments	5		1
Foreign currency adjustments	63		47
Balance, end of period	$	(79)	$	(163)
Treasury stock
Balance, beginning of period	$	(49)	$	(16)
Common Stock issued in connection with employee and director plans, net of tax withheld	7		2
Repurchases of UGI Common Stock	—		(23)
Balance, end of period	$	(42)	$	(37)
Total UGI stockholders’ equity	$	4,437	$	3,996
Noncontrolling interests
Balance, beginning of period	$	9	$	10
Other	—		(1)
Balance, end of period	$	9	$	9
Total equity	$	4,446	$	4,005

See accompanying notes to condensed consolidated financial statements.

9

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

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, 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 Mid-Atlantic region of the U.S., eastern Ohio and the panhandle of West Virginia. 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 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 Public Service Commission of West Virginia and federal antitrust clearance, and is expected to close in the second half of calendar year 2021. UGI currently expects to finance the pending acquisition through the issuance of debt and/or equity-linked securities and existing liquidity.

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.

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 and Pennant.

10

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

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. The Third Circuit subsequently denied PennEast’s petition for rehearing en banc. PennEast also filed a petition for declaratory order with the FERC regarding interpretation of the Natural Gas Act; the FERC issued an order favorable to PennEast’s position on January 30, 2020. PennEast filed a petition for a writ of certiorari to seek U.S. Supreme Court review of the Third Circuit decision on February 18, 2020.  On June 29, 2020, the U.S. Supreme Court invited the U.S. Solicitor General to file a brief in the case expressing the views of the U.S. On December 9, 2020, the U.S. Solicitor General filed a brief supporting PennEast’s petition for a writ of certiorari. On February 3, 2021, the U.S. Supreme Court issued an order granting PennEast’s petition for a writ of certiorari. The case will be set for argument in the April 2021 argument session. The ultimate outcome of these matters cannot be determined at this time, and could result in delays, additional costs, or the inability to move forward with the project, resulting in an impairment of all or a portion of our investment in PennEast.

Restricted Cash. Restricted cash principally represents those cash balances in our commodity futures brokerage accounts that are restricted from withdrawal. The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Condensed Consolidated Balance Sheets to the corresponding amounts reported on the Condensed Consolidated Statements of Cash Flows.

	December 31, 2020		December 31, 2019		September 30, 2020		September 30, 2019
Cash and cash equivalents	$	416	$	333	$	336	$	447
Restricted cash	30		96		21		64
Cash, cash equivalents and restricted cash	$	446	$	429	$	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 December 31,
	2020	2019
Denominator (thousands of shares):
Weighted-average common shares outstanding — basic	208,774	209,439
Incremental shares issuable for stock options and awards (a)	866	1,819
Weighted-average common shares outstanding — diluted	209,640	211,258

(a)For the three months ended December 31, 2020 and 2019, there were 6,000 and 3,499 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.

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

11

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

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 10.

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.

Note 3 — Accounting Changes

New Accounting Standard Adopted in Fiscal 2021

Credit Losses. In June 2016, the FASB issued ASU 2016-13, “Measurement of Credit Losses on Financial Instruments.” This ASU, as subsequently amended, requires entities to estimate lifetime expected credit losses for financial instruments not measured at fair value through net income, including trade and other receivables, net investments in leases, financial receivables, debt securities, and other financial instruments, 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. Effective October 1, 2020, the Company adopted this ASU, as updated, using a modified retrospective transition approach. The adoption of the new guidance did not have a material impact on our consolidated financial statements.

Accounting Standard Not Yet Adopted

Income Taxes. In December 2019, the FASB issued ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” This ASU simplifies the accounting for income taxes by eliminating certain exceptions within the existing guidance for recognizing deferred taxes for equity method investments, performing intraperiod allocations and calculating income taxes in interim periods. Further, this ASU clarifies existing guidance related to, among other things, recognizing deferred taxes for goodwill and allocated taxes to members of a consolidated group. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2021 (Fiscal 2022). Early adoption is permitted. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the period in which the new guidance will be adopted.

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.

12

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

Revenue Disaggregation

The following tables present our disaggregated revenues by reportable segment:

Three Months Ended December 31, 2020	Total		Eliminations (a)		AmeriGas Propane		UGI International		Midstream & Marketing		UGI Utilities		Corporate & Other
Revenues from contracts with customers:
Utility:
Core Market:
Residential	$	165	$	—	$	—	$	—	$	—	$	165	$	—
Commercial & Industrial	60		—		—		—		—		60		—
Large delivery service	40		—		—		—		—		40		—
Off-system sales and capacity releases	15		(14)		—		—		—		29		—
Other	4		(1)		—		—		—		5		—
Total Utility	284		(15)		—		—		—		299		—
Non-Utility:
LPG:
Retail	1,055		—		572		483		—		—		—
Wholesale	59		—		19		40		—		—		—
Energy Marketing	380		(26)		—		155		251		—		—
Midstream:
Pipeline	45		—		—		—		45		—		—
Peaking	2		(36)		—		—		38		—		—
Other	2		—		—		—		2		—		—
Electricity Generation	4		—		—		—		4		—		—
Other	72		—		56		16		—		—		—
Total Non-Utility	1,619		(62)		647		694		340		—		—
Total revenues from contracts with customers	1,903		(77)		647		694		340		299		—
Other revenues (b)	29		(1)		19		6		1		1		3
Total revenues	$	1,932	$	(78)	$	666	$	700	$	341	$	300	$	3

13

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

Three Months Ended December 31, 2019	Total		Eliminations (a)		AmeriGas Propane		UGI International		Midstream & Marketing		UGI Utilities		Corporate & Other
Revenues from contracts with customers:
Utility:
Core Market:
Residential	$	184	$	—	$	—	$	—	$	—	$	184	$	—
Commercial & Industrial	68		—		—		—		—		68		—
Large delivery service	41		—		—		—		—		41		—
Off-system sales and capacity releases	17		(14)		—		—		—		31		—
Other	4		(1)		—		—		—		5		—
Total Utility	314		(15)		—		—		—		329		—
Non-Utility:
LPG:
Retail	1,094		—		631		463		—		—		—
Wholesale	66		—		22		44		—		—		—
Energy Marketing	363		(26)		—		124		265		—		—
Midstream:
Pipeline	43		—		—		—		43		—		—
Peaking	4		(38)		—		—		42		—		—
Other	2		—		—		—		2		—		—
Electricity Generation	9		—		—		—		9		—		—
Other	80		—		59		12		9		—		—
Total Non-Utility	1,661		(64)		712		643		370		—		—
Total revenues from contracts with customers	1,975		(79)		712		643		370		329		—
Other revenues (b)	32		(1)		18		8		3		—		4
Total revenues	$	2,007	$	(80)	$	730	$	651	$	373	$	329	$	4

(a)Includes intersegment revenues principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane.

(b)Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP.

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 $108, $115 and $93 at December 31, 2020, September 30, 2020 and December 31, 2019, respectively, and are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets. Revenues recognized for the three months ended December 31, 2020 and 2019, from the amounts included in contract liabilities at September 30, 2020 and 2019, were $60 and $61, respectively.

14

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

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 December 31, 2020, Midstream & Marketing and UGI Utilities expect to record approximately $2.1 billion and $0.2 billion of revenues, respectively, related to the minimum future performance obligations over the remaining terms of the related contracts.

Note 5 — Inventories

Inventories comprise the following: 

	December 31, 2020		September 30, 2020		December 31, 2019
Non-utility LPG and natural gas	$	181	$	164	$	164
Gas Utility natural gas	19		20		24
Materials, supplies and other	79		57		60
Total inventories	$	279	$	241	$	248

At December 31, 2020, UGI Utilities was party to two principal SCAAs with terms of up to three years. Pursuant to the SCAAs, UGI Utilities has, among other things, released certain natural gas storage and transportation contracts for the terms of the SCAAs. UGI Utilities also transferred certain associated natural gas storage inventories upon commencement of the SCAAs, will receive a transfer of storage inventories at the end of the SCAAs, and makes payments associated with refilling storage inventories during the terms of the SCAAs. The historical cost of natural gas storage inventories released under the SCAAs, which represents a portion of Gas Utility’s total natural gas storage inventories, and any exchange receivable (representing amounts of natural gas inventories used by the other parties to the agreement but not yet replenished for which UGI Utilities has the rights), are included in the caption “Gas Utility natural gas” in the table above. For all periods presented, all of UGI Utilities’ SCAAs were with Energy Services, the effects of which are eliminated in consolidation.

15

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

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:

	December 31, 2020		September 30, 2020		December 31, 2019
Regulatory assets (a):
Income taxes recoverable	$	126	$	124	$	121
Underfunded pension and postretirement plans	172		175		175
Environmental costs	59		61		58
Removal costs, net	24		26		27
Other	14		11		10
Total regulatory assets	$	395	$	397	$	391
Regulatory liabilities (a):
Postretirement benefit overcollections	$	13	$	13	$	14
Deferred fuel and power refunds	24		29		6
State tax benefits — distribution system repairs	28		28		26
PAPUC Temporary Rates Order	5		7		25
Excess federal deferred income taxes	272		274		278
Other	4		2		2
Total regulatory liabilities	$	346	$	353	$	351

(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 collected from customers and recoverable costs incurred. Net undercollected costs are classified as a regulatory asset and net overcollections are classified as a regulatory liability.

Gas Utility uses derivative instruments to reduce volatility in the cost of gas it purchases for retail core-market customers. Realized and unrealized gains or losses on natural gas derivative instruments are included in deferred fuel and power costs or refunds. Net unrealized (losses) gains on such contracts at December 31, 2020, September 30, 2020 and December 31, 2019 were $(1), $8 and $(3), respectively.

Other Regulatory Matters

Base Rate Filings. On January 28, 2020, Gas Utility filed a request with the PAPUC to increase its annual base distribution operating revenues by $75 annually. On October 8, 2020, the PAPUC issued a final Order approving a 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 is authorized to implement a DSIC once Gas Utility total property, plant and equipment less accumulated depreciation reaches $2,875, with this threshold being unchanged from Gas Utility’s 2019 base rate case. The 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.

16

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

On January 28, 2019, Gas Utility filed a rate request with the PAPUC to increase the base operating revenues for residential, commercial, and industrial customers throughout its Pennsylvania service territory by an aggregate $71. On October 4, 2019, the PAPUC issued a final Order approving a settlement that permitted Gas Utility, effective October 11, 2019, to increase its base distribution revenues by $30 under a single consolidated tariff, approved a plan for uniform class rates, and permitted Gas Utility to extend its Energy Efficiency and Conservation and Growth Extension Tariff programs by an additional term of five years. The PAPUC’s final Order approved a negative surcharge, to return to customers $24 of tax benefits experienced by Gas Utility over the period January 1, 2018 to June 30, 2018, plus applicable interest, in accordance with the May 17, 2018 PAPUC Order, which became effective for a twelve-month period beginning on October 11, 2019, the effective date of Gas Utility’s new base rates.

Note 7 — 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 December 31, 2020, September 30, 2020 and December 31, 2019, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the current COA and the predecessor agreements totaled $49, $53 and $50, respectively.

We do not expect the costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to UGI Utilities’ results of operations because UGI Utilities receives ratemaking recovery of actual environmental investigation and remediation costs associated with the sites covered by the COA. This ratemaking recognition reconciles the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. As such, UGI Utilities has recorded an associated regulatory asset for these costs because recovery of these costs from customers is probable (see Note 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.

17

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

AmeriGas Propane

AmeriGas OLP Saranac Lake. In 2008, the NYDEC notified AmeriGas OLP that the NYDEC had placed property purportedly owned by AmeriGas OLP in Saranac Lake, New York on the New York State Registry of Inactive Hazardous Waste Disposal Sites. A site characterization study performed by the NYDEC disclosed contamination related to a former MGP. AmeriGas OLP responded to the NYDEC in 2009 to dispute the contention it was a PRP as it did not operate the MGP and appeared to only own a portion of the site. In 2017, the NYDEC communicated to AmeriGas OLP that the NYDEC had previously issued three RODs related to remediation of the site totaling approximately $28 and requested additional information regarding AmeriGas OLP’s purported ownership. AmeriGas OLP renewed its challenge to designation as a PRP and identified potential defenses. The NYDEC subsequently identified a third party PRP with respect to the site.

The NYDEC commenced implementation of the remediation plan in the spring of 2018. Based on our evaluation of the available information as of December 31, 2020, the Partnership has an undiscounted environmental remediation liability of $8 related to the site. Our share of the actual remediation costs could be significantly more or less than the accrued amount.

Other Matters

Purported Class Action Lawsuits. Between May and October of 2014, purported class action lawsuits were filed in multiple jurisdictions against the Partnership/UGI and a competitor by certain of their direct and indirect customers.  The class action lawsuits allege, among other things, that the Partnership and its competitor colluded, beginning in 2008, to reduce the fill level of portable propane cylinders from 17 pounds to 15 pounds and combined to persuade their common customer, Walmart Stores, Inc., to accept that fill reduction, resulting in increased cylinder costs to retailers and end-user customers in violation of federal and certain state antitrust laws.  The claims seek treble damages, injunctive relief, attorneys’ fees and costs on behalf of the putative classes. 

On October 16, 2014, the United States Judicial Panel on Multidistrict Litigation transferred all of these purported class action cases to the Western Missouri District Court.  As the result of rulings on a series of procedural filings, including petitions filed with the Eighth Circuit and the U.S. Supreme Court, both the federal and state law claims of the direct customer plaintiffs and the state law claims of the indirect customer plaintiffs were remanded to the Western Missouri District Court. The decision of the Western Missouri District Court to dismiss the federal antitrust claims of the indirect customer plaintiffs was upheld by the Eighth Circuit. On April 15, 2019, the Western Missouri District Court ruled that it has jurisdiction over the indirect purchasers’ state law claims and that the indirect customer plaintiffs have standing to pursue those claims. On August 21, 2019, the District Court partially granted the Company’s motion for judgment on the pleadings and dismissed the claims of indirect customer plaintiffs from ten states and the District of Columbia.

On October 2, 2019, the Partnership reached an agreement to resolve the claims of the direct purchaser class of plaintiffs; the agreement received final court approval on June 18, 2020. On September 18, 2020, the Partnership and counsel for the indirect purchaser plaintiffs filed a joint statement with the court that they had reached an agreement in principle to settle the claims of the remaining classes and plaintiffs, subject to court approval.

Although we cannot predict the final results of these pending claims and legal actions, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our financial statements.

In addition to the matters described above, there are other pending claims and legal actions arising in the normal course of our businesses. Although we cannot predict the final results of these pending claims and legal actions, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our financial statements.

Note 8 — 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 expense, net” on the Condensed

18

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

Consolidated Statements of Income. Other postretirement benefit cost was not material for all periods presented. Net periodic pension cost includes the following components:

Three Months Ended December 31,	2020		2019
Service cost	$	3	$	3
Interest cost	5		6
Expected return on assets	(10)		(10)
Amortization of:
Actuarial loss	4		4
Net cost	$	2	$	3

19

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

Note 9 — Fair Value Measurements

Recurring Fair Value Measurements

The following table presents, on a gross basis, our financial assets and liabilities, including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy:

	Asset (Liability)
	Level 1		Level 2		Level 3		Total
December 31, 2020:
Derivative instruments:
Assets:
Commodity contracts	$	60	$	111	$	—	$	171
Foreign currency contracts	$	—	$	14	$	—	$	14
Liabilities:
Commodity contracts	$	(58)	$	(14)	$	—	$	(72)
Foreign currency contracts	$	—	$	(25)	$	—	$	(25)
Interest rate contracts	$	—	$	(50)	$	—	$	(50)
Non-qualified supplemental postretirement grantor trust investments (a)	$	46	$	—	$	—	$	46
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
December 31, 2019:
Derivative instruments:
Assets:
Commodity contracts	$	26	$	20	$	—	$	46
Foreign currency contracts	$	—	$	40	$	—	$	40
Interest rate contracts	$	—	$	3	$	—	$	3
Liabilities:
Commodity contracts	$	(77)	$	(110)	$	—	$	(187)
Foreign currency contracts	$	—	$	(4)	$	—	$	(4)
Interest rate contracts	$	—	$	(7)	$	—	$	(7)
Non-qualified supplemental postretirement grantor trust investments (a)	$	42	$	—	$	—	$	42

(a)Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans.

The fair values of our Level 1 exchange-traded commodity futures and option contracts and non-exchange-traded commodity futures and forward contracts are based upon actively quoted market prices for identical assets and liabilities. The remainder of our derivative instruments are designated as Level 2. The fair values of certain non-exchange-traded commodity derivatives designated as Level 2 are based upon indicative price quotations available through brokers, industry price publications or recent market transactions and related market indicators. The fair values of our Level 2 interest rate contracts and foreign currency

20

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

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:

	December 31, 2020		September 30, 2020		December 31, 2019
Carrying amount	$	6,078	$	6,081	$	5,906
Estimated fair value	$	6,581	$	6,504	$	6,249

Financial instruments other than derivative instruments, such as short-term investments and trade accounts receivable, could expose us to concentrations of credit risk. We limit credit risk from short-term investments by investing only in investment-grade commercial paper, money market mutual funds, securities guaranteed by the U.S. Government or its agencies and FDIC insured bank deposits. The credit risk arising from concentrations of trade accounts receivable is limited because we have a large customer base that extends across many different U.S. markets and a number of foreign countries. For information regarding concentrations of credit risk associated with our derivative instruments, see Note 10.

Note 10 — 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.

21

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

Non-utility Operations

LPG

In order to manage market price risk associated with the Partnership’s fixed-price programs and to reduce the effects of short-term commodity price volatility, the Partnership uses over-the-counter derivative commodity instruments, principally price swap contracts. In addition, the Partnership and our UGI International operations also use over-the-counter price swap contracts to reduce commodity price volatility associated with a portion of their forecasted LPG purchases.

Natural Gas

In order to manage market price risk relating to fixed-price sales contracts for physical natural gas, Midstream & Marketing enters into NYMEX and over-the-counter natural gas futures and over-the-counter and ICE natural gas basis swap contracts. In addition, Midstream & Marketing uses NYMEX and over-the-counter futures and options contracts to economically hedge price volatility associated with the gross margin derived from the purchase and anticipated later near-term sale of natural gas storage inventories. Outside of the financial market, Midstream & Marketing also uses ICE and over-the-counter forward physical contracts. UGI International also uses natural gas futures and forward contracts to economically hedge market price risk associated with fixed-price sales contracts with its customers.

Electricity

In order to manage market price risk relating to fixed-price sales contracts for electricity, Midstream & Marketing enters into electricity futures and forward contracts. Midstream & Marketing also uses NYMEX and over-the-counter electricity futures contracts to economically hedge the price of a portion of its anticipated future sales of electricity from its electric generation facilities. UGI International also uses electricity futures and forward contracts to economically hedge market price risk associated with fixed-price sales and purchase contracts for electricity.

Interest Rate Risk

Certain of our long-term debt agreements have interest rates that are generally indexed to short-term market interest rates. In order to fix the underlying short-term market interest rates, we may enter into pay-fixed, receive-variable interest rate swap agreements and designate such swaps as cash flow hedges.

The remainder of our long-term debt is typically issued at fixed rates of interest. As this long-term debt matures, we typically refinance such debt with new debt having interest rates reflecting then-current market conditions. In order to reduce market rate risk on the underlying benchmark rate of interest associated with near- to medium-term forecasted issuances of fixed-rate debt, from time to time, we enter into IRPAs. We account for IRPAs as cash flow hedges. There were no unsettled IRPAs during any of the periods presented. At December 31, 2020, the amount of pre-tax net losses associated with interest rate hedges (excluding pay-fixed, receive-variable interest rate swaps) expected to be reclassified into earnings during the next twelve months is $4.

Foreign Currency Exchange Rate Risk

Forward Foreign Currency Exchange Contracts

In order to reduce the volatility in net income associated with our foreign operations, principally as a result of changes in the U.S. dollar exchange rate to the euro and British pound sterling, we enter into forward foreign currency exchange contracts. We layer in these foreign currency exchange contracts over a multi-year period to eventually equal approximately 90% of anticipated UGI International local currency earnings before income taxes. Because these contracts are not designated as hedging instruments, realized and unrealized gains and losses on these contracts are recorded in “Other non-operating expense, 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

22

UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

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 $32 and $20 during the three months ended December 31, 2020 and 2019, respectively.

Quantitative Disclosures Related to Derivative Instruments

The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at December 31, 2020, September 30, 2020 and December 31, 2019, and the final settlement dates of the Company's open derivative contracts as of December 31, 2020, excluding those derivatives that qualified for the NPNS exception:

			Notional Amounts (in millions)
Type	Units	Settlements Extending Through	December 31, 2020		September 30, 2020		December 31, 2019
Commodity Price Risk:
Regulated Utility Operations
Gas Utility NYMEX natural gas futures and option contracts	Dekatherms	October 2021	16		22		15
Non-utility Operations
LPG swaps	Gallons	September 2023	719		846		772
Natural gas futures, forward, basis swap, options and pipeline contracts	Dekatherms	May 2025	342		339		358
Electricity long forward and futures contracts	Kilowatt hours	December 2024	4,719		4,517		4,145
Electricity short forward and futures contracts	Kilowatt hours	December 2024	97		188		556
Interest Rate Risk:
Interest rate swaps	Euro	October 2022	€	300	€	300	€	300
Interest rate swaps	USD	July 2024	$	1,306	$	1,344	$	1,354
Foreign Currency Exchange Rate Risk:
Forward foreign currency exchange contracts	USD	September 2023	$	457	$	511	$	431
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

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Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

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 December 31, 2020. Certain of the Partnership’s derivative contracts have credit-risk-related contingent features that may require the posting of additional collateral in the event of a downgrade of the Partnership’s debt rating. At December 31, 2020, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material.

Offsetting Derivative Assets and Liabilities

Derivative assets and liabilities are presented net by counterparty on the 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.

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Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

Fair Value of Derivative Instruments

The following table presents the Company’s derivative assets and liabilities by type, as well as the effects of offsetting:

	December 31, 2020		September 30, 2020		December 31, 2019
Derivative assets:
Derivatives designated as hedging instruments:
Foreign currency contracts	$	8	$	17	$	14
Interest rate contracts	—		—		3
	8		17		17
Derivatives subject to PGC and DS mechanisms:
Commodity contracts	1		7		—
Derivatives not designated as hedging instruments:
Commodity contracts	170		100		46
Foreign currency contracts	6		15		26
	176		115		72
Total derivative assets — gross	185		139		89
Gross amounts offset in the balance sheet	(48)		(57)		(27)
Cash collateral received	(6)		—		(2)
Total derivative assets — net	$	131	$	82	$	60
Derivative liabilities:
Derivatives designated as hedging instruments:
Interest rate contracts	$	(50)	$	(55)	$	(7)
Derivatives subject to PGC and DS mechanisms:
Commodity contracts	(2)		—		(3)
Derivatives not designated as hedging instruments:
Commodity contracts	(70)		(118)		(184)
Foreign currency contracts	(25)		(14)		(4)
	(95)		(132)		(188)
Total derivative liabilities — gross	(147)		(187)		(198)
Gross amounts offset in the balance sheet	48		57		27
Cash collateral pledged	—		7		11
Total derivative liabilities — net	$	(99)	$	(123)	$	(160)

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Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

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 for the three months ended December 31, 2020 and 2019:

Three Months Ended December 31,:
	Gain (Loss) Recognized in AOCI				Loss Reclassified from AOCI into Income				Location of Loss Reclassified from AOCI into Income
Cash Flow Hedges:	2020		2019		2020		2019
Interest rate contracts	$	—	$	8	$	(7)	$	(1)	Interest expense
Net Investment Hedges:
Foreign currency contracts	$	(8)	$	(4)
	Gain (Loss) Recognized in Income
Derivatives Not Designated as Hedging Instruments:	2020		2019		Location of Gain (Loss) Recognized in Income
Commodity contracts	$	3	$	2	Revenues
Commodity contracts	103		(33)		Cost of sales
Commodity contracts	2		—		Operating and administrative expenses
Commodity contracts	5		—		Other operating income, net
Foreign currency contracts	(20)		(11)		Other non-operating expense, net
Total	$	93	$	(42)

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.

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UGI CORPORATION AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

Note 11 — Accumulated Other Comprehensive Income (Loss)

The tables below present changes in AOCI, net of tax:

Three Months Ended December 31, 2020	Postretirement Benefit Plans		Derivative Instruments		Foreign Currency		Total
AOCI — September 30, 2020	$	(26)	$	(54)	$	(67)	$	(147)
Other comprehensive income before reclassification adjustments	—		—		63		63
Amounts reclassified from AOCI	—		5		—		5
Other comprehensive income attributable to UGI	—		5		63		68
AOCI — December 31, 2020	$	(26)	$	(49)	$	(4)	$	(79)
Three Months Ended December 31, 2019	Postretirement Benefit Plans		Derivative Instruments		Foreign Currency		Total
AOCI — September 30, 2019	$	(26)	$	(25)	$	(166)	$	(217)
Other comprehensive income before reclassification adjustments	—		6		47		53
Amounts reclassified from AOCI	—		1		—		1
Other comprehensive income attributable to UGI	—		7		47		54
AOCI — December 31, 2019	$	(26)	$	(18)	$	(119)	$	(163)

Note 12 — 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.

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Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

Three Months Ended December 31, 2020	Total		Eliminations			AmeriGas Propane		UGI International		Midstream & Marketing			UGI Utilities		Corporate & Other (a)
Revenues from external customers	$	1,932	$	—		$	666	$	700	$	279		$	285	$	2
Intersegment revenues	$	—	$	(78)	(b)	$	—	$	—	$	62		$	15	$	1
Cost of sales	$	833	$	(77)	(b)	$	272	$	383	$	237		$	132	$	(114)
Operating income	$	502	$	—		$	141	$	135	$	52		$	77	$	97
Income from equity investees	7		—			—		—		7		(c)	—		—
Other non-operating (expense) income, net	(19)		—			—		1		—			1		(21)
Earnings before interest expense and income taxes	490		—			141		136		59			78		76
Interest expense	(78)		—			(40)		(7)		(10)			(14)		(7)
Income before income taxes	$	412	$	—		$	101	$	129	$	49		$	64	$	69
Depreciation and amortization	$	124	$	—		$	43	$	33	$	18		$	29	$	1
Capital expenditures (including the effects of accruals)	$	152	$	—		$	27	$	29	$	17		$	79	$	—
As of December 31, 2020
Total assets	$	14,725	$	(353)		$	4,471	$	3,564	$	2,851		$	3,959	$	233

Three Months Ended December 31, 2019	Total		Eliminations			AmeriGas Propane		UGI International		Midstream & Marketing			UGI Utilities		Corporate & Other (a)
Revenues from external customers	$	2,007	$	—		$	730	$	651	$	309		$	314	$	3
Intersegment revenues	$	—	$	(80)	(b)	$	—	$	—	$	64		$	15	$	1
Cost of sales	$	1,008	$	(79)	(b)	$	289	$	368	$	264		$	151	$	15
Operating income (loss)	$	377	$	—		$	165	$	96	$	55		$	92	$	(31)
Income from equity investees	7		—			—		—		7		(c)	—		—
Other non-operating (expense) income, net	(12)		—			—		4		—			—		(16)
Earnings (loss) before interest expense and income taxes	372		—			165		100		62			92		(47)
Interest expense	(84)		—			(42)		(7)		(12)			(14)		(9)
Income (loss) before income taxes	$	288	$	—		$	123	$	93	$	50		$	78	$	(56)
Depreciation and amortization	$	119	$	—		$	44	$	31	$	18		$	26	$	—
Capital expenditures (including the effects of accruals)	$	153	$	—		$	39	$	20	$	23		$	71	$	—
As of December 31, 2019
Total assets	$	14,286	$	(366)		$	4,609	$	3,243	$	2,860		$	3,711	$	229

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Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

(a)Corporate & Other includes specific items attributable to our reportable segments that are not included in the segment profit measures used by our CODM in assessing our reportable segments’ performance or allocating resources. The following table presents such pre-tax gains (losses) which have been included in Corporate & Other, and the reportable segments to which they relate:

Three Months Ended December 31, 2020	Location on Income Statement	AmeriGas Propane		UGI International		Midstream & Marketing
Net gains on commodity derivative instruments not associated with current-period transactions	Revenues	$	—	$	—	$	2
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	Cost of sales	$	37	$	106	$	(29)
Unrealized losses on foreign currency derivative instruments	Other non-operating expense, net	$	—	$	(20)	$	—
Business transformation expenses	Operating and administrative expenses	$	(12)	$	(3)	$	—

Three Months Ended December 31, 2019	Location on Income Statement	AmeriGas Propane		UGI International		Midstream & Marketing
Net gains on commodity derivative instruments not associated with current-period transactions	Revenues	$	—	$	—	$	2
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	Cost of sales	$	9	$	(14)	$	(9)
Unrealized losses on foreign currency derivative instruments	Other non-operating expense, net	$	—	$	(15)	$	—
Acquisition and integration expenses associated with the CMG Acquisition	Operating and administrative expenses	$	—	$	—	$	(1)
Business transformation expenses	Operating and administrative expenses	$	(11)	$	(6)	$	—

(b)Represents the elimination of intersegment transactions principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane.

(c)Includes AFUDC associated with PennEast and equity income from Pennant.

Note 13 — 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, during the three months ended December 31, 2020 and 2019, we recognized $15 and $17, respectively of expenses principally comprising consulting, advisory, marketing and employee-related costs. These expenses 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. Amounts reflected in “Operating and administrative expenses” on the Condensed Consolidated Statement of Income in connection with this initiative, during the three months ended December 31, 2020, were not material.

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Notes to Condensed Consolidated Financial Statements

(unaudited)

(Currency in millions, except per share amounts and where indicated otherwise)

Note 14 — Impact of Global Pandemic

In March 2020, the WHO declared a global pandemic attributable to the outbreak and continued spread of COVID-19 that has had a significant impact throughout the global economy. In connection with the mitigation and containment procedures recommended by the WHO, the CDC, and as imposed by federal, state, and local governmental authorities, including shelter-in-place orders, quarantines and similar restrictions, the Company implemented a variety of procedures to protect its employees, third-party business partners, and customers worldwide. The Company continues to provide essential products and services to its global customers in a safe and reliable manner, and will continue to do so in compliance with mandated restrictions presented by each of the markets it serves. The Company continues to evaluate and react to the potential effects of a prolonged disruption and the continued impact on its results of operations. These items may include, but are not limited to: the financial condition of its customers; decreased availability and demand for its products and services; realization of accounts receivable; impairment considerations related to certain current assets, long-lived assets and goodwill; delays related to current and future projects; and the effects of government stimulus efforts including tax legislation in response to COVID-19. While its operations and financial performance continue to be impacted by COVID-19, the Company cannot predict the duration or magnitude of the outbreak and the total effects on its business, financial position, results of operations, liquidity or cash flows at this time.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Forward-Looking Statements

Information contained in this Quarterly Report on Form 10-Q may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Exchange Act. Such statements use forward-looking words such as “believe,” “plan,” “anticipate,” “continue,” “estimate,” “expect,” “may,” or other similar words. These statements discuss plans, strategies, events or developments that we expect or anticipate will or may occur in the future.

A forward-looking statement may include a statement of the assumptions or bases underlying the forward-looking statement. We believe that we have chosen these assumptions or bases in good faith and that they are reasonable. However, we caution you that actual results almost always vary from assumed facts or bases, and the differences between actual results and assumed facts or bases can be material, depending on the circumstances. When considering forward-looking statements, you should keep in mind the following important factors that could affect our future results and could cause those results to differ materially from those expressed in our forward-looking statements: (1) weather conditions, including increasingly uncertain weather patterns due to climate change, resulting in reduced demand and the seasonal nature of our business; (2) cost volatility and availability of propane and other LPG, electricity, and natural gas, as well as the availability of LPG cylinders and the capacity to transport product to our customers; (3) changes in domestic and foreign laws and regulations, including safety, tax, consumer protection, data privacy, accounting matters, and environmental, including regulatory responses to climate change; (4) inability to timely recover costs through utility rate proceedings; (5) the impact of pending and future legal or regulatory proceedings, inquiries or investigations; (6) competitive pressures from the same and alternative energy sources; (7) failure to acquire new customers or retain current customers thereby reducing or limiting any increase in revenues; (8) liability for environmental claims; (9) increased customer conservation measures due to high energy prices and improvements in energy efficiency and technology resulting in reduced demand; (10) adverse labor relations; (11) customer, counterparty, supplier, or vendor defaults; (12) liability for uninsured claims and for claims in excess of insurance coverage, including those for personal injury and property damage arising from explosions, terrorism, natural disasters, pandemics and other catastrophic events that may result from operating hazards and risks incidental to generating and distributing electricity and transporting, storing and distributing natural gas in all forms; (13) transmission or distribution system service interruptions; (14) political, regulatory and economic conditions in the United States, Europe and other foreign countries, including the current conflicts in the Middle East and the withdrawal of the United Kingdom from the European Union, and foreign currency exchange rate fluctuations, particularly the euro; (15) capital market conditions, including reduced access to capital markets and interest rate fluctuations; (16) changes in commodity market prices resulting in significantly higher cash collateral requirements; (17) reduced distributions from subsidiaries impacting the ability to pay dividends; (18) changes in Marcellus and Utica Shale gas production; (19) the availability, timing and success of our acquisitions, commercial initiatives and investments to grow our businesses; (20) our ability to successfully integrate acquired businesses and achieve anticipated synergies; (21) the interruption, disruption, failure or malfunction of our information technology systems, including due to cyber attack; (22) the inability to complete pending or future energy infrastructure projects; (23) our ability to achieve the operational benefits and cost efficiencies expected from the completion of pending and future business transformation initiatives including the impact of customer service disruptions resulting in potential customer loss due to the transformation activities; (24) uncertainties related to a global pandemic, including the duration and/or impact of the COVID-19 pandemic; and (25) the extent to which we are able to utilize certain tax benefits currently available under the CARES Act and similar tax legislation and whether such benefits will remain available in the future.

These factors, and those factors set forth in Item 1A. Risk Factors in the Company’s 2020 Annual Report, are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other unknown or unpredictable factors could also have material adverse effects on future results. We undertake no obligation to update publicly any forward-looking statement whether as a result of new information or future events except as required by the federal securities laws.

ANALYSIS OF RESULTS OF OPERATIONS

The following analyses compare the Company’s results of operations for the 2020 three-month period with the 2019 three-month period. Our analyses of results of operations should be read in conjunction with the segment information included in Note 12 to Condensed Consolidated Financial Statements.

Because most of our businesses sell or distribute energy products used in large part for heating purposes, our results are significantly influenced by temperatures in our service territories, particularly during the heating-season months of October through March. As a result, our operating results, excluding the effects of gains and losses on commodity derivative

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instruments not associated with current-period transactions as further discussed below, are significantly higher in our first and second fiscal quarters.

Recent Developments

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 million, which includes the assumption of approximately $140 million of 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 Public Service Commission of West Virginia and federal antitrust clearance, and is expected to close in the second half of calendar year 2021. UGI currently expects to finance the pending acquisition through the issuance of debt and/or equity-linked securities and existing liquidity.

COVID-19 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, we implemented a variety of procedures to protect our employees, third-party business partners, and customers worldwide. Although our results continue to be impacted by COVID-19 in Fiscal 2021, we continue to provide essential products and services to our 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 we serve. We continue to evaluate and react to the potential effects of a prolonged disruption and the continued impact on our results of operations. These items may include, but are not limited to: the financial condition of our customers; decreased availability and demand for our products and services; realization of accounts receivable; impairment considerations related to certain current assets, long-lived assets and goodwill; delays related to current and future projects; and the effects of government stimulus efforts including tax legislation in response to COVID-19.

On March 27, 2020, the CARES Act was enacted in response to the COVID-19 pandemic. Among other things, the CARES Act includes provisions which modify the NOL limitation and carryback rules including a five-year carryback for NOLs and the temporary removal of the 80 percent limitation on NOL utilization for taxable years beginning before January 1, 2021.

For additional information related to the CARES Act and its impact on our results of operations, see “Interest Expense and Income Taxes” below.

We cannot predict the duration or total magnitude of the pandemic and the total effects on our business, financial position, results of operations, liquidity or cash flows at this time, but we remain focused on managing our financial condition and liquidity throughout this global crisis.

Business Transformation Initiatives

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. While this initiative is being coordinated across multiple support functions, each area is at a different stage of transformation and will undergo the required changes over the next two to three years. In connection with these activities, we expect to incur approximately $40 million of non-recurring costs during that time resulting in more than $15 million of ongoing annualized savings by Fiscal 2023.

AmeriGas Propane. At AmeriGas Propane, we began executing on business transformation initiatives during Fiscal 2019 focused on efficiency and effectiveness in the following key areas: customer digital experience; customer relationship management; operating process redesign and specialization; distribution and routing optimization; sales and marketing effectiveness; purchasing and general and administrative efficiencies; and supply and logistics. The transformation activities will continue to be carried out over Fiscal 2021 and may result in customer service disruptions over the near term. However, once completed, these initiatives are expected to provide total annual benefits of more than $140 million by the end of Fiscal 2022 which will allow us to improve profitability and cash flow through operational efficiencies and expense reductions and enable increased investment into base business customer retention and growth initiatives, including the reduction of margins in select segments of our base business. We estimate the total cost of executing on these initiatives, including approximately $100 million of related capital expenditures, to be approximately $200 million.

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UGI CORPORATION AND SUBSIDIARIES

UGI International. At our UGI International LPG business, we launched an initiative in Fiscal 2019 and embarked on a process of identifying operational synergies across all 17 countries in which we currently do business. We call this initiative Project Alliance, the goal of which is to focus attention on enhanced customer service and safe and efficient operations through the establishment of two centers of excellence. One such center will be focused on commercial excellence to identify and execute projects that improve the customer’s experience. The second center will be focused on operational excellence across our distribution network and our filling centers. The business activities are in process and will continue to be executed primarily during Fiscal 2021. Once completed, these activities are expected to generate over €30 million of annual benefits. We estimate the total cumulative cost of executing on these Project Alliance initiatives, including approximately €10 million related to IT capital expenditures, to be approximately €55 million.

Non-GAAP Financial Measures

UGI management uses “adjusted net income attributable to UGI Corporation” and “adjusted diluted earnings per share,” both of which are non-GAAP financial measures, when evaluating UGI’s overall performance. Management believes that these non-GAAP measures provide meaningful information to investors about UGI’s performance because they eliminate gains and losses on commodity and certain foreign currency derivative instruments not associated with current-period transactions and other significant discrete items that can affect the comparison of period-over-period results.

UGI does not designate its commodity and certain foreign currency derivative instruments as hedges under GAAP. Volatility in net income attributable to UGI Corporation as determined in accordance with GAAP can occur as a result of gains and losses on such derivative instruments not associated with current-period transactions. These gains and losses result principally from recording changes in unrealized gains and losses on unsettled commodity and certain foreign currency derivative instruments and, to a much lesser extent, certain realized gains and losses on settled commodity derivative instruments that are not associated with current-period transactions. However, because these derivative instruments economically hedge anticipated future purchases or sales of energy commodities, or in the case of certain foreign currency derivatives reduce volatility in anticipated future earnings associated with our foreign operations, we expect that such gains or losses will be largely offset by gains or losses on anticipated future energy commodity transactions or mitigate volatility in anticipated future earnings. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measures.

The following tables reflect the adjustments referred to above and reconcile net income attributable to UGI Corporation, the most directly comparable GAAP measure, to adjusted net income attributable to UGI Corporation, and reconcile diluted earnings per share, the most directly comparable GAAP measure, to adjusted diluted earnings per share:

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UGI CORPORATION AND SUBSIDIARIES

Adjusted net income attributable to UGI Corporation	Three Months Ended December 31,
(Dollars in millions)	2020		2019
AmeriGas Propane	$	74	$	91
UGI International	92		73
Midstream & Marketing	35		36
UGI Utilities	49		61
Corporate & Other (a)	53		(49)
Net income attributable to UGI Corporation	303		212
Net (gains) losses on commodity derivative instruments not associated with current-period transactions (net of tax of $31 and $(2), respectively)	(85)		10
Unrealized losses on foreign currency derivative instruments (net of tax of $(5) and $(4), respectively)	15		11
Acquisition and integration expenses associated with the CMG Acquisition (net of tax of $0 and $0, respectively)	—		1
Acquisition expenses associated with the pending Mountaineer Acquisition (net of tax of $(1) and $0, respectively)	1		—
Business transformation expenses (net of tax of $(4) and $(5), respectively)	13		12
Total adjustments (a) (b)	(56)		34
Adjusted net income attributable to UGI Corporation	$	247	$	246
	Three Months Ended December 31,
Adjusted diluted earnings per share	2020		2019
AmeriGas Propane	$	0.35	$	0.43
UGI International	0.44		0.34
Midstream & Marketing	0.17		0.17
UGI Utilities	0.23		0.29
Corporate & Other (a)	0.25		(0.23)
Earnings per share - diluted	1.44		1.00
Net (gains) losses on commodity derivative instruments not associated with current-period transactions	(0.40)		0.05
Unrealized losses on foreign currency derivative instruments	0.07		0.06
Acquisition and integration expenses associated with the CMG Acquisition	—		—
Acquisition expenses associated with the pending Mountaineer Acquisition	0.01		—
Business transformation expenses	0.06		0.06
Total adjustments (a)	(0.26)		0.17
Adjusted earnings per share - diluted	$	1.18	$	1.17

(a)Corporate & Other includes certain adjustments made to our reporting segments in arriving at net income attributable to UGI Corporation. These adjustments have been excluded from the segment results to align with the measure used by our CODM in assessing segment performance and allocating resources.  See Note 12 to Condensed Consolidated Financial Statements for additional information related to these adjustments, as well as other items included within Corporate & Other.

(b)Income taxes associated with pre-tax adjustments determined using statutory business unit tax rates.

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EXECUTIVE OVERVIEW

2020 three-month period compared with 2019 three-month period

Discussion. Net income attributable to UGI Corporation for the 2020 three-month period was $303 million (equal to $1.44 per diluted share) compared to net income attributable to UGI Corporation for the 2019 three-month period of $212 million (equal to $1.00 per diluted share). Net income in the 2020 three-month period reflects gains from changes in unrealized commodity derivative instruments and certain foreign currency derivative instruments compared to losses in the prior-year period. Net income also reflects business transformation expenses of $13 million and $12 million, respectively, for the three-months ended December 31, 2020 and 2019.

Adjusted net income attributable to UGI Corporation for the 2020 three-month period was $247 million (equal to $1.18 per diluted share) compared to adjusted net income attributable to UGI Corporation for the 2019 three-month period of $246 million (equal to $1.17 per diluted share). The slight increase in adjusted net income attributable to UGI Corporation during the 2020 three-month period reflects higher earnings attributable to our international business segment largely offset by lower earnings contributions from our AmeriGas Propane and UGI Utilities business segments.

Net income and adjusted net income in the 2020 three-month period both reflect an NOL benefit resulting from the CARES Act.

The decrease in adjusted net income attributable to UGI from AmeriGas Propane in the 2020 three-month period largely reflects lower total margin resulting from lower volumes and lower average unit margins, partially offset by lower operating and administrative expenses including partial benefits related to ongoing transformation initiatives.

UGI International adjusted net income increased $19 million in the 2020 three-month period principally reflecting higher total margin driven by colder weather compared to the prior-year period, higher average LPG unit margins, and the translation effects of the stronger euro in the 2020 three-month period. These positive factors were partially offset by slightly higher operating and administrative expenses compared to the prior-year period.

Midstream & Marketing adjusted net income in the 2020 three-month period was largely consistent with the prior-year period. The absence of earnings contributions from assets divested in the prior year were largely offset by improved capacity management earnings and lower operating and administrative expenses during the three-months ended December 31, 2020.

UGI Utilities 2020 three-month period adjusted net income decreased $12 million compared to the prior-year period. The decrease was principally attributable to lower total margin attributable to reduced volumes resulting from warmer weather and the impact of COVID-19, higher depreciation expenses and slightly higher operating and administrative expenses compared to the prior-year period.

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SEGMENT RESULTS OF OPERATIONS

2020 Three-Month Period Compared with the 2019 Three-Month Period

AmeriGas Propane

For the three months ended December 31,	2020			2019			Decrease
(Dollars in millions)
Revenues	$	666		$	730		$	(64)	(9)	%
Total margin (a)	$	394		$	441		$	(47)	(11)	%
Operating and administrative expenses	$	221		$	240		$	(19)	(8)	%
Operating income/earnings before interest expense and income taxes	$	141		$	165		$	(24)	(15)	%
Retail gallons sold (millions)	276			304			(28)		(9)	%
Heating degree days—% (warmer) colder than normal (b)	(4.6)		%	4.0		%	—		—

(a)Total margin represents total revenues less total cost of sales.

(b)Beginning in Fiscal 2021, deviation from average heating degree days is determined on a rolling 10-year period utilizing volume-weighted weather data based on weather statistics provided by NOAA for 323 regions in the United States, excluding Alaska and Hawaii. Prior-period amounts have been restated to conform to the current-period presentation.

Average temperatures during the 2020 three-month period were 4.6% warmer than normal and 8.2% warmer than the prior-year period. Total retail gallons sold during the 2020 three-month period were 9% lower than the prior-year period principally reflecting the effects of warmer weather on heating-related sales, structural conservation and other residual volume loss, and the continued impact of COVID-19 on commercial and motor fuel volumes. These decreases were partially offset by higher resale and cylinder exchange volumes compared to the prior-year period attributable to growth and pandemic-related usage increases.

Total revenues decreased $64 million during the 2020 three-month period largely reflecting lower retail and wholesale propane volumes ($63 million) and slightly lower average retail propane selling prices ($1 million) compared to the prior-year period. Average daily wholesale propane commodity prices during the 2020 three-month period at Mont Belvieu, Texas, one of the major supply points in the U.S., were approximately 15% higher than such prices during the 2019 three-month period. Total cost of sales decreased $17 million during the 2020 three-month period principally reflecting the lower retail propane volumes ($23 million) partially offset by higher average retail propane product costs ($6 million).

AmeriGas Propane total margin decreased $47 million in the 2020 three-month period largely attributable to the lower retail propane volumes ($36 million) and lower average retail unit margins ($7 million) compared to the prior-year period.

Operating income and earnings before interest expense and income taxes decreased $24 million during the 2020 three-month period principally reflecting the previously mentioned decrease in total margin partially offset by lower operating and administrative expenses ($19 million). The decrease in operating and administrative expenses in the 2020 three-month period reflects, among other things, lower employee compensation and benefits-related costs ($11 million), decreased vehicle and equipment operating and maintenance expenses ($6 million), and lower general insurance costs ($3 million). The lower operating and administrative expenses reflect the partial benefits related to the previously mentioned ongoing business transformation initiatives.

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UGI International

For the three months ended December 31,	2020			2019			Increase (Decrease)
(Dollars in millions)
Revenues	$	700		$	651		$	49	8	%
Total margin (a)	$	317		$	276		$	41	15	%
Operating and administrative expenses	$	157		$	151		$	6	4	%
Operating income	$	135		$	96		$	39	41	%
Earnings before interest expense and income taxes	$	136		$	100		$	36	36	%
LPG retail gallons sold (millions)	236			246			(10)		(4)	%
Heating degree days—% warmer than normal (b)	(2.0)		%	(6.6)		%	—		—

(a)Total margin represents revenues less cost of sales and, in the 2019 three-month period, LPG cylinder filling costs of $7 million. For financial statement purposes, LPG cylinder filling costs in the 2019 three-month period are included in “Operating and administrative expenses” on the 2019 Condensed Consolidated Statement of Income (but are excluded from operating and administrative expenses presented above). LPG cylinder filling costs are included in “Cost of sales” on the 2020 Condensed Consolidated Statement of Income.

(b)Beginning in Fiscal 2021, deviation from average heating degree days is determined on a rolling 10-year period utilizing volume-weighted weather data at locations in our UGI International service territories. Prior-period amounts have been restated to conform to the current-period presentation.

Average temperatures during the 2020 three-month period were 2.0% warmer than normal, but 4.9% colder than the prior-year period. Total LPG retail gallons sold during the 2020 three-month period were 4% lower reflecting the impact of the termination of a high-volume, low-margin autogas contract in Italy during the prior year partially offset by increased bulk volumes attributable to crop drying and heating-related bulk sales. COVID-19 also continued to negatively impact commercial and industrial volumes during the 2020 three-month period. Average wholesale prices for propane and butane in northwest Europe were approximately 8% and 13% lower, respectively, during the three-months ended December 31, 2020 compared with the prior-year period.

UGI International base-currency results are translated into U.S. dollars based upon exchange rates experienced during the reporting periods. Differences in these translation rates affect the comparison of line item amounts presented in the table above. The functional currency of a significant portion of our UGI International results is the euro and, to a much lesser extent, the British pound sterling. During the 2020 and 2019 three-month periods, the average unweighted euro-to-dollar translation rates were approximately $1.19 and $1.11, respectively, and the average unweighted British pound sterling-to-dollar translation rates were approximately $1.32 and $1.29, respectively.

UGI International revenues and cost of sales increased $49 million and $8 million, respectively, during the 2020 three-month period compared to the prior-year period. The increase in revenues principally reflects the translation effects of the stronger euro (approximately $44 million) and the previously mentioned bulk volume increases, partially offset by the low-margin volumes lost in connection with the autogas contract termination in Italy. The increase in cost of sales is largely attributable to the translation effects of the stronger euro (approximately $23 million) partially offset by the decrease in low-margin wholesale and autogas volumes.

UGI International total margin increased $41 million during the 2020 three-month period reflecting higher average LPG unit margins and the previously mentioned increase in crop drying and heating-related bulk volumes. The translation effects of the stronger euro (approximately $21 million) compared to the prior-year period and higher margins from energy marketing activities also contributed to the improvement in total margin. These positive impacts were partially offset by lower autogas and other low-margin volumes and the continued impact of COVID-19. The increase in average LPG unit margins includes the effects of margin management efforts, lower LPG product costs, and lower costs associated with energy conservation certificates including adjustments related to the current compliance period.

UGI International operating income and earnings before interest expense and income taxes increased $39 million and $36 million, respectively, during the 2020 three-month period compared to the prior-year period. The increase in operating income principally reflects the increase in total margin partially offset by slightly higher operating and administrative expenses ($6 million) compared to the prior-year period. The increase in operating and administrative expenses is largely attributable to the effects of the stronger euro (approximately $10 million) partially offset by lower expenses attributable to the effects of COVID-19. The increase in earnings before interest expense and income taxes in the 2020 three-month period largely reflects

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the higher operating income and lower pre-tax realized gains on foreign currency exchange contracts entered into in order to reduce volatility in UGI International net income resulting from the translation effects of changes in foreign currency exchange rates ($4 million).

Midstream & Marketing

For the three months ended December 31,	2020		2019		Decrease
(Dollars in millions)
Revenues	$	341	$	373	$	(32)	(9)	%
Total margin (a)	$	104	$	109	$	(5)	(5)	%
Operating and administrative expenses	$	32	$	35	$	(3)	(9)	%
Operating income	$	52	$	55	$	(3)	(5)	%
Earnings before interest expense and income taxes	$	59	$	62	$	(3)	(5)	%

(a)Total margin represents revenues less cost of sales.

Average temperatures across Midstream & Marketing’s energy marketing territory during the three months ended December 31, 2020 were 9.1% warmer than normal and 11.4% warmer than the prior-year period. Midstream & Marketing’s prior year results include contributions from its HVAC business and ownership interest in Conemaugh, both of which were sold in September 2020.

Midstream & Marketing revenues for the 2020 three-month period were $32 million lower than the prior-year period principally reflecting decreased natural gas revenues ($27 million) and, to a much lesser extent, lower peaking revenues ($7 million) and the absence of revenues attributable to its former HVAC business and ownership interest in Conemaugh ($16 million). The effect of these revenue decreases was partially offset by higher capacity management revenues ($8 million) and renewable energy revenues ($7 million). Midstream & Marketing cost of sales were $237 million in the 2020 three-month period compared to $264 million in the prior-year period. The $27 million decrease in cost of sales principally reflects decreased natural gas costs ($24 million) and the absence of costs attributable to HVAC and Conemaugh ($9 million), partially offset by higher renewable energy costs ($8 million). The significant decreases in both natural gas revenues and cost of sales during the 2020 three-month period are largely attributable to lower average natural gas prices and, to a much lesser extent, lower volumes compared to the prior-year period.

Midstream & Marketing total margin decreased $5 million in the 2020 three-month period reflecting the absence of margins attributable to HVAC and Conemaugh ($7 million) and lower peaking margin ($5 million) compared to the prior-year period. The effect of these decreases was partially offset by improved capacity management margin ($8 million) in the 2020 three-month period.

Midstream & Marketing operating income and earnings before interest expense and income taxes during the 2020 three-month period each decreased $3 million compared to the prior-year period. These decreases principally reflect the lower total margin partially offset by lower operating and administrative expenses ($3 million). The decrease in operating and administrative expenses was largely related to the absence of the previously mentioned divested assets partially offset by increases related to new assets placed into service and acquisitions.

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UGI Utilities

For the three months ended December 31,	2020			2019			Increase (Decrease)
(Dollars in millions)
Revenues	$	300		$	329		$	(29)	(9)	%
Total margin (a)	$	167		$	177		$	(10)	(6)	%
Operating and administrative expenses (a)	$	60		$	58		$	2	3	%
Operating income	$	77		$	92		$	(15)	(16)	%
Earnings before interest expense and income taxes	$	78		$	92		$	(14)	(15)	%
Gas Utility system throughput—bcf
Core market	23			26			(3)		(12)	%
Total	83			85			(2)		(2)	%
Electric Utility distribution sales - gwh	244			246			(2)		(1)	%
Gas Utility heating degree days—% (warmer) colder than normal (b)	(9.8)		%	0.3		%	—		—

(a)Total margin represents revenues less cost of sales and revenue-related taxes (i.e., Electric Utility gross receipts taxes) of $1 million and $1 million during the three months ended December 31, 2020 and 2019, respectively. For financial statement purposes, revenue-related taxes are included in “Operating and administrative expenses” on the Condensed Consolidated Statements of Income (but are excluded from operating and administrative expenses presented above).

(b)Beginning in Fiscal 2021, deviation from average heating degree days is determined on a rolling 10-year period utilizing volume-weighted weather data based on weather statistics provided by NOAA for airports located within Gas Utility’s service territory. Prior-period amounts have been restated to conform to the current-period presentation.

Temperatures in Gas Utility’s service territory during the three months ended December 31, 2020, were 9.8% warmer than normal and 10.1% warmer than the prior-year period. Gas Utility core market volumes decreased during the 2020 three-month period (3 bcf) reflecting the effects of the warmer weather and reduced commercial and industrial volumes attributable to COVID-19, partially offset by growth in the number of core market customers. Total Gas Utility distribution system throughput decreased (2 bcf) during the 2020 three-month period reflecting the lower core market volumes partially offset by higher large firm delivery service volumes. Electric Utility distribution sales volumes decreased slightly during the 2020 three-month period as a result of warmer weather compared to the prior-year period.

UGI Utilities revenues decreased $29 million in the 2020 three-month period reflecting a $30 million decrease in Gas Utility revenues partially offset by a slight increase in Electric Utility revenues. The decrease in Gas Utility revenues principally reflects lower core market revenues ($28 million) largely attributable to the decrease in core market volumes. The increase in Electric Utility revenues during the 2020 three-month period reflects higher DS rates which were largely offset by the decrease in sales volumes.

UGI Utilities cost of sales was $132 million in the 2020 three-month period compared with $151 million in the prior-year period reflecting lower Gas Utility cost of sales ($20 million) partially offset by higher Electric Utility cost of sales ($1 million). The lower Gas Utility cost of sales is largely attributable to the effect of decreased core market volumes ($11 million) and lower PGC rates ($9 million) compared to the prior-year period. The increase in Electric Utility cost of sales reflects higher average DS rates compared to the prior-year period.

UGI Utilities total margin decreased $10 million during the 2020 three-month period primarily reflecting lower margin from Gas Utility. This decrease in total Gas Utility margin principally reflects lower core market margin ($8 million) largely attributable to the previously mentioned lower core market volumes compared to the prior-year period.

UGI Utilities operating income and earnings before interest expense and income taxes decreased $15 million and $14 million, respectively, during the 2020 three-month period. These decreases reflect the previously mentioned decrease in total margin, higher depreciation expense ($3 million), and higher operating and administrative expenses ($2 million) compared to the prior-year period. The increase in depreciation expense relates to continued IT and distribution system capital expenditure activity. The increase in operating and administrative expenses reflect, among other things, higher employee compensation and benefits-related costs and higher allocation of corporate expenses. These increases were partially offset by lower contracted labor and professional services costs compared to the prior-year period.

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Interest Expense and Income Taxes

Our consolidated interest expense during the 2020 three-month period was $78 million, compared to $84 million during the 2019 three-month period. The decrease in interest expense principally reflects lower average short-term borrowing outstanding compared to the prior-year period.

The effective income tax rate for the 2020 three-month period was largely consistent with the prior-year period. Current year benefits related to the CARES Act and the impact of high-tax exception legislation described below were largely offset by the absence of a discrete benefit which impacted the prior-year period.

In July 2020, the U.S. Department of the Treasury and the IRS released regulations which modify the GILTI provisions of the IRC, as well as proposed regulations related to other IRC provisions. The Company continues to evaluate the elections available under these regulations, including the current period benefit mentioned above and any impact on anticipated benefits under the CARES Act. Accordingly, the impacts on the Company’s income tax provisions and taxes payable or refundable related to the CARES Act and the GILTI provisions are subject to change.

FINANCIAL CONDITION AND LIQUIDITY

The Company expects to have sufficient liquidity including cash on hand and available borrowing capacity to continue to support long-term commitments and ongoing operations despite uncertainties associated with the outbreak and continued spread of COVID-19. Our total available liquidity balance, comprising cash and cash equivalents and available borrowing capacity on our revolving credit facilities, totaled approximately $1.5 billion at both December 31, 2020 and September 30, 2020. The Company does not have any near-term senior note or term loan maturities. While the Company’s operations and financial performance has been impacted by COVID-19 in the 2020 three-month period, it is a rapidly evolving situation and the Company cannot predict the ultimate impact that COVID-19 will have on its liquidity, debt covenants, financial condition or the timing of capital expenditures. UGI and its subsidiaries were in compliance with all debt covenants as of December 31, 2020.

We depend on both internal and external sources of liquidity to provide funds for working capital and to fund capital requirements. Our short-term cash requirements not met by cash from operations are generally satisfied with borrowings under credit facilities and, in the case of Midstream & Marketing, also from a Receivables Facility. Long-term cash requirements are generally met through the issuance of long-term debt or equity securities. We believe that each of our business units has sufficient liquidity in the forms of cash and cash equivalents on hand; cash expected to be generated from operations; credit facility and Receivables Facility borrowing capacity; and the ability to obtain long-term financing to meet anticipated contractual and projected cash commitments. Issuances of debt and equity securities in the capital markets and additional credit facilities may not, however, be available to us on acceptable terms.

The primary sources of UGI’s cash and cash equivalents are the dividends and other cash payments made to UGI or its corporate subsidiaries by its principal business units. Our cash and cash equivalents totaled $416 million at December 31, 2020, compared with $336 million at September 30, 2020. Excluding cash and cash equivalents that reside at UGI’s operating subsidiaries, at December 31, 2020 and September 30, 2020, UGI had $245 million and $112 million of cash and cash equivalents, respectively. Such cash is available to pay dividends on UGI Common Stock and for investment purposes.

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Long-term Debt and Credit Facilities

Long-term Debt

The Company’s debt outstanding at December 31, 2020 and September 30, 2020, comprises the following:

	December 31, 2020												September 30, 2020
(Millions of dollars)	AmeriGas Propane		UGI International		Midstream & Marketing		UGI Utilities		Corp & Other		Total		Total
Short-term borrowings	$	222	$	1	$	79	$	266	$	—	$	568	$	347
Long-term debt (including current maturities):
Senior notes	$	2,575	$	428	$	—	$	975	$	—	$	3,978	$	3,960
Term loans	—		366		690		146		550		1,752		1,741
Other long-term debt	4		24		41		2		277		348		380
Unamortized debt issuance costs	(19)		(6)		(12)		(5)		(3)		(45)		(47)
Total long-term debt	$	2,560	$	812	$	719	$	1,118	$	824	$	6,033	$	6,034
Total debt	$	2,782	$	813	$	798	$	1,384	$	824	$	6,601	$	6,381

Credit Facilities

Additional information related to the Company’s credit agreements can be found in Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and Note 6 to Consolidated Financial Statements in the Company’s 2020 Annual Report.

Information about the Company’s principal credit agreements (excluding the Energy Services Receivables Facility discussed below) as of December 31, 2020 and 2019, is presented in the table below.

(Currency in millions)	Total Capacity		Borrowings Outstanding		Letters of Credit and Guarantees Outstanding		Available Borrowing Capacity
As of December 31, 2020
AmeriGas OLP	$	600	$	222	$	60	$	318
UGI International, LLC (a)	€	300	€	—	€	—	€	300
Energy Services	$	260	$	4	$	—	$	256
UGI Utilities	$	350	$	266	$	—	$	84
UGI Corporation (b)	$	300	$	270	$	—	$	30
As of December 31, 2019
AmeriGas OLP	$	600	$	321	$	63	$	216
UGI International, LLC (a)	€	300	€	161	€	—	€	139
Energy Services	$	200	$	20	$	—	$	180
UGI Utilities	$	350	$	279	$	—	$	71
UGI Corporation (b)	$	300	$	290	$	—	$	10

(a)Permits UGI International, LLC to borrow in euros or dollars. At December 31, 2019, the amount borrowed consisted of USD-denominated borrowings $180 million.

(b)Borrowings outstanding have been classified as “Long-term debt” on the Condensed Consolidated Balance Sheets.

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The average daily and peak short-term borrowings under the Company’s principal credit agreements during the three months ended December 31, 2020 and 2019 are as follows:

	For the three months ended				For the three months ended
	December 31, 2020				December 31, 2019
(Millions of dollars or euros)	Average		Peak		Average		Peak
AmeriGas OLP	$	224	$	266	$	322	$	359
UGI International, LLC	€	—	€	—	€	187	€	187
Energy Services	$	14	$	32	$	41	$	77
UGI Utilities	$	209	$	275	$	226	$	281
UGI Corporation	$	273	$	300	$	294	$	300

Receivables Facility. Energy Services has a Receivables Facility with an issuer of receivables-backed commercial paper currently scheduled to expire in October 22, 2021. At December 31, 2020, the outstanding balance of ESFC trade receivables was $83 million, of which $75 million was sold to the bank. At December 31, 2019, the outstanding balance of ESFC trade receivables was $86 million, of which $68 million was sold to the bank. Amounts sold to the bank are reflected as “Short-term borrowings” on the Condensed Consolidated Balance Sheets. During the three months ended December 31, 2020 and 2019, peak sales of receivables were $75 million and $68 million, respectively, and average daily amounts sold were $28 million and $50 million, respectively.

Dividends

On November 20, 2020, UGI’s Board of Directors declared a cash dividend equal to $0.33 per common share. The dividend was paid on January 1, 2021, to shareholders of record on December 15, 2020. On February 3, 2021, UGI’s Board of Director’s declared a quarterly dividend of $0.33 per common share. The dividend is payable April 1, 2021, to shareholders of record on March 15, 2021.

Cash Flows

Due to the seasonal nature of the Company’s businesses, cash flows from operating activities are generally strongest during the second and third fiscal quarters when customers pay for natural gas, LPG, electricity and other energy products and services consumed during the peak heating season months. Conversely, operating cash flows are generally at their lowest levels during the fourth and first fiscal quarters when the Company’s investment in working capital, principally inventories and accounts receivable, is generally greatest.

Operating Activities. Year-to-year variations in our cash flows from operating activities can be significantly affected by changes in operating working capital especially during periods with significant changes in energy commodity prices. Cash flow provided by operating activities was $151 million in the 2020 three-month period compared to $118 million in the 2019 three-month period. Cash flow from operating activities before changes in operating working capital was $369 million in the 2020 three-month period compared to $356 million in the prior-year period. Cash used to fund changes in operating working capital totaled $218 million in the 2020 three-month period compared to $238 million in the prior-year period. Changes in operating working capital during the 2020 three-month period reflects, among other things, an increase in cash generated from changes in other current liabilities and a decrease in cash required to fund changes in accounts receivable. These changes were partially offset by increases in cash required to fund changes in inventories and other current assets, as well as lower cash received for derivative instrument collateral deposits.

Investing Activities. Cash flow used by investing activities was $189 million in the 2020 three-month period compared to $176 million in the 2019 three-month period. Investing activity cash flow is principally affected by cash expenditures for property, plant and equipment; cash paid for acquisitions of businesses and assets; investments in investees; and proceeds from sales of assets and businesses. Cash expenditures for property, plant and equipment were $187 million in the 2020 three-month period compared with $182 million in the 2019 three-month period. Cash used for acquisitions of businesses and assets in the 2020 three-month period reflects UGI International’s acquisition of an LPG retail business in Europe.

Financing Activities. Cash flow provided by financing activities was $120 million in the 2020 three-month period compared with $33 million of cash used to fund financing activities in the prior-year period. Changes in cash flow from financing activities are primarily due to issuances and repayments of long-term debt; net short-term borrowings/repayments; dividends on UGI Common Stock; and issuances and repurchases of UGI Common Stock. The change in cash flows used by financing

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activities is primarily attributable to $221 million of net borrowings on revolving facility agreements and the Receivables Facility in the 2020 three-month period as compared to $73 million in the 2019 three-month period.

UTILITY REGULATORY MATTERS

Base Rate Filings. On January 28, 2020, Gas Utility filed a request with the PAPUC to increase its annual base distribution operating revenues by $75 million 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 million, through a phased approach, with $10 million beginning January 1, 2021 and an additional $10 million beginning July 1, 2021. Additionally, Gas Utility is authorized to implement a DSIC once Gas Utility total property, plant and equipment less accumulated depreciation reaches $2,875 million, with this threshold being unchanged from Gas Utility’s 2019 base rate case. 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.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our primary market risk exposures are (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 price risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes.

Commodity Price Risk

The risk associated with fluctuations in the prices the Partnership and our UGI International operations pay for LPG is principally a result of market forces reflecting changes in supply and demand for LPG and other energy commodities. Their profitability is sensitive to changes in LPG supply costs. Increases in supply costs are generally passed on to customers. The Partnership and UGI International may not, however, always be able to pass through product cost increases fully or on a timely basis, particularly when product costs rise rapidly. In order to reduce the volatility of LPG market price risk, the Partnership uses contracts for the forward purchase or sale of propane, propane fixed-price supply agreements and over-the-counter derivative commodity instruments including price swap contracts. Our UGI International operations use over-the-counter derivative commodity instruments and may from time to time enter into other derivative contracts, similar to those used by the Partnership, to reduce market risk associated with a portion of their LPG purchases. Over-the-counter derivative commodity instruments used to economically hedge forecasted purchases of LPG are generally settled at expiration of the contract.

Gas Utility's tariffs contain clauses that permit recovery of all prudently incurred costs of natural gas it sells to its retail core-market customers, including the cost of financial instruments used to hedge purchased gas costs. The recovery clauses provide for periodic adjustments for the difference between the total amounts actually collected from customers through PGC rates and the recoverable costs incurred. Because of this ratemaking mechanism, there is limited commodity price risk associated with our Gas Utility operations. Gas Utility uses derivative financial instruments, including natural gas futures and option contracts traded on the NYMEX, to reduce volatility in the cost of gas it purchases for its retail core-market customers. The cost of these derivative financial instruments, net of any associated gains or losses, is included in Gas Utility's PGC recovery mechanism.

In order to manage market price risk relating to substantially all of Midstream & Marketing’s fixed-price sale contracts for physical natural gas and electricity, Midstream & Marketing enters into NYMEX, ICE and over-the-counter natural gas and electricity futures and option contracts, and natural gas basis swap contracts or enters into fixed-price supply arrangements. Midstream & Marketing also uses NYMEX and over-the-counter electricity futures contracts to economically hedge a portion of its anticipated sales of electricity from its electricity generation facilities. Although Midstream & Marketing’s fixed-price supply arrangements mitigate most risks associated with its fixed-price sales contracts, should any of the suppliers under these arrangements fail to perform, increases, if any, in the cost of replacement natural gas or electricity would adversely impact Midstream & Marketing’s results. In order to reduce this risk of supplier nonperformance, Midstream & Marketing has diversified its purchases across a number of suppliers. UGI International’s natural gas and electricity marketing businesses also use natural gas and electricity futures and forward contracts to economically hedge market risk associated with fixed-price sales and purchase contracts.

Midstream & Marketing has entered into fixed-price sales agreements for a portion of the electricity expected to be generated by its electric generation assets. In the event that these generation assets would not be able to produce all of the electricity needed to supply electricity under these agreements, Midstream & Marketing would be required to purchase electricity on the spot market or under contract with other electricity suppliers. Accordingly, increases in the cost of replacement power could negatively impact Midstream & Marketing’s results.

Interest Rate Risk

We have both fixed-rate and variable-rate debt. Changes in interest rates impact the cash flows of variable-rate debt but generally do not impact their fair value. Conversely, changes in interest rates impact the fair value of fixed-rate debt but do not impact their cash flows.

Our variable-rate debt at December 31, 2020, includes revolving credit facility borrowings and variable-rate term loans at UGI International, UGI Utilities, Energy Services and UGI Corporation. These debt agreements have interest rates that are generally indexed to short-term market interest rates. We have entered into pay-fixed, receive-variable interest rate swap agreements on all or a significant portion of the term loans’ principal balances and all or a significant portion of the term loans’ tenor. We have designated these interest rate swaps as cash flow hedges. At December 31, 2020, combined borrowings outstanding under variable-rate debt agreements, excluding the previously mentioned effectively fixed-rate debt, totaled $878 million.

44

UGI CORPORATION AND SUBSIDIARIES

Long-term debt associated with our domestic businesses is typically issued at fixed rates of interest based upon market rates for debt with similar terms and credit ratings. As these long-term debt issues mature, we may refinance such debt with new debt having interest rates reflecting then-current market conditions. In order to reduce interest rate risk associated with near- to medium-term forecasted issuances of fixed rate debt, from time to time we enter into IRPAs.

Foreign Currency Exchange Rate Risk

Our primary currency exchange rate risk is associated with the U.S. dollar versus the euro and, to a lesser extent, the U.S. dollar versus the British pound sterling. The U.S. dollar value of our foreign currency denominated assets and liabilities will fluctuate with changes in the associated foreign currency exchange rates. From time to time, we use derivative instruments to hedge portions of our net investments in foreign subsidiaries. Gains or losses on these net investment hedges remain in AOCI until such foreign operations are sold or liquidated. With respect to our net investments in our UGI International operations, a 10% decline in the value of the associated foreign currencies versus the U.S. dollar would reduce their aggregate net book value at December 31, 2020, by approximately $120 million, which amount would be reflected in other comprehensive income. We have designated certain euro-denominated borrowings as net investment hedges.

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 between the euro and British pound sterling, we enter into forward foreign currency exchange contracts. We layer in these foreign currency exchange contracts over a multi-year period to eventually equal approximately 90% of anticipated UGI International local currency earnings before income taxes.

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 derivative instrument 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. At December 31, 2020, we had received cash collateral from derivative instrument counterparties totaling $6 million. Additionally, our commodity exchange-traded futures contracts generally require cash deposits in margin accounts. At December 31, 2020, restricted cash in brokerage accounts totaled $30 million. Although we have concentrations of credit risk associated with derivative instruments, the maximum amount of loss, based upon the gross fair values of the derivative instruments, we would incur if these counterparties failed to perform according to the terms of their contracts was not material at December 31, 2020. Certain of the Partnership’s derivative contracts have credit-risk-related contingent features that may require the posting of additional collateral in the event of a downgrade of the Partnership’s debt rating. At December 31, 2020, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material.

The following table summarizes the fair values of unsettled market risk sensitive derivative instrument assets (liabilities) held at December 31, 2020 and changes in their fair values due to market risks. Certain of UGI Utilities’ commodity derivative instruments are excluded from the table below because any associated net gains or losses are refundable to or recoverable from customers in accordance with UGI Utilities ratemaking.

	Asset (Liability)
(Millions of dollars)	Fair Value		Change in Fair Value
December 31, 2020
Commodity price risk (1)	$	100	$	(123)
Interest rate risk (2)	$	(50)	$	(7)
Foreign currency exchange rate risk (3)	$	(11)	$	(48)

(1) Change in fair value represents a 10% adverse change in the market prices of certain commodities

(2) Change in fair value represents a 50 basis point adverse change in prevailing market interest rates

(3) Change in fair value represents a 10% adverse change in the value of the Euro and the British pound sterling versus the U.S. dollar.

45

UGI CORPORATION AND SUBSIDIARIES

ITEM 4. CONTROLS AND PROCEDURES

(a)Evaluation of Disclosure Controls and Procedures

The Company's disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by the Company in reports filed or submitted under the Securities Exchange Act of 1934, as amended, is (i) recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms, and (ii) accumulated and communicated to our management, including the Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure. The Company's management, with the participation of the Company’s Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of the Company's disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Company's disclosure controls and procedures, as of the end of the period covered by this Report, were effective at the reasonable assurance level.

(b)Change in Internal Control over Financial Reporting

No change in the Company’s internal control over financial reporting occurred during the Company’s most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

46

UGI CORPORATION AND SUBSIDIARIES

PART II OTHER INFORMATION

ITEM 1A. RISK FACTORS

In addition to the information presented in this report, you should carefully consider the factors discussed in Part I, “Item 1A. Risk Factors” in our 2020 Annual Report, which could materially affect our business, financial condition or future results. The risks described in our 2020 Annual Report are not the only risks facing the Company. Other unknown or unpredictable factors could also have material adverse effects on future results.

ITEM 6. EXHIBITS

The exhibits filed as part of this report are as follows (exhibits incorporated by reference are set forth with the name of the registrant, the type of report and last date of the period for which it was filed, and the exhibit number in such filing):

Incorporation by Reference

Exhibit No.	Exhibit	Registrant	Filing	Exhibit
31.1	Certification by the Chief Executive Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended December 31, 2020, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification by the Chief Financial Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended December 31, 2020, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32	Certification by the Chief Executive Officer and the Chief Financial Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended December 31, 2020, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	XBRL Instance - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Linkbase
101.LAB	XBRL Taxonomy Extension Labels Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

47

UGI CORPORATION AND SUBSIDIARIES

EXHIBIT INDEX

31.1	Certification by the Chief Executive Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended December 31, 2020, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification by the Chief Certification by the Chief Financial Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended December 31, 2020, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32	Certification by the Chief Executive Officer and the Chief Financial Officer relating to the Registrant’s Report on Form 10-Q for the quarter ended December 31, 2020, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	XBRL Instance - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Linkbase
101.LAB	XBRL Taxonomy Extension Labels Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

48

UGI CORPORATION AND SUBSIDIARIES

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

		UGI Corporation
		(Registrant)
Date:	February 4, 2021	By:	/s/ Ted J. Jastrzebski
			Ted J. Jastrzebski
			Chief Financial Officer
Date:	February 4, 2021	By:	/s/ Laurie A. Bergman
			Laurie A. Bergman
			Vice President, Chief Accounting Officer
			and Corporate Controller

49

EX-31.1

EXHIBIT 31.1

CERTIFICATION

I, John L. Walsh, certify that:

1.I have reviewed this periodic report on Form 10-Q of UGI Corporation;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	February 4, 2021
		/s/ John L. Walsh
		John L. Walsh President and Chief Executive Officer of UGI Corporation

EX-31.2

EXHIBIT 31.2

CERTIFICATION

I, Ted J. Jastrzebski, certify that:

1.I have reviewed this periodic report on Form 10-Q of UGI Corporation;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	February 4, 2021
		/s/ Ted J. Jastrzebski
		Ted J. Jastrzebski
		Chief Financial Officer of UGI Corporation

EX-32

EXHIBIT 32

Certification by the Chief Executive Officer and Chief Financial Officer

Relating to a Periodic Report Containing Financial Statements

I, John L. Walsh, Chief Executive Officer, and I, Ted J. Jastrzebski, Chief Financial Officer, of UGI Corporation, a Pennsylvania corporation (the “Company”), hereby certify that to our knowledge:

(1)The Company’s periodic report on Form 10-Q for the period ended December 31, 2020 (the “Form 10-Q”) fully complies with the requirements of Section 13(a) of the Securities Exchange Act of 1934, as amended; and

(2)The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.

CHIEF EXECUTIVE OFFICER		CHIEF FINANCIAL OFFICER
/s/ John L. Walsh		/s/ Ted J. Jastrzebski
John L. Walsh		Ted J. Jastrzebski
Date:	February 4, 2021	Date:	February 4, 2021

XML

Cover Page - shares	3 Months Ended
	Dec. 31, 2020	Jan. 31, 2021
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Dec. 31, 2020
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
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	UGI
Security Exchange Name	NYSE
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		208,553,861
Entity Central Index Key	0000884614
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--09-30

XML

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 416.0	$ 336.0	$ 333.0
Restricted cash	30.0	21.0	96.0
Accounts receivable (less allowances for doubtful accounts of $46, $42 and $36, respectively)	1,030.0	652.0	1,011.0
Accrued utility revenues	61.0	14.0	80.0
Income taxes receivable	85.0	80.0	0.0
Inventories	279.0	241.0	248.0
Derivative instruments	94.0	44.0	28.0
Prepaid expenses and other current assets	185.0	155.0	151.0
Total current assets	2,180.0	1,543.0	1,947.0
Property, plant and equipment, (less accumulated depreciation of $3,822, $3,698 and $3,490, respectively)	7,054.0	6,960.0	6,784.0
Goodwill	3,564.0	3,518.0	3,483.0
Intangible assets, net	667.0	677.0	703.0
Utility regulatory assets	392.0	395.0	386.0
Derivative instruments	37.0	38.0	32.0
Other assets	831.0	854.0	951.0
Total assets	14,725.0	13,985.0	14,286.0
Current liabilities:
Current maturities of long-term debt	21.0	53.0	28.0
Short-term borrowings	568.0	347.0	870.0
Accounts payable	637.0	475.0	598.0
Derivative instruments	43.0	64.0	113.0
Other current liabilities	828.0	816.0	782.0
Total current liabilities	2,097.0	1,755.0	2,391.0
Long-term debt	6,012.0	5,981.0	5,828.0
Deferred income taxes	693.0	640.0	563.0
Derivative instruments	56.0	59.0	47.0
Other noncurrent liabilities	1,421.0	1,413.0	1,452.0
Total liabilities	10,279.0	9,848.0	10,281.0
Commitments and contingencies (Note 7)
UGI Corporation stockholders’ equity:
UGI Common Stock, without par value (authorized — 450,000,000 shares; issued — 209,545,847, 209,514,044 and 209,310,342 shares, respectively)	1,419.0	1,416.0	1,398.0
Retained earnings	3,139.0	2,908.0	2,798.0
Accumulated other comprehensive loss	(79.0)	(147.0)	(163.0)
Treasury stock, at cost	(42.0)	(49.0)	(37.0)
Total UGI Corporation stockholders’ equity	4,437.0	4,128.0	3,996.0
Noncontrolling interests	9.0	9.0	9.0
Total equity	4,446.0	4,137.0	4,005.0
Total liabilities and equity	$ 14,725.0	$ 13,985.0	$ 14,286.0

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 46	$ 42	$ 36
Accumulated depreciation	$ 3,822	$ 3,698	$ 3,490
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	209,545,847	209,514,044	209,310,342

XML

CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Income Statement [Abstract]
Revenues	$ 1,932.0	$ 2,007.0
Costs and expenses:
Cost of sales (excluding depreciation and amortization shown below)	833.0	1,008.0
Operating and administrative expenses	489.0	511.0
Depreciation and amortization	124.0	119.0
Other operating income, net	(16.0)	(8.0)
Costs and expenses	1,430.0	1,630.0
Operating income	502.0	377.0
Income from equity investees	7.0	7.0
Other non-operating expense, net	(19.0)	(12.0)
Interest expense	(78.0)	(84.0)
Income before income taxes	412.0	288.0
Income tax expense	(109.0)	(76.0)
Net income attributable to UGI Corporation	$ 303.0	$ 212.0
Earnings per common share attributable to UGI Corporation stockholders:
Basic (in USD per share)	$ 1.45	$ 1.01
Diluted (in USD per share)	$ 1.44	$ 1.00
Weighted-average common shares outstanding (thousands):
Basic (in shares)	208,774	209,439
Diluted (in shares)	209,640	211,258

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Net income attributable to UGI Corporation	$ 303	$ 212
Other comprehensive income:
Net gains on derivative instruments (net of tax of $0 and $(2), respectively)	0	6
Reclassifications of net losses on derivative instruments (net of tax of $(2) and $0, respectively)	5	1
Foreign currency adjustments (net of tax of $12 and $7, respectively)	63	47
Other comprehensive income	68	54
Comprehensive income attributable to UGI Corporation	$ 371	$ 266

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Net (losses) gains on derivative instruments , tax	$ 0	$ (2)
Tax on reclassification on derivative instruments	(2)	0
Foreign currency adjustments, tax	12	7
Net income attributable to UGI Corporation	$ 303	$ 212

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income attributable to UGI Corporation	$ 303.0	$ 212.0
Adjustments to reconcile net income attributable to UGI Corporation to net cash provided by operating activities:
Depreciation and amortization	124.0	119.0
Deferred income tax expense, net	25.0	5.0
Provision for uncollectible accounts	8.0	8.0
Changes in unrealized gains and losses on derivative instruments	(96.0)	27.0
Income from equity investees	(7.0)	(7.0)
Other, net	12.0	(8.0)
Net change in:
Accounts receivable and accrued utility revenues	(415.0)	(432.0)
Inventories	(34.0)	(16.0)
Utility deferred fuel and power costs, net of changes in unsettled derivatives	4.0	5.0
Accounts payable	187.0	183.0
Derivative instruments collateral deposits received	13.0	20.0
Other current assets	(43.0)	(8.0)
Other current liabilities	70.0	10.0
Net cash provided by operating activities	151.0	118.0
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(187.0)	(182.0)
Acquisitions of businesses and assets, net of cash and restricted cash acquired	(12.0)	0.0
Other, net	10.0	6.0
Net cash used by investing activities	(189.0)	(176.0)
CASH FLOWS FROM FINANCING ACTIVITIES
Dividends on UGI Common Stock	(69.0)	(68.0)
Issuances of long-term debt, net of issuance costs	0.0	15.0
Repayments of long-term debt and finance leases	(36.0)	(31.0)
Increase in short-term borrowings	165.0	51.0
Receivables Facility net borrowings	56.0	22.0
Issuances of UGI Common Stock	4.0	1.0
Repurchases of UGI Common Stock	0.0	(23.0)
Net cash provided (used) by financing activities	120.0	(33.0)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	7.0	9.0
Cash, cash equivalents and restricted cash increase (decrease)	89.0	(82.0)
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Cash, cash equivalents and restricted cash at end of period	446.0	429.0
Cash, cash equivalents and restricted cash at beginning of period	357.0	511.0
Cash, cash equivalents and restricted cash increase (decrease)	$ 89.0	$ (82.0)

XML

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Total UGI stockholders’ equity	Common stock, without par value	Retained earnings	Accumulated other comprehensive income (loss)	Treasury stock	Noncontrolling interests
Balance, beginning of period at Sep. 30, 2019			$ 1,397	$ 2,653	$ (217)	$ (16)	$ 10
Increase (Decrease) in Stockholders' Equity
Equity-based compensation expense			2
Net income attributable to UGI Corporation	$ 212			212
Cash dividends on UGI Common Stock ($0.33, and $0.325, respectively)				(68)
Net gains on derivative instruments	6				6
Reclassification of net losses on derivative instruments	1				1
Foreign currency adjustments	47				47
Common Stock issued in connection with employee and director plans, net of tax withheld						2
Repurchases of UGI Common Stock						(23)
Other			(1)	1			(1)
Balance, end of period at Dec. 31, 2019	4,005	$ 3,996	1,398	2,798	(163)	(37)	9
Balance, beginning of period at Sep. 30, 2020	4,137		1,416	2,908	(147)	(49)	9
Increase (Decrease) in Stockholders' Equity
Common Stock issued in connection with employee and director plans, net of tax withheld			1
Equity-based compensation expense			2
Losses on common stock transactions in connection with employee and director plans				(3)
Net income attributable to UGI Corporation	303			303
Cash dividends on UGI Common Stock ($0.33, and $0.325, respectively)				(69)
Net gains on derivative instruments	0
Reclassification of net losses on derivative instruments	5				5
Foreign currency adjustments	63				63
Common Stock issued in connection with employee and director plans, net of tax withheld						7
Balance, end of period at Dec. 31, 2020	$ 4,446	$ 4,437	$ 1,419	$ 3,139	$ (79)	$ (42)	$ 9

XML

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Statement of Stockholders' Equity [Abstract]
Common stock, dividends, per share, cash paid (in dollars per share)	$ 0.33	$ 0.325

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Nature of Operations

3 Months Ended

Dec. 31, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Nature of Operations

Note 1 — Nature of Operations

UGI is a holding company that, through subsidiaries and affiliates, distributes, stores, transports and markets energy products and related services. In the United States, we own and operate (1) a retail propane marketing and distribution business; (2) natural gas and electric distribution utilities; and (3) an energy marketing, midstream infrastructure, storage, natural gas gathering and processing, natural gas production, electricity generation and energy services businesses. In Europe, we market and distribute propane and other LPG and market other energy products and services.

We conduct a domestic propane marketing and distribution business through AmeriGas Partners. AmeriGas Partners conducts a national propane distribution business through its principal operating subsidiary, AmeriGas OLP.

UGI International, through subsidiaries and affiliates, conducts (1) an LPG distribution business throughout much of Europe and (2) an energy marketing business in France, Belgium, the Netherlands and the United Kingdom. These businesses are conducted principally through our subsidiaries, UGI France, Flaga, AvantiGas, DVEP and UniverGas.

Energy Services conducts, directly and through subsidiaries, energy marketing, 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 Mid-Atlantic region of the U.S., eastern Ohio and the panhandle of West Virginia. 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 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 Public Service Commission of West Virginia and federal antitrust clearance, and is expected to close in the second half of calendar year 2021. UGI currently expects to finance the pending acquisition through the issuance of debt and/or equity-linked securities and existing liquidity.

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Summary of Significant Accounting Policies

3 Months Ended

Dec. 31, 2020

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.

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 and Pennant.

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. The Third Circuit subsequently denied PennEast’s petition for rehearing en banc. PennEast also filed a petition for declaratory order with the FERC regarding interpretation of the Natural Gas Act; the FERC issued an order favorable to PennEast’s position on January 30, 2020. PennEast filed a petition for a writ of certiorari to seek U.S. Supreme Court review of the Third Circuit decision on February 18, 2020.  On June 29, 2020, the U.S. Supreme Court invited the U.S. Solicitor General to file a brief in the case expressing the views of the U.S. On December 9, 2020, the U.S. Solicitor General filed a brief supporting PennEast’s petition for a writ of certiorari. On February 3, 2021, the U.S. Supreme Court issued an order granting PennEast’s petition for a writ of certiorari. The case will be set for argument in the April 2021 argument session. The ultimate outcome of these matters cannot be determined at this time, and could result in delays, additional costs, or the inability to move forward with the project, resulting in an impairment of all or a portion of our investment in PennEast.

Restricted Cash. Restricted cash principally represents those cash balances in our commodity futures brokerage accounts that are restricted from withdrawal. The following table provides a reconciliation of the total cash, cash equivalents and restricted cash reported on the Condensed Consolidated Balance Sheets to the corresponding amounts reported on the Condensed Consolidated Statements of Cash Flows.

	December 31, 2020		December 31, 2019		September 30, 2020		September 30, 2019
Cash and cash equivalents	$	416	$	333	$	336	$	447
Restricted cash	30		96		21		64
Cash, cash equivalents and restricted cash	$	446	$	429	$	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 December 31,
	2020	2019
Denominator (thousands of shares):
Weighted-average common shares outstanding — basic	208,774	209,439
Incremental shares issuable for stock options and awards (a)	866	1,819
Weighted-average common shares outstanding — diluted	209,640	211,258

(a)For the three months ended December 31, 2020 and 2019, there were 6,000 and 3,499 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.

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 10.

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.

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Accounting Changes

3 Months Ended

Dec. 31, 2020

Accounting Changes and Error Corrections [Abstract]

Accounting Changes

Note 3 — Accounting Changes

New Accounting Standard Adopted in Fiscal 2021

Credit Losses. In June 2016, the FASB issued ASU 2016-13, “Measurement of Credit Losses on Financial Instruments.” This ASU, as subsequently amended, requires entities to estimate lifetime expected credit losses for financial instruments not measured at fair value through net income, including trade and other receivables, net investments in leases, financial receivables, debt securities, and other financial instruments, 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. Effective October 1, 2020, the Company adopted this ASU, as updated, using a modified retrospective transition approach. The adoption of the new guidance did not have a material impact on our consolidated financial statements.

Accounting Standard Not Yet Adopted

Income Taxes. In December 2019, the FASB issued ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” This ASU simplifies the accounting for income taxes by eliminating certain exceptions within the existing guidance for recognizing deferred taxes for equity method investments, performing intraperiod allocations and calculating income taxes in interim periods. Further, this ASU clarifies existing guidance related to, among other things, recognizing deferred taxes for goodwill and allocated taxes to members of a consolidated group. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2021 (Fiscal 2022). Early adoption is permitted. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the period in which the new guidance will be adopted.

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Revenue from Contracts with Customers

3 Months Ended

Dec. 31, 2020

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 December 31, 2020	Total		Eliminations (a)		AmeriGas Propane		UGI International		Midstream & Marketing		UGI Utilities		Corporate & Other
Revenues from contracts with customers:
Utility:
Core Market:
Residential	$	165	$	—	$	—	$	—	$	—	$	165	$	—
Commercial & Industrial	60		—		—		—		—		60		—
Large delivery service	40		—		—		—		—		40		—
Off-system sales and capacity releases	15		(14)		—		—		—		29		—
Other	4		(1)		—		—		—		5		—
Total Utility	284		(15)		—		—		—		299		—
Non-Utility:
LPG:
Retail	1,055		—		572		483		—		—		—
Wholesale	59		—		19		40		—		—		—
Energy Marketing	380		(26)		—		155		251		—		—
Midstream:
Pipeline	45		—		—		—		45		—		—
Peaking	2		(36)		—		—		38		—		—
Other	2		—		—		—		2		—		—
Electricity Generation	4		—		—		—		4		—		—
Other	72		—		56		16		—		—		—
Total Non-Utility	1,619		(62)		647		694		340		—		—
Total revenues from contracts with customers	1,903		(77)		647		694		340		299		—
Other revenues (b)	29		(1)		19		6		1		1		3
Total revenues	$	1,932	$	(78)	$	666	$	700	$	341	$	300	$	3

Three Months Ended December 31, 2019	Total		Eliminations (a)		AmeriGas Propane		UGI International		Midstream & Marketing		UGI Utilities		Corporate & Other
Revenues from contracts with customers:
Utility:
Core Market:
Residential	$	184	$	—	$	—	$	—	$	—	$	184	$	—
Commercial & Industrial	68		—		—		—		—		68		—
Large delivery service	41		—		—		—		—		41		—
Off-system sales and capacity releases	17		(14)		—		—		—		31		—
Other	4		(1)		—		—		—		5		—
Total Utility	314		(15)		—		—		—		329		—
Non-Utility:
LPG:
Retail	1,094		—		631		463		—		—		—
Wholesale	66		—		22		44		—		—		—
Energy Marketing	363		(26)		—		124		265		—		—
Midstream:
Pipeline	43		—		—		—		43		—		—
Peaking	4		(38)		—		—		42		—		—
Other	2		—		—		—		2		—		—
Electricity Generation	9		—		—		—		9		—		—
Other	80		—		59		12		9		—		—
Total Non-Utility	1,661		(64)		712		643		370		—		—
Total revenues from contracts with customers	1,975		(79)		712		643		370		329		—
Other revenues (b)	32		(1)		18		8		3		—		4
Total revenues	$	2,007	$	(80)	$	730	$	651	$	373	$	329	$	4

(a)Includes intersegment revenues principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane.

(b)Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP.

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 $108, $115 and $93 at December 31, 2020, September 30, 2020 and December 31, 2019, respectively, and are included in “Other current liabilities” and “Other noncurrent liabilities” on the Condensed Consolidated Balance Sheets. Revenues recognized for the three months ended December 31, 2020 and 2019, from the amounts included in contract liabilities at September 30, 2020 and 2019, were $60 and $61, 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 December 31, 2020, Midstream & Marketing and UGI Utilities expect to record approximately $2.1 billion and $0.2 billion of revenues, respectively, related to the minimum future performance obligations over the remaining terms of the related contracts.

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Inventories

3 Months Ended

Dec. 31, 2020

Inventory Disclosure [Abstract]

Inventories

Note 5 — Inventories

Inventories comprise the following: 

	December 31, 2020		September 30, 2020		December 31, 2019
Non-utility LPG and natural gas	$	181	$	164	$	164
Gas Utility natural gas	19		20		24
Materials, supplies and other	79		57		60
Total inventories	$	279	$	241	$	248

At December 31, 2020, UGI Utilities was party to two principal SCAAs with terms of up to three years. Pursuant to the SCAAs, UGI Utilities has, among other things, released certain natural gas storage and transportation contracts for the terms of the SCAAs. UGI Utilities also transferred certain associated natural gas storage inventories upon commencement of the SCAAs, will receive a transfer of storage inventories at the end of the SCAAs, and makes payments associated with refilling storage inventories during the terms of the SCAAs. The historical cost of natural gas storage inventories released under the SCAAs, which represents a portion of Gas Utility’s total natural gas storage inventories, and any exchange receivable (representing amounts of natural gas inventories used by the other parties to the agreement but not yet replenished for which UGI Utilities has the rights), are included in the caption “Gas Utility natural gas” in the table above. For all periods presented, all of UGI Utilities’ SCAAs were with Energy Services, the effects of which are eliminated in consolidation.

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Utility Regulatory Assets and Liabilities and Regulatory Matters

3 Months Ended

Dec. 31, 2020

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:

	December 31, 2020		September 30, 2020		December 31, 2019
Regulatory assets (a):
Income taxes recoverable	$	126	$	124	$	121
Underfunded pension and postretirement plans	172		175		175
Environmental costs	59		61		58
Removal costs, net	24		26		27
Other	14		11		10
Total regulatory assets	$	395	$	397	$	391
Regulatory liabilities (a):
Postretirement benefit overcollections	$	13	$	13	$	14
Deferred fuel and power refunds	24		29		6
State tax benefits — distribution system repairs	28		28		26
PAPUC Temporary Rates Order	5		7		25
Excess federal deferred income taxes	272		274		278
Other	4		2		2
Total regulatory liabilities	$	346	$	353	$	351

(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 collected from customers and recoverable costs incurred. Net undercollected costs are classified as a regulatory asset and net overcollections are classified as a regulatory liability.

Gas Utility uses derivative instruments to reduce volatility in the cost of gas it purchases for retail core-market customers. Realized and unrealized gains or losses on natural gas derivative instruments are included in deferred fuel and power costs or refunds. Net unrealized (losses) gains on such contracts at December 31, 2020, September 30, 2020 and December 31, 2019 were $(1), $8 and $(3), respectively.

Other Regulatory Matters

Base Rate Filings. On January 28, 2020, Gas Utility filed a request with the PAPUC to increase its annual base distribution operating revenues by $75 annually. On October 8, 2020, the PAPUC issued a final Order approving a 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 is authorized to implement a DSIC once Gas Utility total property, plant and equipment less accumulated depreciation reaches $2,875, with this threshold being unchanged from Gas Utility’s 2019 base rate case. The 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.

On January 28, 2019, Gas Utility filed a rate request with the PAPUC to increase the base operating revenues for residential, commercial, and industrial customers throughout its Pennsylvania service territory by an aggregate $71. On October 4, 2019, the PAPUC issued a final Order approving a settlement that permitted Gas Utility, effective October 11, 2019, to increase its base distribution revenues by $30 under a single consolidated tariff, approved a plan for uniform class rates, and permitted Gas Utility to extend its Energy Efficiency and Conservation and Growth Extension Tariff programs by an additional term of five years. The PAPUC’s final Order approved a negative surcharge, to return to customers $24 of tax benefits experienced by Gas Utility over the period January 1, 2018 to June 30, 2018, plus applicable interest, in accordance with the May 17, 2018 PAPUC Order, which became effective for a twelve-month period beginning on October 11, 2019, the effective date of Gas Utility’s new base rates.

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Commitments and Contingencies

3 Months Ended

Dec. 31, 2020

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Note 7 — 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 December 31, 2020, September 30, 2020 and December 31, 2019, our aggregate estimated accrued liabilities for environmental investigation and remediation costs related to the current COA and the predecessor agreements totaled $49, $53 and $50, respectively.

We do not expect the costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to UGI Utilities’ results of operations because UGI Utilities receives ratemaking recovery of actual environmental investigation and remediation costs associated with the sites covered by the COA. This ratemaking recognition reconciles the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites. As such, UGI Utilities has recorded an associated regulatory asset for these costs because recovery of these costs from customers is probable (see Note 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 December 31, 2020, the Partnership has an undiscounted environmental remediation liability of $8 related to the site. Our share of the actual remediation costs could be significantly more or less than the accrued amount.

Other Matters

Purported Class Action Lawsuits. Between May and October of 2014, purported class action lawsuits were filed in multiple jurisdictions against the Partnership/UGI and a competitor by certain of their direct and indirect customers.  The class action lawsuits allege, among other things, that the Partnership and its competitor colluded, beginning in 2008, to reduce the fill level of portable propane cylinders from 17 pounds to 15 pounds and combined to persuade their common customer, Walmart Stores, Inc., to accept that fill reduction, resulting in increased cylinder costs to retailers and end-user customers in violation of federal and certain state antitrust laws.  The claims seek treble damages, injunctive relief, attorneys’ fees and costs on behalf of the putative classes. 

On October 16, 2014, the United States Judicial Panel on Multidistrict Litigation transferred all of these purported class action cases to the Western Missouri District Court.  As the result of rulings on a series of procedural filings, including petitions filed with the Eighth Circuit and the U.S. Supreme Court, both the federal and state law claims of the direct customer plaintiffs and the state law claims of the indirect customer plaintiffs were remanded to the Western Missouri District Court. The decision of the Western Missouri District Court to dismiss the federal antitrust claims of the indirect customer plaintiffs was upheld by the Eighth Circuit. On April 15, 2019, the Western Missouri District Court ruled that it has jurisdiction over the indirect purchasers’ state law claims and that the indirect customer plaintiffs have standing to pursue those claims. On August 21, 2019, the District Court partially granted the Company’s motion for judgment on the pleadings and dismissed the claims of indirect customer plaintiffs from ten states and the District of Columbia.

On October 2, 2019, the Partnership reached an agreement to resolve the claims of the direct purchaser class of plaintiffs; the agreement received final court approval on June 18, 2020. On September 18, 2020, the Partnership and counsel for the indirect purchaser plaintiffs filed a joint statement with the court that they had reached an agreement in principle to settle the claims of the remaining classes and plaintiffs, subject to court approval.

Although we cannot predict the final results of these pending claims and legal actions, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our financial statements.

In addition to the matters described above, there are other pending claims and legal actions arising in the normal course of our businesses. Although we cannot predict the final results of these pending claims and legal actions, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our financial statements.

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Defined Benefit Pension and Other Postretirement Plans

3 Months Ended

Dec. 31, 2020

Retirement Benefits [Abstract]

Defined Benefit Pension and Other Postretirement Plans

Note 8 — 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 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:

Three Months Ended December 31,	2020		2019
Service cost	$	3	$	3
Interest cost	5		6
Expected return on assets	(10)		(10)
Amortization of:
Actuarial loss	4		4
Net cost	$	2	$	3

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Fair Value Measurements

3 Months Ended

Dec. 31, 2020

Fair Value Disclosures [Abstract]

Fair Value Measurements

Note 9 — Fair Value Measurements

Recurring Fair Value Measurements

The following table presents, on a gross basis, our financial assets and liabilities, including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy:

	Asset (Liability)
	Level 1		Level 2		Level 3		Total
December 31, 2020:
Derivative instruments:
Assets:
Commodity contracts	$	60	$	111	$	—	$	171
Foreign currency contracts	$	—	$	14	$	—	$	14
Liabilities:
Commodity contracts	$	(58)	$	(14)	$	—	$	(72)
Foreign currency contracts	$	—	$	(25)	$	—	$	(25)
Interest rate contracts	$	—	$	(50)	$	—	$	(50)
Non-qualified supplemental postretirement grantor trust investments (a)	$	46	$	—	$	—	$	46
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
December 31, 2019:
Derivative instruments:
Assets:
Commodity contracts	$	26	$	20	$	—	$	46
Foreign currency contracts	$	—	$	40	$	—	$	40
Interest rate contracts	$	—	$	3	$	—	$	3
Liabilities:
Commodity contracts	$	(77)	$	(110)	$	—	$	(187)
Foreign currency contracts	$	—	$	(4)	$	—	$	(4)
Interest rate contracts	$	—	$	(7)	$	—	$	(7)
Non-qualified supplemental postretirement grantor trust investments (a)	$	42	$	—	$	—	$	42

(a)Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans.

The fair values of our Level 1 exchange-traded commodity futures and option contracts and non-exchange-traded commodity futures and forward contracts are based upon actively quoted market prices for identical assets and liabilities. The remainder of our derivative instruments are designated as Level 2. The fair values of certain non-exchange-traded commodity derivatives designated as Level 2 are based upon indicative price quotations available through brokers, industry price publications or recent market transactions and related market indicators. The fair values of our Level 2 interest rate contracts and foreign currency

contracts are based upon third-party quotes or indicative values based on recent market transactions. The fair values of investments held in grantor trusts are derived from quoted market prices as substantially all of the investments in these trusts have active markets.

Other Financial Instruments

The carrying amounts of other financial instruments included in current assets and current liabilities (except for current maturities of long-term debt) approximate their fair values because of their short-term nature. We estimate the fair value of long-term debt by using current market rates and by discounting future cash flows using rates available for similar type debt (Level 2). The carrying amounts and estimated fair values of our long-term debt (including current maturities but excluding unamortized debt issuance costs) were as follows:

	December 31, 2020		September 30, 2020		December 31, 2019
Carrying amount	$	6,078	$	6,081	$	5,906
Estimated fair value	$	6,581	$	6,504	$	6,249

Financial instruments other than derivative instruments, such as short-term investments and trade accounts receivable, could expose us to concentrations of credit risk. We limit credit risk from short-term investments by investing only in investment-grade commercial paper, money market mutual funds, securities guaranteed by the U.S. Government or its agencies and FDIC insured bank deposits. The credit risk arising from concentrations of trade accounts receivable is limited because we have a large customer base that extends across many different U.S. markets and a number of foreign countries. For information regarding concentrations of credit risk associated with our derivative instruments, see Note 10.

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Derivative Instruments and Hedging Activities

3 Months Ended

Dec. 31, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

Note 10 — 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.

The remainder of our long-term debt is typically issued at fixed rates of interest. As this long-term debt matures, we typically refinance such debt with new debt having interest rates reflecting then-current market conditions. In order to reduce market rate risk on the underlying benchmark rate of interest associated with near- to medium-term forecasted issuances of fixed-rate debt, from time to time, we enter into IRPAs. We account for IRPAs as cash flow hedges. There were no unsettled IRPAs during any of the periods presented. At December 31, 2020, the amount of pre-tax net losses associated with interest rate hedges (excluding pay-fixed, receive-variable interest rate swaps) expected to be reclassified into earnings during the next twelve months is $4.

Foreign Currency Exchange Rate Risk

Forward Foreign Currency Exchange Contracts

In order to reduce the volatility in net income associated with our foreign operations, principally as a result of changes in the U.S. dollar exchange rate to the euro and British pound sterling, we enter into forward foreign currency exchange contracts. We layer in these foreign currency exchange contracts over a multi-year period to eventually equal approximately 90% of anticipated UGI International local currency earnings before income taxes. Because these contracts are not designated as hedging instruments, realized and unrealized gains and losses on these contracts are recorded in “Other non-operating expense, 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 $32 and $20 during the three months ended December 31, 2020 and 2019, respectively.

Quantitative Disclosures Related to Derivative Instruments

The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at December 31, 2020, September 30, 2020 and December 31, 2019, and the final settlement dates of the Company's open derivative contracts as of December 31, 2020, excluding those derivatives that qualified for the NPNS exception:

			Notional Amounts (in millions)
Type	Units	Settlements Extending Through	December 31, 2020		September 30, 2020		December 31, 2019
Commodity Price Risk:
Regulated Utility Operations
Gas Utility NYMEX natural gas futures and option contracts	Dekatherms	October 2021	16		22		15
Non-utility Operations
LPG swaps	Gallons	September 2023	719		846		772
Natural gas futures, forward, basis swap, options and pipeline contracts	Dekatherms	May 2025	342		339		358
Electricity long forward and futures contracts	Kilowatt hours	December 2024	4,719		4,517		4,145
Electricity short forward and futures contracts	Kilowatt hours	December 2024	97		188		556
Interest Rate Risk:
Interest rate swaps	Euro	October 2022	€	300	€	300	€	300
Interest rate swaps	USD	July 2024	$	1,306	$	1,344	$	1,354
Foreign Currency Exchange Rate Risk:
Forward foreign currency exchange contracts	USD	September 2023	$	457	$	511	$	431
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 December 31, 2020. Certain of the Partnership’s derivative contracts have credit-risk-related contingent features that may require the posting of additional collateral in the event of a downgrade of the Partnership’s debt rating. At December 31, 2020, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material.

Offsetting Derivative Assets and Liabilities

Derivative assets and liabilities are presented net by counterparty on the 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:

	December 31, 2020		September 30, 2020		December 31, 2019
Derivative assets:
Derivatives designated as hedging instruments:
Foreign currency contracts	$	8	$	17	$	14
Interest rate contracts	—		—		3
	8		17		17
Derivatives subject to PGC and DS mechanisms:
Commodity contracts	1		7		—
Derivatives not designated as hedging instruments:
Commodity contracts	170		100		46
Foreign currency contracts	6		15		26
	176		115		72
Total derivative assets — gross	185		139		89
Gross amounts offset in the balance sheet	(48)		(57)		(27)
Cash collateral received	(6)		—		(2)
Total derivative assets — net	$	131	$	82	$	60
Derivative liabilities:
Derivatives designated as hedging instruments:
Interest rate contracts	$	(50)	$	(55)	$	(7)
Derivatives subject to PGC and DS mechanisms:
Commodity contracts	(2)		—		(3)
Derivatives not designated as hedging instruments:
Commodity contracts	(70)		(118)		(184)
Foreign currency contracts	(25)		(14)		(4)
	(95)		(132)		(188)
Total derivative liabilities — gross	(147)		(187)		(198)
Gross amounts offset in the balance sheet	48		57		27
Cash collateral pledged	—		7		11
Total derivative liabilities — net	$	(99)	$	(123)	$	(160)

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 for the three months ended December 31, 2020 and 2019:

Three Months Ended December 31,:
	Gain (Loss) Recognized in AOCI				Loss Reclassified from AOCI into Income				Location of Loss Reclassified from AOCI into Income
Cash Flow Hedges:	2020		2019		2020		2019
Interest rate contracts	$	—	$	8	$	(7)	$	(1)	Interest expense
Net Investment Hedges:
Foreign currency contracts	$	(8)	$	(4)
	Gain (Loss) Recognized in Income
Derivatives Not Designated as Hedging Instruments:	2020		2019		Location of Gain (Loss) Recognized in Income
Commodity contracts	$	3	$	2	Revenues
Commodity contracts	103		(33)		Cost of sales
Commodity contracts	2		—		Operating and administrative expenses
Commodity contracts	5		—		Other operating income, net
Foreign currency contracts	(20)		(11)		Other non-operating expense, net
Total	$	93	$	(42)

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.

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Accumulated Other Comprehensive Income (Loss)

3 Months Ended

Dec. 31, 2020

Equity [Abstract]

Accumulated Other Comprehensive Income (Loss)

Note 11 — Accumulated Other Comprehensive Income (Loss)

The tables below present changes in AOCI, net of tax:

Three Months Ended December 31, 2020	Postretirement Benefit Plans		Derivative Instruments		Foreign Currency		Total
AOCI — September 30, 2020	$	(26)	$	(54)	$	(67)	$	(147)
Other comprehensive income before reclassification adjustments	—		—		63		63
Amounts reclassified from AOCI	—		5		—		5
Other comprehensive income attributable to UGI	—		5		63		68
AOCI — December 31, 2020	$	(26)	$	(49)	$	(4)	$	(79)
Three Months Ended December 31, 2019	Postretirement Benefit Plans		Derivative Instruments		Foreign Currency		Total
AOCI — September 30, 2019	$	(26)	$	(25)	$	(166)	$	(217)
Other comprehensive income before reclassification adjustments	—		6		47		53
Amounts reclassified from AOCI	—		1		—		1
Other comprehensive income attributable to UGI	—		7		47		54
AOCI — December 31, 2019	$	(26)	$	(18)	$	(119)	$	(163)

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Segment Information

3 Months Ended

Dec. 31, 2020

Segment Reporting [Abstract]

Segment Information

Note 12 — 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 December 31, 2020	Total		Eliminations			AmeriGas Propane		UGI International		Midstream & Marketing			UGI Utilities		Corporate & Other (a)
Revenues from external customers	$	1,932	$	—		$	666	$	700	$	279		$	285	$	2
Intersegment revenues	$	—	$	(78)	(b)	$	—	$	—	$	62		$	15	$	1
Cost of sales	$	833	$	(77)	(b)	$	272	$	383	$	237		$	132	$	(114)
Operating income	$	502	$	—		$	141	$	135	$	52		$	77	$	97
Income from equity investees	7		—			—		—		7		(c)	—		—
Other non-operating (expense) income, net	(19)		—			—		1		—			1		(21)
Earnings before interest expense and income taxes	490		—			141		136		59			78		76
Interest expense	(78)		—			(40)		(7)		(10)			(14)		(7)
Income before income taxes	$	412	$	—		$	101	$	129	$	49		$	64	$	69
Depreciation and amortization	$	124	$	—		$	43	$	33	$	18		$	29	$	1
Capital expenditures (including the effects of accruals)	$	152	$	—		$	27	$	29	$	17		$	79	$	—
As of December 31, 2020
Total assets	$	14,725	$	(353)		$	4,471	$	3,564	$	2,851		$	3,959	$	233

Three Months Ended December 31, 2019	Total		Eliminations			AmeriGas Propane		UGI International		Midstream & Marketing			UGI Utilities		Corporate & Other (a)
Revenues from external customers	$	2,007	$	—		$	730	$	651	$	309		$	314	$	3
Intersegment revenues	$	—	$	(80)	(b)	$	—	$	—	$	64		$	15	$	1
Cost of sales	$	1,008	$	(79)	(b)	$	289	$	368	$	264		$	151	$	15
Operating income (loss)	$	377	$	—		$	165	$	96	$	55		$	92	$	(31)
Income from equity investees	7		—			—		—		7		(c)	—		—
Other non-operating (expense) income, net	(12)		—			—		4		—			—		(16)
Earnings (loss) before interest expense and income taxes	372		—			165		100		62			92		(47)
Interest expense	(84)		—			(42)		(7)		(12)			(14)		(9)
Income (loss) before income taxes	$	288	$	—		$	123	$	93	$	50		$	78	$	(56)
Depreciation and amortization	$	119	$	—		$	44	$	31	$	18		$	26	$	—
Capital expenditures (including the effects of accruals)	$	153	$	—		$	39	$	20	$	23		$	71	$	—
As of December 31, 2019
Total assets	$	14,286	$	(366)		$	4,609	$	3,243	$	2,860		$	3,711	$	229

(a)Corporate & Other includes specific items attributable to our reportable segments that are not included in the segment profit measures used by our CODM in assessing our reportable segments’ performance or allocating resources. The following table presents such pre-tax gains (losses) which have been included in Corporate & Other, and the reportable segments to which they relate:

Three Months Ended December 31, 2020	Location on Income Statement	AmeriGas Propane		UGI International		Midstream & Marketing
Net gains on commodity derivative instruments not associated with current-period transactions	Revenues	$	—	$	—	$	2
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	Cost of sales	$	37	$	106	$	(29)
Unrealized losses on foreign currency derivative instruments	Other non-operating expense, net	$	—	$	(20)	$	—
Business transformation expenses	Operating and administrative expenses	$	(12)	$	(3)	$	—

Three Months Ended December 31, 2019	Location on Income Statement	AmeriGas Propane		UGI International		Midstream & Marketing
Net gains on commodity derivative instruments not associated with current-period transactions	Revenues	$	—	$	—	$	2
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	Cost of sales	$	9	$	(14)	$	(9)
Unrealized losses on foreign currency derivative instruments	Other non-operating expense, net	$	—	$	(15)	$	—
Acquisition and integration expenses associated with the CMG Acquisition	Operating and administrative expenses	$	—	$	—	$	(1)
Business transformation expenses	Operating and administrative expenses	$	(11)	$	(6)	$	—

(b)Represents the elimination of intersegment transactions principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane.

(c)Includes AFUDC associated with PennEast and equity income from Pennant.

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Business Transformation Initiatives

3 Months Ended

Dec. 31, 2020

Restructuring and Related Activities [Abstract]

Business Transformation Initiatives

Note 13 — 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, during the three months ended December 31, 2020 and 2019, we recognized $15 and $17, respectively of expenses principally comprising consulting, advisory, marketing and employee-related costs. These expenses 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. Amounts reflected in “Operating and administrative expenses” on the Condensed Consolidated Statement of Income in connection with this initiative, during the three months ended December 31, 2020, were not material.

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Impact of Global Pandemic

3 Months Ended

Dec. 31, 2020

Unusual or Infrequent Items, or Both [Abstract]

Impact of Global Pandemic

Note 14 — Impact of Global Pandemic

In March 2020, the WHO declared a global pandemic attributable to the outbreak and continued spread of COVID-19 that has had a significant impact throughout the global economy. In connection with the mitigation and containment procedures recommended by the WHO, the CDC, and as imposed by federal, state, and local governmental authorities, including shelter-in-place orders, quarantines and similar restrictions, the Company implemented a variety of procedures to protect its employees, third-party business partners, and customers worldwide. The Company continues to provide essential products and services to its global customers in a safe and reliable manner, and will continue to do so in compliance with mandated restrictions presented by each of the markets it serves. The Company continues to evaluate and react to the potential effects of a prolonged disruption and the continued impact on its results of operations. These items may include, but are not limited to: the financial condition of its customers; decreased availability and demand for its products and services; realization of accounts receivable; impairment considerations related to certain current assets, long-lived assets and goodwill; delays related to current and future projects; and the effects of government stimulus efforts including tax legislation in response to COVID-19. While its operations and financial performance continue to be impacted by COVID-19, the Company cannot predict the duration or magnitude of the outbreak and the total effects on its business, financial position, results of operations, liquidity or cash flows at this time.

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Summary of Significant Accounting Policies (Policies)

3 Months Ended

Dec. 31, 2020

Accounting Policies [Abstract]

Restricted Cash

Restricted Cash. Restricted cash principally represents those cash balances in our commodity futures brokerage accounts that are restricted from withdrawal.

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. In June 2016, the FASB issued ASU 2016-13, “Measurement of Credit Losses on Financial Instruments.” This ASU, as subsequently amended, requires entities to estimate lifetime expected credit losses for financial instruments not measured at fair value through net income, including trade and other receivables, net investments in leases, financial receivables, debt securities, and other financial instruments, 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. Effective October 1, 2020, the Company adopted this ASU, as updated, using a modified retrospective transition approach. The adoption of the new guidance did not have a material impact on our consolidated financial statements.

Accounting Standard Not Yet Adopted

Income Taxes. In December 2019, the FASB issued ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” This ASU simplifies the accounting for income taxes by eliminating certain exceptions within the existing guidance for recognizing deferred taxes for equity method investments, performing intraperiod allocations and calculating income taxes in interim periods. Further, this ASU clarifies existing guidance related to, among other things, recognizing deferred taxes for goodwill and allocated taxes to members of a consolidated group. This new guidance is effective for the Company for interim and annual periods beginning October 1, 2021 (Fiscal 2022). Early adoption is permitted. The Company is in the process of assessing the impact on its financial statements from the adoption of the new guidance and determining the period in which the new guidance will be adopted.

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Summary of Significant Accounting Policies (Tables)

3 Months Ended

Dec. 31, 2020

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.

	December 31, 2020		December 31, 2019		September 30, 2020		September 30, 2019
Cash and cash equivalents	$	416	$	333	$	336	$	447
Restricted cash	30		96		21		64
Cash, cash equivalents and restricted cash	$	446	$	429	$	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.

	December 31, 2020		December 31, 2019		September 30, 2020		September 30, 2019
Cash and cash equivalents	$	416	$	333	$	336	$	447
Restricted cash	30		96		21		64
Cash, cash equivalents and restricted cash	$	446	$	429	$	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 December 31,
	2020	2019
Denominator (thousands of shares):
Weighted-average common shares outstanding — basic	208,774	209,439
Incremental shares issuable for stock options and awards (a)	866	1,819
Weighted-average common shares outstanding — diluted	209,640	211,258

(a)For the three months ended December 31, 2020 and 2019, there were 6,000 and 3,499 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.

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Revenue from Contracts with Customers (Tables)

3 Months Ended

Dec. 31, 2020

Revenue from Contract with Customer [Abstract]

Summary of Disaggregation of Revenue

The following tables present our disaggregated revenues by reportable segment:

Three Months Ended December 31, 2020	Total		Eliminations (a)		AmeriGas Propane		UGI International		Midstream & Marketing		UGI Utilities		Corporate & Other
Revenues from contracts with customers:
Utility:
Core Market:
Residential	$	165	$	—	$	—	$	—	$	—	$	165	$	—
Commercial & Industrial	60		—		—		—		—		60		—
Large delivery service	40		—		—		—		—		40		—
Off-system sales and capacity releases	15		(14)		—		—		—		29		—
Other	4		(1)		—		—		—		5		—
Total Utility	284		(15)		—		—		—		299		—
Non-Utility:
LPG:
Retail	1,055		—		572		483		—		—		—
Wholesale	59		—		19		40		—		—		—
Energy Marketing	380		(26)		—		155		251		—		—
Midstream:
Pipeline	45		—		—		—		45		—		—
Peaking	2		(36)		—		—		38		—		—
Other	2		—		—		—		2		—		—
Electricity Generation	4		—		—		—		4		—		—
Other	72		—		56		16		—		—		—
Total Non-Utility	1,619		(62)		647		694		340		—		—
Total revenues from contracts with customers	1,903		(77)		647		694		340		299		—
Other revenues (b)	29		(1)		19		6		1		1		3
Total revenues	$	1,932	$	(78)	$	666	$	700	$	341	$	300	$	3

Three Months Ended December 31, 2019	Total		Eliminations (a)		AmeriGas Propane		UGI International		Midstream & Marketing		UGI Utilities		Corporate & Other
Revenues from contracts with customers:
Utility:
Core Market:
Residential	$	184	$	—	$	—	$	—	$	—	$	184	$	—
Commercial & Industrial	68		—		—		—		—		68		—
Large delivery service	41		—		—		—		—		41		—
Off-system sales and capacity releases	17		(14)		—		—		—		31		—
Other	4		(1)		—		—		—		5		—
Total Utility	314		(15)		—		—		—		329		—
Non-Utility:
LPG:
Retail	1,094		—		631		463		—		—		—
Wholesale	66		—		22		44		—		—		—
Energy Marketing	363		(26)		—		124		265		—		—
Midstream:
Pipeline	43		—		—		—		43		—		—
Peaking	4		(38)		—		—		42		—		—
Other	2		—		—		—		2		—		—
Electricity Generation	9		—		—		—		9		—		—
Other	80		—		59		12		9		—		—
Total Non-Utility	1,661		(64)		712		643		370		—		—
Total revenues from contracts with customers	1,975		(79)		712		643		370		329		—
Other revenues (b)	32		(1)		18		8		3		—		4
Total revenues	$	2,007	$	(80)	$	730	$	651	$	373	$	329	$	4

(a)Includes intersegment revenues principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane.

(b)Primarily represents revenues from tank rentals at AmeriGas Propane and UGI International, revenues from certain gathering assets at Midstream & Marketing, and gains and losses on commodity derivative instruments not associated with current-period transactions reflected in Corporate & Other, none of which are within the scope of ASC 606 and are accounted for in accordance with other GAAP.

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Inventories (Tables)

3 Months Ended

Dec. 31, 2020

Inventory Disclosure [Abstract]

Components of Inventories

Inventories comprise the following: 

	December 31, 2020		September 30, 2020		December 31, 2019
Non-utility LPG and natural gas	$	181	$	164	$	164
Gas Utility natural gas	19		20		24
Materials, supplies and other	79		57		60
Total inventories	$	279	$	241	$	248

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Utility Regulatory Assets and Liabilities and Regulatory Matters (Tables)

3 Months Ended

Dec. 31, 2020

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:

	December 31, 2020		September 30, 2020		December 31, 2019
Regulatory assets (a):
Income taxes recoverable	$	126	$	124	$	121
Underfunded pension and postretirement plans	172		175		175
Environmental costs	59		61		58
Removal costs, net	24		26		27
Other	14		11		10
Total regulatory assets	$	395	$	397	$	391
Regulatory liabilities (a):
Postretirement benefit overcollections	$	13	$	13	$	14
Deferred fuel and power refunds	24		29		6
State tax benefits — distribution system repairs	28		28		26
PAPUC Temporary Rates Order	5		7		25
Excess federal deferred income taxes	272		274		278
Other	4		2		2
Total regulatory liabilities	$	346	$	353	$	351

(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:

	December 31, 2020		September 30, 2020		December 31, 2019
Regulatory assets (a):
Income taxes recoverable	$	126	$	124	$	121
Underfunded pension and postretirement plans	172		175		175
Environmental costs	59		61		58
Removal costs, net	24		26		27
Other	14		11		10
Total regulatory assets	$	395	$	397	$	391
Regulatory liabilities (a):
Postretirement benefit overcollections	$	13	$	13	$	14
Deferred fuel and power refunds	24		29		6
State tax benefits — distribution system repairs	28		28		26
PAPUC Temporary Rates Order	5		7		25
Excess federal deferred income taxes	272		274		278
Other	4		2		2
Total regulatory liabilities	$	346	$	353	$	351

(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.

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Defined Benefit Pension and Other Postretirement Plans (Tables)

3 Months Ended

Dec. 31, 2020

Retirement Benefits [Abstract]

Components of Net Periodic Pension Expense and Other Postretirement Benefit Costs

Net periodic pension cost includes the following components:

Three Months Ended December 31,	2020		2019
Service cost	$	3	$	3
Interest cost	5		6
Expected return on assets	(10)		(10)
Amortization of:
Actuarial loss	4		4
Net cost	$	2	$	3

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Fair Value Measurements (Tables)

3 Months Ended

Dec. 31, 2020

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
December 31, 2020:
Derivative instruments:
Assets:
Commodity contracts	$	60	$	111	$	—	$	171
Foreign currency contracts	$	—	$	14	$	—	$	14
Liabilities:
Commodity contracts	$	(58)	$	(14)	$	—	$	(72)
Foreign currency contracts	$	—	$	(25)	$	—	$	(25)
Interest rate contracts	$	—	$	(50)	$	—	$	(50)
Non-qualified supplemental postretirement grantor trust investments (a)	$	46	$	—	$	—	$	46
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
December 31, 2019:
Derivative instruments:
Assets:
Commodity contracts	$	26	$	20	$	—	$	46
Foreign currency contracts	$	—	$	40	$	—	$	40
Interest rate contracts	$	—	$	3	$	—	$	3
Liabilities:
Commodity contracts	$	(77)	$	(110)	$	—	$	(187)
Foreign currency contracts	$	—	$	(4)	$	—	$	(4)
Interest rate contracts	$	—	$	(7)	$	—	$	(7)
Non-qualified supplemental postretirement grantor trust investments (a)	$	42	$	—	$	—	$	42

(a)Consists primarily of mutual fund investments held in grantor trusts associated with non-qualified supplemental retirement plans.

Schedule of Carrying Amount and Estimated Fair Value of Long-term Debt

The carrying amounts and estimated fair values of our long-term debt (including current maturities but excluding unamortized debt issuance costs) were as follows:

	December 31, 2020		September 30, 2020		December 31, 2019
Carrying amount	$	6,078	$	6,081	$	5,906
Estimated fair value	$	6,581	$	6,504	$	6,249

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Derivative Instruments and Hedging Activities (Tables)

3 Months Ended

Dec. 31, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Notional Amounts Related to Open Derivative Contracts

The following table summarizes by derivative type the gross notional amounts related to open derivative contracts at December 31, 2020, September 30, 2020 and December 31, 2019, and the final settlement dates of the Company's open derivative contracts as of December 31, 2020, excluding those derivatives that qualified for the NPNS exception:

			Notional Amounts (in millions)
Type	Units	Settlements Extending Through	December 31, 2020		September 30, 2020		December 31, 2019
Commodity Price Risk:
Regulated Utility Operations
Gas Utility NYMEX natural gas futures and option contracts	Dekatherms	October 2021	16		22		15
Non-utility Operations
LPG swaps	Gallons	September 2023	719		846		772
Natural gas futures, forward, basis swap, options and pipeline contracts	Dekatherms	May 2025	342		339		358
Electricity long forward and futures contracts	Kilowatt hours	December 2024	4,719		4,517		4,145
Electricity short forward and futures contracts	Kilowatt hours	December 2024	97		188		556
Interest Rate Risk:
Interest rate swaps	Euro	October 2022	€	300	€	300	€	300
Interest rate swaps	USD	July 2024	$	1,306	$	1,344	$	1,354
Foreign Currency Exchange Rate Risk:
Forward foreign currency exchange contracts	USD	September 2023	$	457	$	511	$	431
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:

	December 31, 2020		September 30, 2020		December 31, 2019
Derivative assets:
Derivatives designated as hedging instruments:
Foreign currency contracts	$	8	$	17	$	14
Interest rate contracts	—		—		3
	8		17		17
Derivatives subject to PGC and DS mechanisms:
Commodity contracts	1		7		—
Derivatives not designated as hedging instruments:
Commodity contracts	170		100		46
Foreign currency contracts	6		15		26
	176		115		72
Total derivative assets — gross	185		139		89
Gross amounts offset in the balance sheet	(48)		(57)		(27)
Cash collateral received	(6)		—		(2)
Total derivative assets — net	$	131	$	82	$	60
Derivative liabilities:
Derivatives designated as hedging instruments:
Interest rate contracts	$	(50)	$	(55)	$	(7)
Derivatives subject to PGC and DS mechanisms:
Commodity contracts	(2)		—		(3)
Derivatives not designated as hedging instruments:
Commodity contracts	(70)		(118)		(184)
Foreign currency contracts	(25)		(14)		(4)
	(95)		(132)		(188)
Total derivative liabilities — gross	(147)		(187)		(198)
Gross amounts offset in the balance sheet	48		57		27
Cash collateral pledged	—		7		11
Total derivative liabilities — net	$	(99)	$	(123)	$	(160)

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 for the three months ended December 31, 2020 and 2019:

Three Months Ended December 31,:
	Gain (Loss) Recognized in AOCI				Loss Reclassified from AOCI into Income				Location of Loss Reclassified from AOCI into Income
Cash Flow Hedges:	2020		2019		2020		2019
Interest rate contracts	$	—	$	8	$	(7)	$	(1)	Interest expense
Net Investment Hedges:
Foreign currency contracts	$	(8)	$	(4)
	Gain (Loss) Recognized in Income
Derivatives Not Designated as Hedging Instruments:	2020		2019		Location of Gain (Loss) Recognized in Income
Commodity contracts	$	3	$	2	Revenues
Commodity contracts	103		(33)		Cost of sales
Commodity contracts	2		—		Operating and administrative expenses
Commodity contracts	5		—		Other operating income, net
Foreign currency contracts	(20)		(11)		Other non-operating expense, net
Total	$	93	$	(42)

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Accumulated Other Comprehensive Income (Loss) (Tables)

3 Months Ended

Dec. 31, 2020

Equity [Abstract]

Schedule of Accumulated Other Comprehensive Income

The tables below present changes in AOCI, net of tax:

Three Months Ended December 31, 2020	Postretirement Benefit Plans		Derivative Instruments		Foreign Currency		Total
AOCI — September 30, 2020	$	(26)	$	(54)	$	(67)	$	(147)
Other comprehensive income before reclassification adjustments	—		—		63		63
Amounts reclassified from AOCI	—		5		—		5
Other comprehensive income attributable to UGI	—		5		63		68
AOCI — December 31, 2020	$	(26)	$	(49)	$	(4)	$	(79)
Three Months Ended December 31, 2019	Postretirement Benefit Plans		Derivative Instruments		Foreign Currency		Total
AOCI — September 30, 2019	$	(26)	$	(25)	$	(166)	$	(217)
Other comprehensive income before reclassification adjustments	—		6		47		53
Amounts reclassified from AOCI	—		1		—		1
Other comprehensive income attributable to UGI	—		7		47		54
AOCI — December 31, 2019	$	(26)	$	(18)	$	(119)	$	(163)

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Segment Information (Tables)

3 Months Ended

Dec. 31, 2020

Segment Reporting [Abstract]

Schedule of Segment Reporting Information

Three Months Ended December 31, 2020	Total		Eliminations			AmeriGas Propane		UGI International		Midstream & Marketing			UGI Utilities		Corporate & Other (a)
Revenues from external customers	$	1,932	$	—		$	666	$	700	$	279		$	285	$	2
Intersegment revenues	$	—	$	(78)	(b)	$	—	$	—	$	62		$	15	$	1
Cost of sales	$	833	$	(77)	(b)	$	272	$	383	$	237		$	132	$	(114)
Operating income	$	502	$	—		$	141	$	135	$	52		$	77	$	97
Income from equity investees	7		—			—		—		7		(c)	—		—
Other non-operating (expense) income, net	(19)		—			—		1		—			1		(21)
Earnings before interest expense and income taxes	490		—			141		136		59			78		76
Interest expense	(78)		—			(40)		(7)		(10)			(14)		(7)
Income before income taxes	$	412	$	—		$	101	$	129	$	49		$	64	$	69
Depreciation and amortization	$	124	$	—		$	43	$	33	$	18		$	29	$	1
Capital expenditures (including the effects of accruals)	$	152	$	—		$	27	$	29	$	17		$	79	$	—
As of December 31, 2020
Total assets	$	14,725	$	(353)		$	4,471	$	3,564	$	2,851		$	3,959	$	233

Three Months Ended December 31, 2019	Total		Eliminations			AmeriGas Propane		UGI International		Midstream & Marketing			UGI Utilities		Corporate & Other (a)
Revenues from external customers	$	2,007	$	—		$	730	$	651	$	309		$	314	$	3
Intersegment revenues	$	—	$	(80)	(b)	$	—	$	—	$	64		$	15	$	1
Cost of sales	$	1,008	$	(79)	(b)	$	289	$	368	$	264		$	151	$	15
Operating income (loss)	$	377	$	—		$	165	$	96	$	55		$	92	$	(31)
Income from equity investees	7		—			—		—		7		(c)	—		—
Other non-operating (expense) income, net	(12)		—			—		4		—			—		(16)
Earnings (loss) before interest expense and income taxes	372		—			165		100		62			92		(47)
Interest expense	(84)		—			(42)		(7)		(12)			(14)		(9)
Income (loss) before income taxes	$	288	$	—		$	123	$	93	$	50		$	78	$	(56)
Depreciation and amortization	$	119	$	—		$	44	$	31	$	18		$	26	$	—
Capital expenditures (including the effects of accruals)	$	153	$	—		$	39	$	20	$	23		$	71	$	—
As of December 31, 2019
Total assets	$	14,286	$	(366)		$	4,609	$	3,243	$	2,860		$	3,711	$	229

(a)Corporate & Other includes specific items attributable to our reportable segments that are not included in the segment profit measures used by our CODM in assessing our reportable segments’ performance or allocating resources. The following table presents such pre-tax gains (losses) which have been included in Corporate & Other, and the reportable segments to which they relate:

Three Months Ended December 31, 2020	Location on Income Statement	AmeriGas Propane		UGI International		Midstream & Marketing
Net gains on commodity derivative instruments not associated with current-period transactions	Revenues	$	—	$	—	$	2
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	Cost of sales	$	37	$	106	$	(29)
Unrealized losses on foreign currency derivative instruments	Other non-operating expense, net	$	—	$	(20)	$	—
Business transformation expenses	Operating and administrative expenses	$	(12)	$	(3)	$	—

Three Months Ended December 31, 2019	Location on Income Statement	AmeriGas Propane		UGI International		Midstream & Marketing
Net gains on commodity derivative instruments not associated with current-period transactions	Revenues	$	—	$	—	$	2
Net gains (losses) on commodity derivative instruments not associated with current-period transactions	Cost of sales	$	9	$	(14)	$	(9)
Unrealized losses on foreign currency derivative instruments	Other non-operating expense, net	$	—	$	(15)	$	—
Acquisition and integration expenses associated with the CMG Acquisition	Operating and administrative expenses	$	—	$	—	$	(1)
Business transformation expenses	Operating and administrative expenses	$	(11)	$	(6)	$	—

(b)Represents the elimination of intersegment transactions principally among Midstream & Marketing, UGI Utilities and AmeriGas Propane.

(c)Includes AFUDC associated with PennEast and equity income from Pennant.

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Nature of Operations (Details) Customer in Thousands, $ in Millions		3 Months Ended
	Dec. 29, 2020 USD ($) Customer county	Dec. 31, 2020 county
Business Acquisition [Line Items]
Number of counties of operation | county		1
Mountaineer [Member] | Pending
Business Acquisition [Line Items]
Number of counties of operation | county	50
Enterprise value | $	$ 540
Assumption of debt | $	$ 140
Customers served | Customer	215

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Summary of Significant Accounting Policies - (Narrative) (Details) - Affiliated Entity - Penn East Pipeline Company LLC	Dec. 31, 2020
UGI Penn East LLC
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Equity method investment ownership percent	20.00%
Southern Company
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Equity method investment ownership percent	20.00%
New Jersey Resources
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Equity method investment ownership percent	20.00%
South Jersey Industries
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Equity method investment ownership percent	20.00%
Enbridge Inc
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Equity method investment ownership percent	20.00%

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Summary of Significant Accounting Policies - Schedule of Cash and Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019	Sep. 30, 2019
Accounting Policies [Abstract]
Cash and cash equivalents	$ 416.0	$ 336.0	$ 333.0	$ 447.0
Restricted cash	30.0	21.0	96.0	64.0
Cash, cash equivalents and restricted cash	$ 446.0	$ 357.0	$ 429.0	$ 511.0

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Summary of Significant Accounting Policies - Shares Used in Computing Basic and Diluted Earnings Per Share (Details) - shares shares in Thousands	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Denominator:
Weighted-average common shares outstanding - basic (in shares)	208,774	209,439
Incremental shares issuable for stock options and awards (in shares)	866	1,819
Weighted-average common shares outstanding - diluted (in shares)	209,640	211,258
Antidilutive securities excluded from computation of earnings per share (in shares)	6,000	3,499

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Revenue from Contracts with Customers - Disaggregation (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 1,903.0	$ 1,975.0
Other revenue	29.0	32.0
Total revenues	1,932.0	2,007.0
Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	284.0	314.0
Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	165.0	184.0
Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	60.0	68.0
Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	40.0	41.0
Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	15.0	17.0
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4.0	4.0
Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,619.0	1,661.0
Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,055.0	1,094.0
Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	59.0	66.0
Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	380.0	363.0
Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	45.0	43.0
Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2.0	4.0
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2.0	2.0
Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4.0	9.0
Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	72.0	80.0
Eliminations
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(77.0)	(79.0)
Other revenue	(1.0)	(1.0)
Total revenues	(78.0)	(80.0)
Eliminations | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(15.0)	(15.0)
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	(14.0)	(14.0)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(1.0)	(1.0)
Eliminations | Total Non-Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	(62.0)	(64.0)
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	(26.0)	(26.0)
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	(36.0)	(38.0)
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0.0	0.0
Eliminations | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0.0	0.0
Eliminations | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0.0	0.0
Eliminations | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues	0.0	0.0
Eliminations | UGI International
Disaggregation of Revenue [Line Items]
Total revenues	0.0	0.0
Eliminations | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues	(62.0)	(64.0)
Eliminations | UGI Utilities
Disaggregation of Revenue [Line Items]
Total revenues	(15.0)	(15.0)
Operating Segments | AmeriGas Propane
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	647.0	712.0
Other revenue	19.0	18.0
Total revenues	666.0	730.0
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	647.0	712.0
Operating Segments | AmeriGas Propane | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	572.0	631.0
Operating Segments | AmeriGas Propane | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	19.0	22.0
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	56.0	59.0
Operating Segments | UGI International
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	694.0	643.0
Other revenue	6.0	8.0
Total revenues	700.0	651.0
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	694.0	643.0
Operating Segments | UGI International | Retail
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	483.0	463.0
Operating Segments | UGI International | Wholesale
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	40.0	44.0
Operating Segments | UGI International | Energy Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	155.0	124.0
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	16.0	12.0
Operating Segments | Midstream & Marketing
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	340.0	370.0
Other revenue	1.0	3.0
Total revenues	341.0	373.0
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	340.0	370.0
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	251.0	265.0
Operating Segments | Midstream & Marketing | Pipeline
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	45.0	43.0
Operating Segments | Midstream & Marketing | Peaking
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	38.0	42.0
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	2.0	2.0
Operating Segments | Midstream & Marketing | Electricity Generation
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	4.0	9.0
Operating Segments | Midstream & Marketing | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	0.0	9.0
Operating Segments | UGI Utilities
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	299.0	329.0
Other revenue	1.0	0.0
Total revenues	300.0	329.0
Operating Segments | UGI Utilities | Total Utility
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	299.0	329.0
Operating Segments | UGI Utilities | Residential
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	165.0	184.0
Operating Segments | UGI Utilities | Commercial & Industrial
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	60.0	68.0
Operating Segments | UGI Utilities | Large delivery service
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	40.0	41.0
Operating Segments | UGI Utilities | Off-system sales and capacity releases
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	29.0	31.0
Operating Segments | UGI Utilities | Other
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	5.0	5.0
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	3.0	4.0
Total revenues	3.0	4.0
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

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Revenue from Contracts with Customers (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Contract with customer, liability, current	$ 108	$ 93	$ 115
Contract with customer, liability, revenue recognized	60	61
Midstream & Marketing
Disaggregation of Revenue [Line Items]
Revenue, remaining performance obligation	$ 2,100
UGI Utilities
Disaggregation of Revenue [Line Items]
Revenue, remaining performance obligation		$ 200

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Inventories - Components of Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019
Inventory
Total inventories	$ 279	$ 241	$ 248
Non-utility LPG and natural gas
Inventory
Total inventories	181	164	164
Gas Utility natural gas
Inventory
Total inventories	19	20	24
Materials, supplies and other
Inventory
Total inventories	$ 79	$ 57	$ 60

XML

Inventories - Narrative (Details) - UGI Utilities	3 Months Ended
	Dec. 31, 2020 storage_agreement
Inventory
Number of storage agreements	2
SCAA contract term (up to)	3 years

XML

Utility Regulatory Assets and Liabilities and Regulatory Matters (Details) - UGI Utilities - USD ($) $ in Millions	Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019
Regulatory Assets
Regulatory assets	$ 395.0	$ 397.0	$ 391.0
Regulatory Liabilities
Regulatory liabilities	346.0	353.0	351.0
Postretirement benefit overcollections
Regulatory Liabilities
Regulatory liabilities	13.0	13.0	14.0
Deferred fuel and power refunds
Regulatory Liabilities
Regulatory liabilities	24.0	29.0	6.0
State tax benefits — distribution system repairs
Regulatory Liabilities
Regulatory liabilities	28.0	28.0	26.0
PAPUC temporary rates order
Regulatory Liabilities
Regulatory liabilities	5.0	7.0	25.0
Excess federal deferred income taxes
Regulatory Liabilities
Regulatory liabilities	272.0	274.0	278.0
Other
Regulatory Liabilities
Regulatory liabilities	4.0	2.0	2.0
Income taxes recoverable
Regulatory Assets
Regulatory assets	126.0	124.0	121.0
Underfunded pension and postretirement plans
Regulatory Assets
Regulatory assets	172.0	175.0	175.0
Environmental costs
Regulatory Assets
Regulatory assets	59.0	61.0	58.0
Removal costs, net
Regulatory Assets
Regulatory assets	24.0	26.0	27.0
Other
Regulatory Assets
Regulatory assets	$ 14.0	$ 11.0	$ 10.0

XML

Utility Regulatory Assets and Liabilities and Regulatory Matters - Narrative (Details) - USD ($)	Oct. 08, 2020	Jan. 28, 2020	Oct. 11, 2019	Jan. 28, 2019	Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019
UGI Gas
Regulatory Assets
Public utilities, tax benefits, effective period			12 months
UGI Gas | PAPUC
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
UGI Gas | PAPUC | Beginning January 1, 2021
Regulatory Assets
Public utilities, approved rate increase (decrease), amount	$ 10,000,000
UGI Gas | PAPUC | 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)					$ (1,000,000)	$ 8,000,000	$ (3,000,000)

XML

Commitments and Contingencies (Details)	3 Months Ended	12 Months Ended
	Dec. 31, 2020 USD ($) subsidiary	Dec. 31, 2017 USD ($) record_of_decision	Dec. 31, 2008 lb	Dec. 31, 2007 lb	Sep. 30, 2020 USD ($)	Dec. 31, 2019 USD ($)
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	$ 50,000,000
UGI Utilities | PNG and CPG
Loss Contingencies
Number of subsidiaries acquired with similar histories | subsidiary	2
AmeriGas OLP | Saranac Lake, New York | New York State Department of Environment Conservation Remediation Plan
Loss Contingencies
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

XML

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
	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure
Service cost	$ 3	$ 3
Interest cost	5	6
Expected return on assets	(10)	(10)
Amortization of:
Actuarial loss	4	4
Net cost	$ 2	$ 3

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Fair Value Measurements - Financial Assets and Liabilities that are Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Millions	Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	$ 185	$ 139	$ 89
Derivative instruments, Liabilities	(147)	(187)	(198)
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	46	42	42
Fair Value, Measurements, Recurring | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	171	107	46
Derivative instruments, Liabilities	(72)	(118)	(187)
Fair Value, Measurements, Recurring | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	14	32	40
Derivative instruments, Liabilities	(25)	(14)	(4)
Fair Value, Measurements, Recurring | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets			3
Derivative instruments, Liabilities	(50)	(55)	(7)
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	46	42	42
Fair Value, Measurements, Recurring | Level 1 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	60	68	26
Derivative instruments, Liabilities	(58)	(54)	(77)
Fair Value, Measurements, 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
Fair Value, Measurements, Recurring | Level 1 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets			0
Derivative instruments, Liabilities	0	0	0
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	0	0	0
Fair Value, Measurements, Recurring | Level 2 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	111	39	20
Derivative instruments, Liabilities	(14)	(64)	(110)
Fair Value, Measurements, Recurring | Level 2 | Foreign currency contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets	14	32	40
Derivative instruments, Liabilities	(25)	(14)	(4)
Fair Value, Measurements, Recurring | Level 2 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets			3
Derivative instruments, Liabilities	(50)	(55)	(7)
Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Non-qualified supplemental postretirement grantor trust investments	0	0	0
Fair Value, Measurements, 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
Fair Value, Measurements, 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
Fair Value, Measurements, Recurring | Level 3 | Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis
Derivative instruments, Assets			0
Derivative instruments, Liabilities	$ 0	$ 0	$ 0

XML

Fair Value Measurements - (Details) - USD ($) $ in Millions	Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,078	$ 6,081	$ 5,906
Estimated fair value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 6,581	$ 6,504	$ 6,249

XML

Derivative Instruments and Hedging Activities - Narrative (Details) - USD ($)	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Sep. 30, 2020
Derivative [Line Items]
Pre-tax net losses associated with interest rate hedges	$ 4,000,000
Pre-tax losses associated with net investment hedges	32,000,000	$ 20,000,000
Interest Rate Protection Agreements
Derivative [Line Items]
Notional amount	$ 0	$ 0	$ 0
Foreign Exchange Forward
Derivative [Line Items]
Derivative notional amount percent of required need coverage	90.00%

XML

Derivative Instruments and Hedging Activities - Schedule of Notional Amounts (Details) € in Millions, kWh in Millions, gal in Millions, DTH in Millions, $ in Millions	Dec. 31, 2020 USD ($) gal DTH kWh	Dec. 31, 2020 EUR (€) gal DTH kWh	Sep. 30, 2020 USD ($) gal kWh DTH	Sep. 30, 2020 EUR (€) gal kWh DTH	Dec. 31, 2019 USD ($) kWh gal DTH	Dec. 31, 2019 EUR (€) kWh gal DTH
Commodity contracts | Propane
Derivative [Line Items]
Notional amount (in units) | gal	719	719	846	846	772	772
Commodity contracts | Electricity | Long
Derivative [Line Items]
Notional amount (in units) | kWh	4,719	4,719	4,517	4,517	4,145	4,145
Commodity contracts | Electricity | Short
Derivative [Line Items]
Notional amount (in units) | kWh	97	97	188	188	556	556
Natural gas futures, forward and pipeline contracts (in dekatherms) | Natural Gas
Derivative [Line Items]
Notional amount (in units) | DTH	342	342	339	339	358	358
Interest rate swaps
Derivative [Line Items]
Notional amount	$ 1,306	€ 300	$ 1,344	€ 300	$ 1,354	€ 300
Forward foreign currency exchange contracts
Derivative [Line Items]
Notional amount	$ 457	€ 173	$ 511	€ 173	$ 431	€ 173
Regulated Utility Operations | Commodity contracts | Natural Gas
Derivative [Line Items]
Notional amount (in units) | DTH	16	16	22	22	15	15

XML

Derivative Instruments and Hedging Activities - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019
Derivative assets:
Total derivative assets — gross	$ 185	$ 139	$ 89
Gross amounts offset in the balance sheet	(48)	(57)	(27)
Cash collateral received	(6)	0	(2)
Total derivative assets — net	131	82	60
Derivative liabilities:
Total derivative liabilities — gross	(147)	(187)	(198)
Gross amounts offset in the balance sheet	48	57	27
Cash collateral pledged	0	7	11
Total derivative liabilities — net	(99)	(123)	(160)
Derivatives subject to PGC and DS mechanisms:
Derivative assets:
Total derivative assets — gross	1	7	0
Derivative liabilities:
Total derivative liabilities — gross	(2)	0	(3)
Derivatives designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	8	17	17
Derivatives designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	8	17	14
Derivatives designated as hedging instruments: | Interest rate contracts
Derivative assets:
Total derivative assets — gross	0	0	3
Derivative liabilities:
Total derivative liabilities — gross	(50)	(55)	(7)
Derivatives not designated as hedging instruments:
Derivative assets:
Total derivative assets — gross	176	115	72
Derivative liabilities:
Total derivative liabilities — gross	(95)	(132)	(188)
Derivatives not designated as hedging instruments: | Foreign currency contracts
Derivative assets:
Total derivative assets — gross	6	15	26
Derivative liabilities:
Total derivative liabilities — gross	(25)	(14)	(4)
Derivatives not designated as hedging instruments: | Commodity contracts
Derivative assets:
Total derivative assets — gross	170	100	46
Derivative liabilities:
Total derivative liabilities — gross	$ (70)	$ (118)	$ (184)

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Derivative Instruments and Hedging Activities - Effects of Derivative Instruments on the Condensed Consolidated Statements of Income and Changes in AOCI (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Derivatives Not Designated as Hedging Instruments
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 93	$ (42)
Interest rate contracts | Interest expense
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in AOCI	0	8
Loss Reclassified from AOCI into Income	(7)	(1)
Foreign currency contracts
Derivative Instruments, Gain (Loss)
Foreign currency contracts	(8)	(4)
Foreign currency contracts | Derivatives Not Designated as Hedging Instruments | Other non-operating expense, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	(20)	(11)
Commodity contracts | Derivatives Not Designated as Hedging Instruments | Revenues
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	3	2
Commodity contracts | Derivatives Not Designated as Hedging Instruments | Cost of sales
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	103	(33)
Commodity contracts | Derivatives Not Designated as Hedging Instruments | Operating and administrative expenses
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	2	0
Commodity contracts | Derivatives Not Designated as Hedging Instruments | Other operating income, net
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 5	$ 0

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Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	$ 4,137
Other comprehensive (loss) income before reclassification adjustments (after-tax)	63	$ 53
Amounts reclassified from AOCI	5	1
Other comprehensive income (loss) attributable to UGI	68	54
Balance, end of period	4,446	4,005
Postretirement Benefit Plans
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(26)	(26)
Other comprehensive (loss) income before reclassification adjustments (after-tax)	0	0
Amounts reclassified from AOCI	0	0
Other comprehensive income (loss) attributable to UGI	0	0
Balance, end of period	(26)	(26)
Derivative Instruments
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(54)	(25)
Other comprehensive (loss) income before reclassification adjustments (after-tax)	0	6
Amounts reclassified from AOCI	5	1
Other comprehensive income (loss) attributable to UGI	5	7
Balance, end of period	(49)	(18)
Foreign Currency
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(67)	(166)
Other comprehensive (loss) income before reclassification adjustments (after-tax)	63	47
Amounts reclassified from AOCI	0	0
Other comprehensive income (loss) attributable to UGI	63	47
Balance, end of period	(4)	(119)
Total
AOCI Attributable to Parent, Net of Tax
Balance, beginning of period	(147)	(217)
Balance, end of period	$ (79)	$ (163)

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Segment Information - Narrative (Details)	3 Months Ended
	Dec. 31, 2020 segment
Segment Reporting [Abstract]
Number of reportable segments	4

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Segment Information - Schedule of Segment Reporting Information (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Sep. 30, 2020
Segment Reporting Information [Line Items]
Revenues	$ 1,932.0	$ 2,007.0
Cost of sales	833.0	1,008.0
Operating income	502.0	377.0
Income (loss) from equity investees	7.0	7.0
Other non-operating expense, net	(19.0)	(12.0)
Earnings before interest expense and income taxes	490.0	372.0
Interest expense	(78.0)	(84.0)
Income before income taxes	412.0	288.0
Depreciation and amortization	124.0	119.0
Capital expenditures (including the effects of accruals)	152.0	153.0
Total assets	14,725.0	14,286.0	$ 13,985.0
Eliminations
Segment Reporting Information [Line Items]
Revenues	(78.0)	(80.0)
Cost of sales	(77.0)	(79.0)
Operating income	0.0	0.0
Income (loss) from equity investees	0.0	0.0
Other non-operating expense, net	0.0	0.0
Earnings before interest expense and income taxes	0.0	0.0
Interest expense	0.0	0.0
Income before income taxes	0.0	0.0
Depreciation and amortization	0.0	0.0
Capital expenditures (including the effects of accruals)	0.0	0.0
Total assets	(353.0)	(366.0)
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	(62.0)	(64.0)
Eliminations | UGI Utilities
Segment Reporting Information [Line Items]
Revenues	(15.0)	(15.0)
Operating Segments | AmeriGas Propane
Segment Reporting Information [Line Items]
Revenues	666.0	730.0
Cost of sales	272.0	289.0
Operating income	141.0	165.0
Income (loss) from equity investees	0.0	0.0
Other non-operating expense, net	0.0	0.0
Earnings before interest expense and income taxes	141.0	165.0
Interest expense	(40.0)	(42.0)
Income before income taxes	101.0	123.0
Depreciation and amortization	43.0	44.0
Capital expenditures (including the effects of accruals)	27.0	39.0
Total assets	4,471.0	4,609.0
Operating Segments | UGI International
Segment Reporting Information [Line Items]
Revenues	700.0	651.0
Cost of sales	383.0	368.0
Operating income	135.0	96.0
Income (loss) from equity investees	0.0	0.0
Other non-operating expense, net	1.0	4.0
Earnings before interest expense and income taxes	136.0	100.0
Interest expense	(7.0)	(7.0)
Income before income taxes	129.0	93.0
Depreciation and amortization	33.0	31.0
Capital expenditures (including the effects of accruals)	29.0	20.0
Total assets	3,564.0	3,243.0
Operating Segments | Midstream & Marketing
Segment Reporting Information [Line Items]
Revenues	341.0	373.0
Revenues, before intersegment effect	279.0	309.0
Cost of sales	237.0	264.0
Operating income	52.0	55.0
Income (loss) from equity investees	7.0	7.0
Other non-operating expense, net	0.0	0.0
Earnings before interest expense and income taxes	59.0	62.0
Interest expense	(10.0)	(12.0)
Income before income taxes	49.0	50.0
Depreciation and amortization	18.0	18.0
Capital expenditures (including the effects of accruals)	17.0	23.0
Total assets	2,851.0	2,860.0
Operating Segments | UGI Utilities
Segment Reporting Information [Line Items]
Revenues	300.0	329.0
Revenues, before intersegment effect	285.0	314.0
Cost of sales	132.0	151.0
Operating income	77.0	92.0
Income (loss) from equity investees	0.0	0.0
Other non-operating expense, net	1.0	0.0
Earnings before interest expense and income taxes	78.0	92.0
Interest expense	(14.0)	(14.0)
Income before income taxes	64.0	78.0
Depreciation and amortization	29.0	26.0
Capital expenditures (including the effects of accruals)	79.0	71.0
Total assets	3,959.0	3,711.0
Corporate & Other
Segment Reporting Information [Line Items]
Revenues, before intersegment effect	2.0	3.0
Cost of sales	(114.0)	15.0
Operating income	97.0	(31.0)
Income (loss) from equity investees	0.0	0.0
Other non-operating expense, net	(21.0)	(16.0)
Earnings before interest expense and income taxes	76.0	(47.0)
Interest expense	(7.0)	(9.0)
Income before income taxes	69.0	(56.0)
Depreciation and amortization	1.0	0.0
Capital expenditures (including the effects of accruals)	0.0	0.0
Total assets	233.0	229.0
Intersegment revenues Corporate & Other
Segment Reporting Information [Line Items]
Revenues	$ (1.0)	$ (1.0)

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Segment Information - Reconciliation of Partnership Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions	$ 96	$ (27)
AmeriGas Propane | Corporate & Other
Segment Reporting Information [Line Items]
Business transformation expenses	(12)	(11)
AmeriGas Propane | Affiliated Entity | CMG | Pennant | Corporate & Other
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition		0
AmeriGas Propane | Commodity contracts | Corporate & Other
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions	0	0
AmeriGas Propane | Cost of sales | Corporate & Other
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions	37	9
AmeriGas Propane | Foreign currency contracts | Corporate & Other
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions	0	0
UGI International | Corporate & Other
Segment Reporting Information [Line Items]
Business transformation expenses	(3)	(6)
UGI International | Affiliated Entity | CMG | Pennant | Corporate & Other
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition		0
UGI International | Commodity contracts | Corporate & Other
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions	0	0
UGI International | Cost of sales | Corporate & Other
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions	106	(14)
UGI International | Foreign currency contracts | Corporate & Other
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions	(20)	(15)
Midstream & Marketing | Corporate & Other
Segment Reporting Information [Line Items]
Business transformation expenses	0	0
Midstream & Marketing | Affiliated Entity | CMG | Pennant | Corporate & Other
Segment Reporting Information [Line Items]
Acquisition and integration expenses associated with the CMG Acquisition		(1)
Midstream & Marketing | Commodity contracts | Corporate & Other
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions	2	2
Midstream & Marketing | Cost of sales | Corporate & Other
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions	(29)	(9)
Midstream & Marketing | Foreign currency contracts | Corporate & Other
Segment Reporting Information [Line Items]
Net gains on commodity derivative instruments not associated with current-period transactions	$ 0	$ 0

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Business Transformation Initiatives (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Restructuring and Related Activities [Abstract]
Costs principally comprising consulting, advisory and employee-related costs	$ 15	$ 17