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Table of Contents

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K
ANNUAL REPORT PURSUANT TO SECTIONS 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED SEPTEMBER 30, 2021
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)
(610337-1000
(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 valueUGINew York Stock Exchange
Corporate UnitsUGICNew York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes No
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes No
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 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 such files). Yes No
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a 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 filerAccelerated filerNon-accelerated filer
Smaller reporting companyEmerging 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 has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report.
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes No
The aggregate market value of UGI Corporation Common Stock held by non-affiliates of the registrant on March 31, 2021 was $8,512,319,963.
At November 12, 2021, there were 209,221,695 shares of UGI Corporation Common Stock issued and outstanding.
Portions of the Proxy Statement for the Annual Meeting of Shareholders to be held on January 28, 2022 are incorporated by reference into Part III of this Form 10-K.


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Table of Contents
GLOSSARY OF TERMS AND ABBREVIATIONS
 
Terms and abbreviations used in this Form 10-K 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, together with its consolidated subsidiaries, as the “Partnership”

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

AmeriGas Propane Holdings, Inc. - A Delaware corporation and an indirect wholly owned subsidiary of UGI

AmeriGas Propane Holdings, LLC - A Delaware limited liability company and an indirect wholly-owned subsidiary of UGI; also referred to as the “Merger Sub”

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, Inc.’s regulated electric distribution utility

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

Enterprises - UGI Enterprises, LLC, a wholly owned 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, Inc.’s regulated natural gas distribution business

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

GHI - GHI Energy, LLC, a Houston-based renewable natural gas company and indirect wholly owned subsidiary of Energy Services

HVAC - UGI HVAC Enterprises, Inc., a wholly owned subsidiary of Enterprises

Merger Sub - AmeriGas Propane Holdings, LLC, an indirect wholly owned subsidiary of UGI

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

Mountaineer - Mountaineer Gas Company, a natural gas distribution company in West Virginia and an indirect wholly owned subsidiary of Mountaintop Energy Holdings LLC

Mountaintop Energy Holdings, LLC - Indirect parent company of Mountaineer and wholly owned subsidiary of UGI, acquired on September 1, 2021

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

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

PennEast - PennEast Pipeline Company, LLC

Pine Run - Pine Run Gathering, LLC

UGI - UGI Corporation or, collectively, UGI Corporation and its consolidated subsidiaries

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 subsidiary of Enterprises

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

UGI Pine Run, LLC - A wholly owned subsidiary of Energy Services that holds a 49% membership interest in Pine Run

UGI Utilities - Reportable segment comprising UGI Utilities, Inc. and Mountaintop Energy Holdings, LLC

UGI Utilities, Inc. - A wholly owned subsidiary of UGI comprising Gas Utility and Electric Utility

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

2013 OICP - UGI Corporation 2013 Omnibus Incentive Compensation Plan

1.59% Senior Note - A private placement of $100 million principal amount of senior notes due June 2026, issued by UGI Utilities, Inc.

1.64% Senior Note - A private placement of $75 million principal amount of senior notes due September 2026, issued by UGI Utilities, Inc.

2021 IAP - UGI Corporation 2021 Incentive Award Plan

2021 UGI Corporation Senior Credit Facility - An amended unsecured senior facilities agreement entered into on May 4, 2021, by UGI which extended the maturity date of the previous three-year $300 million loan term facility included in the UGI Corporation Senior Credit Facility, now due in May 2025 and includes a new four-year $215 million term loan commitment

2024 Purchase Contract - A forward stock purchase contract issued by UGI Corporation as a part of the issuance of Equity Units which obligates holders to purchase a number of shares of UGI common stock from the Company on June 1, 2024

ABO - Accumulated Benefit Obligation

ACE - AmeriGas Cylinder Exchange

Act 11 - Act 11 of 2012

Adjusted LIBOR - A rate derived from LIBOR

AEPS Act - Alternative Energy Portfolio Standards Act
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AFUDC - Allowance for Funds Used During Construction

AmeriGas Merger - The transaction contemplated by the Merger Agreement pursuant to which AmeriGas Propane Holdings, LLC merged with and into the Partnership, on August 21, 2019, with the Partnership surviving as an indirect wholly owned subsidiary of UGI

AmeriGas OLP Credit Agreement - The second amended and restated credit agreement entered into by AmeriGas OLP providing for borrowings of up to $600 million, including a letter of credit subfacility of up to $150 million

AOCI - Accumulated Other Comprehensive Income (Loss)

ASC - Accounting Standards Codification

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

ASC 740 - ASC 740, “Income Taxes”

ASC 805 - ASC 805, “Business Combinations”

ASC 820 - ASC 820, “Fair Value Measurement”

ASC 842 - ASC 842, “Leases” (effective October 1, 2019)

ASC 980 - ASC 980, “Regulated Operations”

ASU - Accounting Standards Update

Bcf - Billions of cubic feet

BIE - Pennsylvania Public Utility Commission Bureau of Investigation and Enforcement

Board of Directors - The board of directors of UGI

Btu - British thermal unit

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

CDC - Centers for Disease Control and Prevention

CERCLA - Comprehensive Environmental Response, Compensation and Liability Act

CFTC - Commodity Futures Trading Commission

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

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Common Units - Limited partnership ownership interests in AmeriGas Partners

Conemaugh - Conemaugh generation station, a 1,711-megawatt, coal-fired electricity generation station located near Johnstown, Pennsylvania

Convertible Preferred Stock - Preferred stock of UGI titled 0.125% series A cumulative perpetual convertible preferred stock without par value and having a liquidation preference of $1,000 per share

Core market - Comprises (1) firm residential, commercial and industrial customers to whom UGI Utilities has a statutory obligation to provide service who purchase their natural gas or electricity from UGI Utilities; and (2) residential, commercial and industrial customers to whom UGI Utilities has a statutory obligation to provide service who purchase their natural gas or electricity from others

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

DOT - U.S. Department of Transportation

DS - Default service        

DSIC - Distribution System Improvement Charge

EBITDA - Earnings before interest expense, income taxes, depreciation, and amortization

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

Energy Services Credit Agreement - Third amended and restated credit agreement entered into by Energy Services, as borrower, providing for borrowings up to $260 million, including a letter or credit subfacility of up to $50 million, scheduled to expire in March 2025

Energy Services Term Loan - A seven-year $700 million senior secured term loan agreement entered into on August 13, 2019, with a group of lenders

EPA - Environmental Protection Agency

EPACT 2005 - Energy Policy Act of 2005

ERISA - Employee Retirement Income Security Act of 1974

ERO - Electric Reliability Organization

EU - European Union

Equity Unit Agreements - Collection of agreements governing the rights, privileges and obligations of the holders of the Equity Units and UGI as issuer of the Equity Units, which were filed with the SEC on Form 8-K on May 25, 2021

Equity Unit - A corporate unit consisting of a 2024 Purchase Contract and 1/10th or 10% undivided interest in one share of Convertible Preferred Stock

Exchange Act - Securities Exchange Act of 1934, as amended

FASB - Financial Accounting Standards Board

FDIC - Federal Deposit Insurance Corporation

FERC - Federal Energy Regulatory Commission

FIFO - First-in, first-out inventory valuation method

Fiscal 2018 - The fiscal year ended September 30, 2018
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Fiscal 2019 - The fiscal year ended September 30, 2019

Fiscal 2020 - The fiscal year ended September 30, 2020

Fiscal 2021 - The fiscal year ended September 30, 2021

Fiscal 2022 - The fiscal year ending September 30, 2022

Fiscal 2023 - The fiscal year ending September 30, 2023

Fiscal 2024 - The fiscal year ending September 30, 2024

Fiscal 2025 - The fiscal year ending September 30, 2025

Fiscal 2026 - The fiscal year ending September 30, 2026

GAAP - U.S. generally accepted accounting principles

GDPR - General Data Protection Regulation

GHG - Greenhouse gas

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 Service

IT - Information technology

LIBOR - London Inter-bank Offered Rate

LNG - Liquefied natural gas

LPG - Liquefied petroleum gas

LTIIP - Long-term infrastructure improvement plans

MD&A - Management’s Discussion and Analysis of Financial Condition and Results of Operations

MDPSC - Maryland Public Service Commission

Merger Agreement - Agreement and Plan of Merger, dated as of April 1, 2019, among UGI, AmeriGas Propane Holdings, Inc., AmeriGas Propane Holdings, LLC, AmeriGas Partners and AmeriGas Propane

MGP - Manufactured gas plant

Mountaineer Acquisition - Acquisition of Mountaintop Energy Holdings LLC, which closed on September 1, 2021

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Mountaineer Credit Agreement - Third amended and restated credit agreement entered into by Mountaineer, as borrower, providing for borrowings up to $100 million, with the option to increase to a maximum principal amount of $200 million assuming certain conditions are met, including a letter or credit subfacility of up to $20 million, scheduled to expire in November 2024

NAV - Net asset value

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

OSHA - Occupational Safety and Health Act

PADEP - Pennsylvania Department of Environmental Protection

PAPUC - Pennsylvania Public Utility Commission

Partnership Agreement - Fourth amended and restated agreement of Limited Partnership of AmeriGas Partners, L.P. dated as of July 27, 2009, as amended

PBO - Projected benefit obligation

PennEnergy - PennEnergy Resources, LLC

PGA - Purchased gas adjustment

PGC - Purchased gas costs

PJM - PJM Interconnection, LLC

PRP - Potentially Responsible Party

PUHCA 2005 - Public Utility Holding Company Act of 2005

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 UGI Utilities

RNG - Renewable natural gas

ROU - Right-of-use

ROD - Record of Decision

SCAA - Storage Contract Administrative Agreements

SEC - U.S. Securities and Exchange Commission

Series B preferred stock - Preferred stock of UGI titled 0.125% series B cumulative perpetual preferred stock with terms substantially identical to the Convertible Preferred Stock, except that it will not be convertible

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Stonehenge - Stonehenge Energy Resources III, LLC, a portfolio company of Energy Spectrum Partners VIII, L.P.

Stock Unit - Unit awards that entitle the grantee to shares of UGI Common Stock or cash subject to service conditions

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

TSR - Total Shareholder Return

UGI comparator group - The Russell Midcap Utility Index, excluding telecommunications companies

UGI Corporation Senior Credit Facility - An unsecured senior facilities agreement entered into on August 1, 2019, by UGI comprising (1) a five-year $250 million term loan facility; (2) a three-year $300 million term loan facility; and (3) a five-year $300 million revolving credit facility (including a $10 million sublimit for letters of credit)

UGI International 3.25% Senior Notes - An underwritten private placement of €350 million principal amount of senior unsecured notes due November 1, 2025, issued by UGI International, LLC

UGI International Credit Facilities Agreement - A five-year unsecured senior facilities agreement entered into in October 2018, by UGI International, LLC comprising a €300 million term loan facility and a €300 million revolving credit facility, scheduled to expire in October 2023

UGI Performance Units - Unit awards that entitle the grantee to shares of UGI Common Stock or cash subject to service and market performance conditions

UGI Utilities, Inc. Credit Agreement - A five-year unsecured revolving credit agreement entered into by UGI Utilities, Inc. on June 27, 2019, providing for borrowings up to $350 million, including a letter of credit subfacility of up to $100 million, scheduled to expire in June 2024

Units or Unit Awards - UGI Corporation stock options, grants of UGI Corporation stock-based equity instruments and, prior to the AmeriGas Merger, grants of AmeriGas Partners, L.P. equity instruments (together with UGI Corporation stock-based equity instruments)

USD - U.S. dollar

U.S. Pension Plans – Consists of (1) a defined benefit pension plan for employees hired prior to January 1, 2009 of UGI, UGI Utilities, Inc. and certain of UGI’s other domestic wholly owned subsidiaries; and (2) a defined benefit pension plan for substantially all Mountaineer employees

Utilities Term Loan - A $125 million unsecured variable-rate term loan agreement entered into in September 2018 by UGI Utilities, Inc. with a group of banks

VEBA - Voluntary Employees’ Beneficiary Association

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

WHO - World Health Organization

WVPSC - Public Service Commission of West Virginia
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FORWARD-LOOKING INFORMATION

Information contained in this Annual Report on Form 10-K may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. 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 our Risk Factors included in Item 1A herein and 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, and environmental matters, such as 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 and our ability to address existing or potential workforce shortages; (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, 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, and those of our third-party vendors or service providers, 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; (25) the impact of proposed or future tax legislation, including the potential reversal of existing tax legislation that is beneficial to us; and (26) our ability to overcome supply chain issues that may result in delays or shortages in, as well as increased costs of, equipment, materials or other resources that are critical to our business operations.

These factors 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.

PART I:

ITEMS 1. AND 2. BUSINESS AND PROPERTIES
CORPORATE OVERVIEW

UGI Corporation 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) energy marketing (including RNG), midstream infrastructure, storage, natural gas gathering and processing, natural gas production, electricity generation and energy services businesses. In
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Europe, we market and distribute LPG and other energy products and services. Our subsidiaries and affiliates operate principally in the following four business segments:

AmeriGas Propane
UGI International
Midstream & Marketing
UGI Utilities

The AmeriGas Propane segment consists of the propane distribution business of AmeriGas Partners, an indirect wholly owned subsidiary of UGI Corporation. The Partnership conducts its propane distribution business through its principal operating subsidiary, AmeriGas Propane, L.P., and is the nation’s largest retail propane distributor based on the volume of propane gallons distributed annually. The general partner of AmeriGas Partners is our wholly owned subsidiary, AmeriGas Propane, Inc.

The UGI International segment consists of LPG distribution businesses conducted by our subsidiaries and affiliates in Austria, Belgium, the Czech Republic, Denmark, Finland, France, Hungary, Italy, Luxembourg, the Netherlands, Norway, Poland, Romania, Slovakia, Sweden, Switzerland and the United Kingdom. In addition, UGI International conducts an energy marketing business in France, Belgium, the Netherlands and the United Kingdom. Based on market volumes for 2020, which is the most recent information available, UGI International believes that it is the largest distributor of LPG in France, Austria, Belgium, Denmark, Luxembourg, Norway and Hungary and one of the largest distributors of LPG in Poland, the Czech Republic, Slovakia, the Netherlands and Sweden.

The Midstream & Marketing segment consists of energy-related businesses conducted by our indirect, wholly owned subsidiary, UGI Energy Services, LLC. These businesses (i) conduct energy marketing, including RNG, in the Mid-Atlantic region of the United States and California, (ii) own and operate natural gas liquefaction, storage and vaporization facilities and propane-air mixing assets, (iii) manage natural gas pipeline and storage contracts, (iv) develop, own and operate pipelines, gathering infrastructure and gas storage facilities in the Marcellus and Utica Shale regions of Pennsylvania, eastern Ohio, and the panhandle of West Virginia, (v) own electricity generation facilities, and (vi) own RNG production facilities. Energy Services and its subsidiaries’ storage, LNG and portions of its midstream transmission operations are subject to regulation by the FERC.

The UGI Utilities segment consists of the regulated natural gas and electric distribution businesses of our wholly owned subsidiary, UGI Utilities, Inc. (“Gas Utility” and “Electric Utility,” respectively), and the regulated natural gas distribution business of our indirect, wholly owned subsidiary, Mountaineer Gas Company (“Mountaineer”). Gas Utility serves approximately 672,000 customers in eastern and central Pennsylvania and more than 500 customers in portions of one Maryland county. Mountaineer serves nearly 214,000 customers across 50 of West Virginia’s 55 counties. Electric Utility serves approximately 62,500 customers in portions of Luzerne and Wyoming counties in northeastern Pennsylvania. Gas Utility is subject to regulation by the PAPUC and FERC and, with respect to its customers in Maryland, the MDPSC. Mountaineer is subject to regulation by the WVPSC and FERC. Electric Utility is subject to regulation by the PAPUC and FERC.

Business Strategy

Our business strategy is to grow the Company by focusing on our core competencies of distributing, storing, transporting and marketing energy products and services. We utilize our core competencies from our existing diversified businesses and our international experience, extensive asset base and access to customers to accelerate both organic growth and growth through acquisitions in our existing businesses, as well as in related and complementary businesses.

In Fiscal 2021, we identified and communicated to our investors three key elements that we believe will advance our strategy: (1) providing reliable earnings growth; (2) investing in renewable energy solutions; and (3) rebalancing our portfolio, with an emphasis on natural gas and renewable energy solutions. The following discussion highlights some of our key accomplishments in these areas during Fiscal 2021.

Reliable Earnings Growth

We are committed to consistently growing our earnings and plan to continue this growth through increased investments in our regulated utilities business, generating significant fee-based income in our Midstream and Marketing operations, and investing in high-growth and more weather resilient markets at our LPG businesses.

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In September 2021, we completed the acquisition of Mountaineer Gas Company, the largest gas local distribution company in West Virginia. Mountaineer serves nearly 214,000 customers across 50 of West Virginia’s 55 counties and has a customer base that is approximately 90% residential and 10% commercial and industrial. We expect the addition of Mountaineer to significantly increase our rate base initially, with additional rate base growth anticipated over the longer term.

Our Midstream and Marketing business continues to provide a stable earnings stream, which is underpinned by fee-based contracts from customers. This fee-based income is derived from fixed fee peaking, storage and gathering, and fixed rate, variable volume gathering and marketing transactions. In Fiscal 2021, approximately 87% of Midstream and Marketing’s total margin was fee-based.

In Fiscal 2021, AmeriGas Propane continued to expand its Cynch propane home delivery service into twenty-two cities as of September 30, 2021 and plans to introduce Cynch into additional U.S. markets in Fiscal 2022 and Fiscal 2023. Similarly, UGI International offers propane cylinder vending machines in several European countries and plans to expand into additional markets in the near term. These programs are convenient for customers, and we believe they will position us for growth in the near future.

AmeriGas Propane and UGI International also continued to execute on multi-year business transformation initiatives designed to improve long-term operational performance by, among other things, reducing costs and improving efficiency and effectiveness in a number of key areas. These transformation activities are substantially complete and are expected to provide total annual benefits to AmeriGas Propane and UGI International of more than $150 million and €30 million, respectively, by the end of Fiscal 2022. For further information on these initiatives, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Executive Overview - Strategic Initiatives.”

Finally, our natural gas businesses completed a number of transactions in the renewable energy space, which we believe will further contribute to our earnings growth. For more information on these transactions, see “Investment in Renewable Energy” below.

Investment in Renewable Energy

We are pursuing investments in a number of key renewable energy areas, including RNG, bio-LPG and renewable dimethyl ether (“rDME”), among others. Our natural gas businesses are actively exploring RNG opportunities involving both distribution and RNG feedstock infrastructure, and our LPG businesses are developing bio-LPG sources to augment our existing bio-LPG source in Sweden. We believe that UGI is particularly well-positioned to develop investment opportunities in these rapidly emerging markets due to our competencies in project development, project execution, gas transportation and storage, and energy marketing.

We expect to utilize our existing natural gas and LPG distribution infrastructure to deliver RNG and bio-LPG to the customers we serve. In most cases, these renewable solutions can be delivered to our customers with no additional local infrastructure, incremental investments by our customers, or community disruption related to infrastructure buildout.

In Fiscal 2021, we completed the following transactions, which we believe will provide a foundation for growth within the renewable energy space:

Energy Services invested in a joint venture to develop dairy farm digester projects that produce RNG in upstate New York. The first project, announced in May 2021, incorporates an existing anaerobic digester that generates biogas, which is used to produce renewable electricity, and is expected to be completed in the second half of calendar year 2022. The second project, announced in September 2021, includes the construction of an anaerobic digester and a combined heat and power project that are expected to produce 85 million cubic feet (“MMcf”) of RNG each year once completed in the second half of calendar year 2022.

In September 2021, Energy Services announced that it would partially fund a joint venture designed to develop several clusters of dairy farm digester projects to produce RNG from multiple farms in South Dakota. The clusters of projects, which Energy Services will have the option to fund on a project-by-project basis, are expected to produce 650 MMcf of RNG annually when complete and on-line by the end of calendar year 2024. The RNG will be delivered to the local natural gas pipelines serving the regional distribution system.

In August 2021, Energy Services invested in a joint venture to develop innovative food waste digester projects to produce RNG in Ohio and Kentucky. The first digester project is expected to be completed in the first half of calendar 2023 and will process approximately 190,000 tons annually of food waste from nearby food manufacturers in an
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anaerobic digester. The project is expected to generate approximately 250,000 MMBTUs of pipeline-quality RNG each year that will be injected into a local natural gas pipeline on the regional distribution system.

In May 2021, UGI International announced its intention to launch a joint venture to advance the production and use of rDME, a low-carbon sustainable liquid gas, in the LPG industry. The parties anticipate the development of up to six production plants within the next five years, targeting a total production capacity of 300 kilotons of rDME per year by 2027.

In February 2021, UGI Utilities, Inc. entered an RNG interconnect agreement with a landfill gas developer in northeast Pennsylvania. When fully operational, the system is designed to take up to 16 MMcf per day of RNG supply at a rate of up to 780 thousand cubic feet (“Mcf”) per hour.

In February 2021, UGI International entered a supply and development partnership with a Polish technology specialist in catalytic conversion of bioethanol to bio-gasoline and bioLPG for the exclusive rights to its supply of bioLPG. We believe this is a significant step in reducing UGI International’s carbon footprint and achieving its decarbonization targets.

In November 2020, Energy Services invested in a utility-scale RNG project in Idaho. The project is expected to produce several hundred MMcf of RNG each year from on-site dairy waste feedstock once it is expanded to reach full production in 2022.

These projects provide a range of benefits, including reducing our carbon footprint while also addressing increased customer demand for low carbon energy sources, and we expect to continue to expand our renewable energy investments over the next five years.

Rebalancing Our Portfolio

In Fiscal 2019, we completed the AmeriGas Merger, whereby AmeriGas Partners, L.P. became a wholly owned subsidiary of UGI Corporation. Following this transaction, our LPG businesses have contributed to our earnings per share at a greater percentage than our natural gas businesses. We plan to rebalance our portfolio through both organic growth and investment in natural gas and renewable energy solutions.

In Fiscal 2021, we executed on our rebalancing strategy through several transactions and investments, including the Mountaineer Acquisition and the aforementioned investments in renewable energy. In addition to these transactions and investments, UGI Utilities, Inc. continued to execute on its infrastructure replacement and system betterment program, with record capital expenditures in Fiscal 2021 and additional expenditures expected in the coming years. UGI Utilities, Inc. remains on schedule to achieve its goal of replacing the cast iron portions of its gas mains by March 2027 and the bare steel portion of its gas mains by September 2041. We believe that the replacement of aging infrastructure results in increased contributions to rate base growth and also reduces emissions while improving operational efficiency.

Environmental Strategy

In Fiscal 2021, UGI pledged to reduce its enterprise Scope 1 GHG emissions by 55% over the next five years (using Fiscal 2020 as a baseline), while committing to continue to grow our earnings per share and dividends. We believe we can accomplish this objective through a three-pronged strategy that focuses on:

reducing our emissions through investment in infrastructure and more efficient operations;
reducing our customers’ emissions through conversions, energy efficiency programs and fleet conversions; and
investing in alternative energy solutions (such as renewable energy) to reduce GHG emissions and provide low or zero carbon solutions to our customers.

We report our progress on environmental goals and commitments annually in our Sustainability Reports, including our Scope 1 and 2 emissions, air quality impact, and water management efforts. Our Sustainability Reports may be accessed on our website under “ESG - Resources - Sustainability Reports.” Information published in our Sustainability Reports is not intended to be incorporated into this Report.

In formulating our environmental strategy, our management and Board of Directors consider certain risks and uncertainties that may materially impact our financial condition and results of operations. For more information on these risks and uncertainties,
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see “Risk Factors - The potential effects of climate change may affect our business, operations, supply chain and customers, which could adversely impact our financial condition and results of operations.

Corporate Information

UGI was incorporated in Pennsylvania in 1991. The Company is not subject to regulation by the PAPUC but, following completion of the Mountaineer Acquisition, is a regulated “holding company” under PUHCA 2005. PUHCA 2005 and the implementing regulations of FERC give FERC access to certain holding company books and records and impose certain accounting, record-keeping, and reporting requirements on holding companies. PUHCA 2005 also provides state utility regulatory commissions with access to holding company books and records in certain circumstances.

Our executive offices are located at 460 North Gulph Road, King of Prussia, Pennsylvania 19406, and our telephone number is (610) 337-1000. In this report, the terms “Company” and “UGI,” as well as the terms “our,” “we,” “us,” and “its” are sometimes used as abbreviated references to UGI Corporation or, collectively, UGI Corporation and its consolidated subsidiaries. For further information on the meaning of certain terms used in this Report, see “Glossary of Terms and Abbreviations.”

The Company’s corporate website can be found at www.ugicorp.com. Information on our website, including the information published in our Sustainability Reports, is not intended to be incorporated into this Report. The Company makes available free of charge at this website (under the “Investors - Financial Reports - SEC Filings and Proxies” caption) copies of its reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act, including its Annual Reports on Form 10-K, its Quarterly Reports on Form 10-Q and its Current Reports on Form 8-K. The Company’s Principles of Corporate Governance and Code of Business Conduct and Ethics are available on the Company’s website under the caption “Company - Leadership and Governance - Governance Documents.” The charters of the Audit, Corporate Governance, Compensation and Management Development, Pension, and Safety, Environmental and Regulatory Compliance Committees of the Board of Directors are available on the Company’s website under the caption “Company - Leadership and Governance - Committees & Charters.” All of these documents are also available free of charge by writing to Director, Investor Relations, UGI Corporation, P.O. Box 858, Valley Forge, PA 19482.

AMERIGAS PROPANE

Products, Services and Marketing

Our domestic propane distribution business is conducted through AmeriGas Propane. AmeriGas Propane serves nearly 1.4 million customers in all 50 states from approximately 1,600 propane distribution locations. Typically, propane distribution locations are in suburban and rural areas where natural gas is not readily available. Our local offices generally consist of operations facilities and propane storage. As part of its overall transportation and distribution infrastructure, AmeriGas Propane operates as an interstate carrier in all states throughout the continental U.S.

AmeriGas Propane sells propane primarily to residential, commercial/industrial, motor fuel, agricultural and wholesale customers. AmeriGas Propane distributed approximately 1.1 billion gallons of propane in Fiscal 2021. Approximately 88% of AmeriGas Propane’s Fiscal 2021 sales (based on gallons sold) was to retail accounts and approximately 12% was to wholesale and supply customers. Sales to residential customers in Fiscal 2021 represented approximately 32% of retail gallons sold; commercial/industrial customers 41%; motor fuel customers 19%; and agricultural customers 4%. Transport gallons, which are large-scale deliveries to retail customers other than residential, accounted for 4% of Fiscal 2021 retail gallons. No single customer represents, or is anticipated to represent, more than 5% of AmeriGas Propane’s consolidated revenues.

The ACE program continued to be an important element of AmeriGas Propane’s business in Fiscal 2021. At September 30, 2021, ACE cylinders were available at over 50,000 retail locations throughout the U.S. Sales of our ACE cylinders to retailers are included in commercial/industrial sales. The ACE program enables consumers to purchase or exchange propane cylinders at various retail locations such as home centers, gas stations, mass merchandisers and grocery and convenience stores. In addition, in Fiscal 2021, we continued to expand our Cynch propane home delivery service, which is now available in twenty-two cities as of September 30, 2021, and plan to expand into additional markets in Fiscal 2022 and Fiscal 2023. We also supply retailers with large propane tanks to enable them to replenish customers’ propane cylinders directly at the retailer’s location.

Residential and commercial customers use propane primarily for home heating, water heating and cooking purposes. Commercial users include hotels, restaurants, churches, warehouses, and retail stores. Industrial customers use propane to fire furnaces, as a cutting gas and in other process applications. Other industrial customers are large-scale heating accounts and
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local gas utility customers that use propane as a supplemental fuel to meet peak load deliverability requirements. As a motor fuel, propane is burned in internal combustion engines that power school buses and other over-the-road vehicles, forklifts, and stationary engines. Agricultural uses include tobacco curing, chicken brooding, crop drying, and orchard heating. In its wholesale operations, AmeriGas Propane principally sells propane to large industrial end-users and other propane distributors.

Retail deliveries of propane are usually made to customers by means of bobtail and rack trucks. Propane is pumped from the bobtail truck, which generally holds 2,400 to 3,000 gallons of propane, into a stationary storage tank on the customer’s premises. AmeriGas Propane owns most of these storage tanks and leases them to its customers. The capacity of these tanks ranges from approximately 120 gallons to approximately 1,200 gallons. AmeriGas Propane also delivers propane in portable cylinders, including ACE and motor fuel cylinders. Some of these deliveries are made to the customer’s location, where cylinders are either picked up or replenished in place.

During Fiscal 2021, we made technology and other investments to promote the safety of our employees and the communities we serve. For example, (i) we continued installing cameras in our delivery and service vehicles to facilitate in-cab coaching capabilities, among other functionality and (ii) we continued to install fall protection towers on rail terminals that are designed to prevent employees from falling during the process of offloading propane into bulk storage.

Moreover, in Fiscal 2021, AmeriGas Propane continued executing on multi-year business transformation initiatives designed to improve long-term operational performance by, among other things, reducing costs and improving 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. These transformation activities are substantially complete and are expected to provide total annual benefits of more than $150 million by the end of Fiscal 2022. For further information on these initiatives, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Executive Overview - Strategic Initiatives.”

Propane Supply and Storage

The U.S. propane market has more than 180 domestic and international sources of supply, including the spot market. Supplies of propane from AmeriGas Propane’s sources historically have been readily available; however, beginning in April 2020 and continuing through Fiscal 2021, certain geographies experienced varying levels of reduced propane availability as a result of COVID-19 and transportation issues within the supply chain. While some refineries have returned to normal production, others have ceased operations entirely. In response to these supply and transportation challenges, AmeriGas Propane utilized a combination of increased regional storage as well as rail and transport supply from different origins to offset localized supply/demand imbalances that occurred during Fiscal 2021.

In addition to these factors, the availability and pricing of propane supply has historically been dependent upon, among other things, the severity of winter weather, the price and availability of competing fuels such as natural gas and crude oil, and the amount and availability of exported supply and, to a much lesser extent, imported supply. For more information on risks relating to our supply chain, see “Risk Factors - Risks Relating to Our Supply Chain and Our Ability to Obtain Adequate Quantities of LPG.”

During Fiscal 2021, approximately 98% of AmeriGas Propane’s propane supply was purchased under supply agreements with terms of one to three years. Although no assurance can be given that supplies of propane will be readily available in the future, management currently expects to be able to secure adequate supplies during Fiscal 2022. If supply from major sources were interrupted, however, the cost of procuring replacement supplies and transporting those supplies from alternative locations might be materially higher and, at least on a short-term basis, margins could be adversely affected. In Fiscal 2021, AmeriGas Propane derived approximately 11% of its propane supply from each of Enterprise Products Operating LLC and Targa Liquids Marketing and Trade. No other single supplier provided more than 10% of AmeriGas Propane’s total propane supply in Fiscal 2021. In certain geographic areas, however, a single supplier provides more than 50% of AmeriGas Propane’s requirements. Disruptions in supply in these areas could also have an adverse impact on AmeriGas Propane’s margins.

AmeriGas Propane’s supply contracts typically provide for pricing based upon (i) index formulas using the current prices established at a major storage point such as Mont Belvieu, Texas, or Conway, Kansas, or (ii) posted prices at the time of delivery. In addition, some agreements provide maximum and minimum seasonal purchase volume guidelines. The percentage of contract purchases, and the amount of supply contracted for at fixed prices, will vary from year to year. AmeriGas Propane uses a number of interstate pipelines, as well as railroad tank cars, delivery trucks and barges, to transport propane from suppliers to storage and distribution facilities. AmeriGas Propane stores propane at various storage facilities and terminals located in strategic areas across the U.S.
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Because AmeriGas Propane’s profitability is sensitive to changes in wholesale propane costs, AmeriGas Propane generally seeks to pass on increases in the cost of propane to customers. There is no assurance, however, that AmeriGas Propane will always be able to pass on product cost increases fully, or keep pace with such increases, particularly when product costs rise rapidly. Product cost increases can be triggered by periods of severe cold weather, supply interruptions, increases in the prices of base commodities such as crude oil and natural gas, or other unforeseen events. AmeriGas Propane has supply acquisition and product cost risk management practices to reduce the effect of volatility on selling prices. These practices currently include the use of summer storage, forward purchases and derivative commodity instruments, such as propane price swaps. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Market Risk Disclosures.”

The following graph shows the average prices of propane on the propane spot market during the last five fiscal years at Mont Belvieu, Texas, and Conway, Kansas, both major storage areas.
Average Propane Spot Market Prices
https://cdn.kscope.io/90968a42528af0c6146eec512c4c8dc4-ugi-20210930_g1.jpg

General Industry Information

Propane is separated from crude oil during the refining process and also extracted from natural gas or oil wellhead gas at processing plants. Propane is normally transported and stored in a liquid state under moderate pressure or refrigeration for economy and ease of handling in shipping and distribution. When the pressure is released or the temperature is increased, it is usable as a flammable gas. Propane is colorless and odorless; an odorant is added to allow for its detection. Propane is considered a clean alternative fuel under the Clean Air Act Amendments of 1990, producing negligible amounts of pollutants when properly consumed.

Competition

Propane competes with other sources of energy, some of which are less costly for equivalent energy value. Propane distributors compete for customers with suppliers of electricity, fuel oil and natural gas, principally on the basis of price, service, availability and portability. Electricity is generally more expensive than propane on a Btu equivalent basis, but the convenience and efficiency of electricity make it an attractive energy source for consumers and developers of new homes. Fuel oil, which is also a major competitor of propane, is currently more expensive than propane and is a less environmentally attractive energy source. Furnaces and appliances that burn propane will not operate on fuel oil, and vice versa, and, therefore, a conversion from one fuel to the other requires the installation of new equipment. Propane serves as an alternative to natural gas in rural and suburban areas where natural gas is unavailable or portability of product is required. Natural gas is generally a significantly less expensive source of energy than propane, although in areas where natural gas is available, propane is used for certain industrial and commercial applications and as a standby fuel during interruptions in natural gas service. The gradual expansion of the nation’s natural gas distribution systems has resulted in the availability of natural gas in some areas that previously depended upon propane. However, natural gas pipelines are not present in many areas of the country where propane is sold for
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heating and cooking purposes.

For motor fuel customers, propane competes with gasoline, diesel fuel, electric batteries, fuel cells and, in certain applications, LNG and compressed natural gas. Wholesale propane distribution is a highly competitive, low margin business. Propane sales to other retail distributors and large-volume, direct-shipment industrial end-users are price sensitive and frequently involve a competitive bidding process.

Retail propane industry volumes have been declining for several years and no or modest growth in total demand is foreseen in the next several years. Therefore, AmeriGas Propane’s ability to grow within the industry is dependent on the success of its sales and marketing programs designed to attract and retain customers, the success of business transformation initiatives, its ability to achieve internal growth, which includes expansion of the ACE, Cynch and National Accounts programs (through which multi-location propane users enter into a single AmeriGas Propane supply agreement rather than agreements with multiple suppliers), and its ability to acquire other retail distributors. The failure of AmeriGas Propane to retain and grow its customer base would have an adverse effect on its long-term results.

The domestic propane retail distribution business is highly competitive. AmeriGas Propane competes in this business with other large propane marketers, including other full-service marketers, and thousands of small independent operators. Some farm cooperatives, rural electric cooperatives and fuel oil distributors include propane distribution in their businesses and AmeriGas Propane competes with them as well. The ability to compete effectively depends on providing high quality customer service, maintaining competitive retail prices and controlling operating expenses. AmeriGas Propane also offers customers various payment and service options, including guaranteed price programs, fixed price arrangements and pricing arrangements based on published propane prices at specified terminals.

In Fiscal 2021, AmeriGas Propane’s retail propane sales totaled nearly 970 million gallons. Based on the most recent annual survey by the Propane Education & Research Council, 2019 domestic retail propane sales (annual sales for other than chemical uses) in the U.S. totaled approximately 10.1 billion gallons. Based on LP-GAS magazine rankings, 2019 sales volume of the ten largest propane distribution companies (including AmeriGas Propane) represented approximately 31% of domestic retail propane sales.

Properties

As of September 30, 2021, AmeriGas Propane owned 87% of its approximately 530 local offices throughout the country. The transportation of propane requires specialized equipment. The trucks and railroad tank cars utilized for this purpose carry specialized steel tanks that maintain the propane in a liquefied state. As of September 30, 2021, the Partnership operated a transportation fleet with the following assets:
Approximate Quantity & Equipment Type% Owned% Leased
880Trailers71%29%
340Tractors5%95%
680Railroad tank cars0%100%
2,470Bobtail trucks9%91%
320Rack trucks12%88%
2,950Service and delivery trucks15%85%

Other assets owned at September 30, 2021 included approximately 960,000 stationary storage tanks with typical capacities of more than 120 gallons, approximately 4.1 million portable propane cylinders with typical capacities of 1 to 120 gallons, 21 terminals and 12 transflow units.

Trade Names, Trade and Service Marks
AmeriGas Propane markets propane and other services principally under the “AmeriGas®,” “America’s Propane Company®,” “Propane That’s Pro-You℠” and “Cynch®” trade names and related service marks and continues to maintain the “Driving Every Day®” and “Relationships Matter®” trademarks. UGI owns, directly or indirectly, all the right, title and interest in the “AmeriGas” name and related trade and service marks. The General Partner owns all right, title and interest in the “America’s Propane Company” trade name and related service marks. The Partnership has an exclusive (except for use by UGI, AmeriGas, Inc., AmeriGas Polska Sp. z.o.o. and the General Partner), royalty-free license to use these trade names and related service marks. UGI and the General Partner each have the option to terminate its respective license agreement (except its licenses with permitted transferees and on 12 months’ prior notice in the case of UGI), without penalty, if the General Partner is removed as
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general partner of the Partnership for cause. If the General Partner ceases to serve as the general partner of the Partnership other than for cause, the General Partner has the option to terminate its license agreement upon payment of a fee to AmeriGas Propane, L.P. equal to the fair market value of the licensed trade names. UGI has a similar termination option; however, UGI must provide 12 months’ prior notice in addition to paying the fee to AmeriGas OLP. UGI and the General Partner each also have the right to terminate its respective license agreement in order to settle any claim of infringement, unfair competition or similar claim or if the agreement has been materially breached without appropriate cure.

Seasonality

Because many customers use propane for heating purposes, AmeriGas Propane’s retail sales volume is seasonal. During Fiscal 2021, approximately 65% of the Partnership’s retail sales volume occurred, and substantially all of AmeriGas Propane’s operating income was earned, during the peak heating season from October through March. As a result of this seasonality, revenues are typically higher in AmeriGas Propane’s first and second fiscal quarters (October 1 through March 31). Cash receipts are generally greatest during the second and third fiscal quarters when customers pay for propane purchased during the winter heating season. As a result of the AmeriGas Merger, we expect that UGI will continue to derive a greater percentage of its earnings during the peak heating season of October through March. For more information on the risks associated with the seasonality of our business, see “Risk Factors - Our business is seasonal and decreases in the demand for our energy products and services because of warmer-than-normal heating season weather or unfavorable weather conditions may adversely affect our results of operations.”

Sales volume for AmeriGas Propane traditionally fluctuates from year-to-year in response to variations in weather, prices, competition, customer mix and other factors, such as conservation efforts and general economic conditions. For information on national weather statistics, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

Government Regulation

AmeriGas Propane is subject to various federal, state and local environmental, health, safety and transportation laws and regulations governing the storage, distribution and transportation of propane and the operation of bulk storage propane terminals.

Environmental

Generally, applicable environmental laws impose limitations on the discharge of pollutants, establish standards for the handling of solid and hazardous substances, and require the investigation and cleanup of environmental contamination. These laws include, among others, the Resource Conservation and Recovery Act, CERCLA, the Clean Air Act, the Clean Water Act, the Homeland Security Act of 2002, the Emergency Planning and Community Right-to-Know Act, comparable state statutes and any applicable amendments. The Partnership incurs expenses associated with compliance with its obligations under federal and state environmental laws and regulations, and we believe that the Partnership is in material compliance with its obligations. The Partnership maintains various permits that are necessary to operate its facilities, some of which may be material to its operations. AmeriGas Propane continually monitors its operations with respect to potential environmental issues, including changes in legal requirements.

AmeriGas Propane is investigating and remediating contamination at a number of present and former operating sites in the U.S., including sites where its predecessor entities operated manufactured gas plants. CERCLA and similar state laws impose joint and several liability on certain classes of persons considered to have contributed to the release or threatened release of a “hazardous substance” into the environment without regard to fault or the legality of the original conduct. Propane is not a hazardous substance within the meaning of CERCLA.

Health and Safety
AmeriGas Propane is subject to the requirements of OSHA and comparable state laws that regulate the protection of the health and safety of our workers. These laws require the Partnership, among other things, to maintain information about materials, some of which may be hazardous or toxic, that are used, released, or produced in the course of our operations. Certain portions of this information must be provided to employees, federal and state and local governmental authorities and responders, commercial and industrial customers and local citizens in accordance with applicable federal and state Emergency Planning and Community Right-to-Know Act requirements. AmeriGas Propane’s operations are also subject to federal safety hazard communication requirements and reporting obligations.

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All states in which AmeriGas Propane operates have adopted fire safety codes that regulate the storage, distribution, and use of propane. In some states, these laws are administered by state agencies, and in others they are administered on a municipal level. AmeriGas Propane conducts training programs to help ensure that its operations are in compliance with applicable governmental regulations. With respect to general operations, AmeriGas Propane is subject in all jurisdictions in which it operates to rules and procedures governing the safe handling of propane, including those established by National Fire Protection Association Pamphlets No. 54 and No. 58, various state, local and international codes (including international fire, building and fuel gas codes), and OSHA fall protection standards. Management believes that the policies and procedures currently in effect at all of its facilities for the handling, storage, distribution and use of propane, as well as its fall protection standards, are consistent with industry standards and are in compliance, in all material respects, with applicable laws and regulations.

With respect to the transportation of propane by truck, AmeriGas Propane is subject to regulations promulgated under federal legislation, including the Federal Motor Carrier Safety Act, the Hazardous Materials & Transportation Act and the Homeland Security Act of 2002. Regulations under these statutes cover the security and transportation of hazardous materials, including propane for purposes of these regulations, and are administered by the Pipeline and Hazardous Materials Safety Administration of the DOT. The Natural Gas Safety Act of 1968 required the DOT to develop and enforce minimum safety regulations for the transportation of gases by pipeline. The DOT's pipeline safety regulations apply to, among other things, a propane gas system that supplies 10 or more residential customers or two or more commercial customers from a single source and to a propane gas system any portion of which is located in a public place. The DOT’s pipeline safety regulations require operators of all gas systems to provide operator qualification standards and training and written instructions for employees and third party contractors working on covered pipelines and facilities, establish written procedures to minimize the hazards resulting from gas pipeline emergencies, and conduct and keep records of inspections and testing. Operators are subject to the Pipeline Safety Improvement Act of 2002. Management believes that the procedures currently in effect at all of AmeriGas Propane’s facilities for the handling, storage, transportation and distribution of propane are consistent with industry standards and are in compliance, in all material respects, with applicable laws and regulations.

Climate Change

There continues to be concern, both nationally and internationally, about climate change and the contribution of GHG emissions, most notably carbon dioxide, to global warming. Because propane is considered a clean alternative fuel under the federal Clean Air Act Amendments of 1990, the Partnership anticipates that this will provide it with a competitive advantage over other sources of energy, such as fuel oil and coal, to the extent new climate change regulations become effective. At the same time, increased regulation of GHG emissions, especially in the transportation sector, could impose significant additional costs on AmeriGas Propane, its suppliers, its vendors and its customers. In recent years, there has been an increase in state initiatives aimed at regulating GHG emissions. For example, the California Environmental Protection Agency established a Cap & Trade program that requires certain covered entities, including propane distribution companies, to purchase allowances to compensate for the GHG emissions created by their business operations. Compliance with these types of regulations may increase our operating costs if we are unable to pass on these costs to our customers.

Employees

The Partnership does not directly employ any persons responsible for managing or operating the Partnership. The General Partner provides these services and is reimbursed for its direct and indirect costs and expenses, including all compensation and benefit costs. At September 30, 2021, the General Partner had approximately 5,800 employees, including more than 100 part-time, seasonal and temporary employees, working on behalf of the Partnership. UGI also performs, and is reimbursed for, certain financial and administrative services on behalf of the Partnership and AmeriGas OLP.

UGI INTERNATIONAL

UGI International, through subsidiaries and affiliates, conducts (i) an LPG distribution business in 17 countries throughout Europe (Austria, Belgium, the Czech Republic, Denmark, Finland, France, Hungary, Italy, Luxembourg, the Netherlands, Norway, Poland, Romania, Slovakia, Sweden, Switzerland and the United Kingdom), and (ii) an energy marketing business in France, Belgium, the Netherlands and the United Kingdom. Based on market volumes for 2020, which is the most recent information available, UGI International believes that it is the largest distributor of LPG in France, Austria, Belgium, Denmark, Luxembourg, Norway and Hungary and one of the largest distributors of LPG in Poland, the Czech Republic, Slovakia, the Netherlands and Sweden.
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Products, Services and Marketing
LPG Distribution Business
During Fiscal 2021, UGI International sold more than 975 million gallons of LPG throughout Europe. UGI International operates under seven distinct LPG brands, and its customer base primarily consists of residential, commercial, industrial, agricultural, wholesale and automobile fuel (‘‘autogas’’) customers that use LPG for space heating, cooking, water heating, motor fuel, leisure activities, crop drying, irrigation, construction, power generation, manufacturing and as an aerosol propellant. For Fiscal 2021, 45% of UGI International’s LPG volume was sold to commercial and industrial customers, 19% was sold to residential, 11% was sold to agricultural and 25% was sold to wholesale and other customers (including autogas). UGI International supplies LPG to its customers in small, medium and large bulk tanks at their locations. In addition to bulk sales, UGI International sells LPG in cylinders through retail outlets, such as supermarkets, individually owned stores and gas stations and directly to businesses that operate LPG-powered forklifts. Sales of LPG are also made to service stations to fuel vehicles that run on LPG. Approximately 63% of Fiscal 2021 LPG sales (based on volumes) was attributed to bulk, 16% to cylinder, 19% to wholesale and 2% to autogas. For Fiscal 2021, no single customer represented more than 5% of UGI International’s revenues.
Bulk
UGI International classifies its bulk customers as small, medium or large bulk, depending upon volume consumed annually at the customer locations. Based on volumes consumed, small bulk customers are primarily residential and small business users, such as restaurants, that use LPG mainly for heating and cooking. Medium bulk customers consist mainly of large residential housing developments, hospitals, hotels, municipalities, medium-sized industrial enterprises and poultry brooders. Large bulk customers include agricultural customers (including crop drying) and companies that use LPG in their industrial processes. At September 30, 2021, UGI International had approximately 517,000 bulk LPG customers and sold more than 610 million gallons of bulk LPG during Fiscal 2021.
Cylinder
UGI International sells LPG in both steel and composite cylinders and typically owns the cylinders in which the LPG is sold. The principal end-users of cylinders are residential customers who use LPG for domestic applications, such as cooking and heating. Non-residential uses include fuel for forklift trucks, road construction and welding. At September 30, 2021, UGI International had more than 20 million cylinders in circulation and sold more than 150 million gallons of LPG in cylinders during Fiscal 2021. UGI International also delivers LPG to wholesale and retail customers in cylinders, including through the use of vending machines.
Wholesale, Autogas and Other Services
Approximately 19% of UGI International’s Fiscal 2021 LPG sales (based on volumes) were to wholesale customers (including small competitors and large industrial customers), and approximately 2% of Fiscal 2021 LPG sales (based on volumes) were to autogas customers. UGI International also provides logistics, storage and other services to third-party LPG distributors.
Energy Marketing Business
UGI International markets and supplies natural gas and electricity to small and medium enterprises, schools and municipalities through third-party distribution systems. UGI International started developing its energy marketing business organically in 2012 and further expanded this business through the acquisition of DVEP in the Netherlands in August 2017 and continues to expand this business through strategic transactions. UGI International sold approximately 36 Bcf of natural gas and over 3,300 Gwh of electricity during Fiscal 2021.
LPG Supply, Storage and Transportation
UGI International is typically party to term contracts, with more than 40 different suppliers, including producers and international oil and gas trading companies, to meet LPG supply requirements throughout Europe. LPG supply is transported via rail and sea, and by road for shorter distances. Agreements are generally one- to two-year terms with pricing based on internationally quoted market prices. Additionally, LPG is purchased on the European spot markets to manage supply needs. In certain geographic areas (the United Kingdom and Italy), a single supplier may provide 50% or more of UGI International’s requirements. Because UGI International’s profitability is sensitive to changes in wholesale LPG costs, UGI International generally seeks to pass on increases in the cost of LPG to its customers. There can be no assurance, however, that UGI International will always be able to pass on product cost increases fully, or keep pace with such increases, particularly when product costs rise rapidly. Product cost increases can be triggered by periods of severe cold weather, supply interruptions, increases in the prices of base commodities such as crude oil and natural gas, or other unforeseen events.
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Throughout Fiscal 2021, propane and butane production reduction continued to occur at refineries due to COVID-19 related demand decreases on primary fuels such as jet, gasoline and diesel. Reductions started in April 2020 and continued at varying levels through Fiscal 2021. The severity of reductions varied across the European market and the return of production to normal levels has also varied. Production has returned to normal at some refineries, while other refineries continue to operate at lower rates, and some have permanently ceased operations.
UGI International stores LPG at various storage facilities and terminals located across Europe and has interests in 10 primary storage facilities and more than 80 secondary storage facilities. LPG stored in primary storage facilities is transported to smaller storage facilities by rail and road. At secondary storage facilities, LPG is loaded into cylinders or trucks equipped with tanks and then delivered to customers. UGI International also manages an extensive logistics and transportation network and has access to seaborne import facilities.

UGI International transports LPG to customers primarily through outsourced transportation providers to serve both bulk and cylinder markets. UGI International has long-term relationships with many providers of logistics and transportation services in most of its markets and is not dependent on the services of any single transportation provider.
Renewable Energy Projects
In Fiscal 2021, UGI International announced investments in the following renewable energy projects:
In February 2021, UGI International entered a supply and development partnership with a Polish technology specialist in catalytic conversion of bioethanol to bio-gasoline and bioLPG for the exclusive rights to its supply of bioLPG. Notably, this product can be utilized by UGI International’s existing LPG entities operating across Europe.
In May 2021, UGI International announced its intention to launch a joint venture to advance the production and use of rDME, a low-carbon sustainable liquid gas, in the LPG industry. The parties anticipate the development of up to six production plants within the next five years, targeting a total production capacity of 300 kilotons of rDME per year by 2027.
We believe these projects will significantly contribute to reducing UGI International’s carbon footprint and achieving its decarbonization targets.
Competition and Seasonality
The LPG markets in western and northern Europe are mature, with modest declines in total demand due to competition with other fossil fuels and other energy sources, conservation and macroeconomic conditions. Sales volumes are affected principally by the severity of the weather and customer migration to alternative energy forms, including natural gas, electricity, heating oil and wood. High LPG prices also may result in slower than expected growth due to customer conservation and customers seeking less expensive alternative energy sources. In addition, government policies and incentives that favor alternative energy sources, such as wind and solar, can result in customers migrating to energy sources other than LPG. In addition to price, UGI International competes for customers in its various markets based on contract terms. UGI International competes locally as well as regionally in many of its service territories. Additionally, particularly in France, although UGI International supplies certain supermarket chains, it also competes with some of these supermarket chains that affiliate with LPG distributors to offer their own brands of cylinders. UGI International seeks to increase demand for its LPG cylinders through marketing and product innovations.
In its energy marketing business, UGI International competes against small- and medium-sized enterprise providers of natural gas and electricity in four countries in Europe where the markets have been deregulated for at least ten years. The markets are generally stable, developed and growing and competition can be local, regional or pan-European.
Because many of UGI International’s customers use LPG for heating, sales volume is affected principally by the severity of the temperatures during the heating season months and traditionally fluctuates from year-to-year in response to variations in weather, prices and other factors, such as conservation efforts and the economic environment. During Fiscal 2021, approximately 60% of UGI International’s retail sales volume occurred during the peak heating season from October through March. As a result of this seasonality, revenues are typically higher in UGI International’s first and second fiscal quarters (October 1 through March 31). For historical information on weather statistics for UGI International, see ‘‘Management’s Discussion and Analysis of Financial Condition and Results of Operations.’’
Business Transformation Initiatives
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. The goal of this initiative was to focus attention on enhanced customer service and safe and efficient operations through the establishment of two centers of excellence. One center focuses on commercial excellence to
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identify and execute projects that improve the customer’s experience. The second center focuses on operational excellence across our distribution network and our filling centers. These business activities are substantially complete and are expected to generate over €30 million of annual benefits by the end of Fiscal 2022.
Government Regulation
UGI International’s business is subject to various laws and regulations at the country and local levels, as well as at the EU level, with respect to matters such as protection of the environment, the storage, transportation and handling of hazardous materials and flammable substances (including the Seveso II Directive), regulations specific to bulk tanks, cylinders and piped networks, competition, pricing, regulation of contract terms, anti-corruption (including the U.S. Foreign Corrupt Practices Act, Sapin II and the U.K. Bribery Act), data privacy and protection, and the safety of persons and property.
Environmental
Environmental laws and regulations may require expenditures over a long timeframe to control environmental effects. Estimates of liabilities for environmental response costs are difficult to determine with precision because of the various factors that can affect their ultimate level. These factors include, but are not limited to, the following: (i) the complexity of the site; (ii) changes in environmental laws and regulations; (iii) the number of regulatory agencies or other parties involved; (iv) new technology that renders previous technology obsolete or experience with existing technology that proves ineffective; (v) the level of remediation required; and (vi) variation between the estimated and actual period of time required to respond to an environmentally-contaminated site.
Data Privacy
The EU adopted the GDPR, which became effective in May of 2018. The GDPR expanded the EU data protection laws to all companies processing data of EU residents. It primarily focuses on unifying and strengthening the regulations dealing with the collection, processing, use and security of personal and sensitive data.
Properties
In addition to regional headquarter locations and sales offices throughout its service territory, UGI International has interests in 10 primary storage facilities and more than 80 secondary storage facilities.
Employees
At September 30, 2021, UGI International had over 2,600 employees, including approximately 200 part-time, seasonal and temporary employees.


MIDSTREAM & MARKETING

Retail Energy Marketing

Our retail energy marketing business is conducted through Energy Services and its subsidiaries and sells natural gas, RNG, liquid fuels and electricity to approximately 12,600 residential, commercial and industrial customers at over 42,400 locations. We (i) serve customers in all or portions of Pennsylvania, New Jersey, Delaware, New York, Ohio, Maryland, Massachusetts, Virginia, North Carolina, South Carolina, Rhode Island, California and the District of Columbia, (ii) distribute natural gas through the use of the distribution systems of 46 local gas utilities, and (iii) supply power to customers through the use of the transmission and distribution lines of 20 utility systems.

Historically, a majority of Energy Services’ commodity sales have been made under fixed-price agreements, which typically contain a take-or-pay arrangement that permits customers to purchase a fixed amount of product for a fixed price during a specified period, and requires payment even if the customer does not take delivery of the product. However, a growing number of Energy Services’ commodity sales are currently being made under requirements contracts, under which Energy Services is typically an exclusive supplier and will supply as much product at a fixed price as the customer requires. Energy Services manages supply cost volatility related to these agreements by (i) entering into fixed-price supply arrangements with a diverse group of suppliers, (ii) holding its own interstate pipeline transportation and storage contracts to efficiently utilize gas supplies, (iii) entering into exchange-traded futures contracts on NYMEX and ICE, (iv) entering into over-the-counter derivative arrangements with major international banks and major suppliers, (v) utilizing supply assets that it owns or manages, and (vi) utilizing financial transmission rights to hedge price risk against certain transmission costs. Energy Services also bears the risk for balancing and delivering natural gas and power to its customers under various gas pipeline and utility company tariffs. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Market Risk Disclosures.”
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Midstream Assets

LNG

Our midstream assets, which are owned by Energy Services and its subsidiaries, comprise a natural gas liquefaction, storage and vaporization facility in Temple, Pennsylvania, a natural gas liquefaction and storage facility in Mehoopany, Pennsylvania, liquefied natural gas vaporization and storage facilities in Steelton and Bethlehem, Pennsylvania, and three small mobile facilities located in Reading, Mount Carmel and Stroudsburg, Pennsylvania.

In addition, Energy Services sells LNG to customers for use by trucks, drilling rigs, other motor vehicles and facilities located off the natural gas grid.

Natural Gas and Propane Storage

Energy Services and its subsidiaries own propane storage and propane-air mixing stations in Bethlehem, Reading, Hunlock Creek, and White Deer, Pennsylvania. Energy Services and its subsidiaries also operate propane storage, rail transshipment terminals and propane-air mixing stations in Steelton and Williamsport, Pennsylvania. These assets are used in Midstream & Marketing’s energy peaking business that provides supplemental energy, primarily LNG and propane-air mixtures, to gas utilities at times of high demand (generally during periods of coldest winter weather).

A wholly owned subsidiary of Energy Services owns and operates underground natural gas storage and related high pressure pipeline facilities, which have FERC approval to sell storage services at market-based rates. The storage facilities are located in the Marcellus Shale region of north-central Pennsylvania and have a total storage capacity of 15 million dekatherms and a maximum daily withdrawal quantity of 224,000 dekatherms. In Fiscal 2021, Energy Services leased approximately 74% of the firm capacity at its underground natural gas facilities to third parties.

Gathering Systems and Pipelines

Energy Services operates the Auburn gathering system in the Marcellus Shale region of northeastern Pennsylvania with a total system capacity of 635,000 dekatherms per day, including the expansion that was completed in Fiscal 2020. The gathering system delivers into both the Tennessee Gas and Transcontinental Gas pipelines. Energy Services also operates a 6.5-mile pipeline, known as the Union Dale pipeline, that gathers gas in Susquehanna County and has a capacity of 100,000 dekatherms per day. In addition, Energy Services owns and operates approximately 87 miles of natural gas gathering lines, dehydration and compression facilities, known as Texas Creek, Marshlands, and Ponderosa, located in Bradford, Tioga, Lycoming, Potter and Clinton Counties, Pennsylvania. The combined capacity of these three systems is more than 250,000 dekatherms per day. In Fiscal 2021, our Midstream & Marketing segment also managed natural gas pipeline and storage contracts for utility company customers, including UGI Utilities, Inc.

Energy Services and its subsidiaries also own and operate a 35-mile, 20-inch pipeline, known as the Sunbury pipeline, with related facilities located in Snyder, Union, Northumberland, Montour, and Lycoming Counties, Pennsylvania, which has a design capacity of 200,000 dekatherms per day. In addition, Energy Services owns and operates the Mt. Bethel pipeline, which runs 12.5 miles in Northampton County, Pennsylvania and is designed to provide 72,000 dekatherms per day.

Energy Services’ subsidiary, UGI Appalachia, consists of five natural gas gathering systems with approximately 240 miles of natural gas gathering pipelines and gas compressors and one processing plant in southwestern Pennsylvania, eastern Ohio, and the panhandle of West Virginia. Energy Services also has a 47% ownership interest in Pennant Midstream, LLC, a natural gas gathering system that was acquired in the CMG Acquisition. The UGI Appalachia assets provide natural gas gathering and processing services in the Appalachian Basin with gathering capacity of approximately 2,675,000 dekatherms per day and processing capacity of approximately 240,000 dekatherms per day.

In Fiscal 2021, a subsidiary of Energy Services entered into a joint venture with Stonehenge Energy Resource Holdings III LLC (“Stonehenge”) to acquire Pine Run Midstream, LLC. Energy Services owns approximately 49% of the joint venture with Stonehenge, and Stonehenge operates the system. The system is comprised of approximately 42 miles of pipeline, 43,125 HP of installed compression and dedicated production of 54,000 gross acres. The system is attached to another gathering system owned by Energy Services.

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Electric Generation Assets

Midstream & Marketing holds electric generation facilities conducted by Energy Services’ wholly owned subsidiary, UGID. UGID owns and operates the Hunlock Creek Energy Center located near Wilkes-Barre, Pennsylvania, a 174-megawatt natural gas-fueled electricity generating station. UGID also owns and operates a landfill gas-fueled generation plant near Hegins, Pennsylvania, with gross generating capacity of 11 megawatts, that qualifies for renewable energy credits. Additionally, UGID owns and operates 13.5 megawatts of solar-powered generation capacity in Pennsylvania, Maryland and New Jersey.

Renewable Natural Gas

In Fiscal 2020, Energy Services purchased GHI, a Houston-based company that markets RNG in California. GHI purchases gas produced from landfills and biodigesters and resells the gas to fleet operators in California. Environmental credits are generated through this process, which are then sold to various third parties for an additional revenue stream.

In Fiscal 2021, we announced investments in the following RNG production projects:

Energy Services invested in a joint venture to develop dairy farm digester projects that produce RNG in upstate New York. The first project, announced in May 2021, incorporates an existing anaerobic digester that generates biogas, which is used to produce renewable electricity, and is expected to be completed in the second half of calendar year 2022. The second project, announced in September 2021, includes the construction of an anaerobic digester and a combined heat and power project that are expected to produce 85 MMcf of RNG each year once completed in the second half of calendar year 2022.

In September 2021, Energy Services announced that it would partially fund a joint venture designed to develop several clusters of dairy farm digester projects to produce RNG from multiple farms in South Dakota. The clusters of projects, which Energy Services will have the option to fund on a project-by-project basis, are expected to produce 650 MMcf of RNG annually when complete and on-line by the end of calendar year 2024. The RNG will be delivered to the local natural gas pipelines serving the regional distribution system.

In August 2021, Energy Services invested in a joint venture to develop innovative food waste digester projects to produce RNG in Ohio and Kentucky. The first digester project is expected to be completed in the first half of calendar 2023 and will process approximately 190,000 tons annually of food waste from nearby food manufacturers in an anaerobic digester. The project is expected to generate approximately 250,000 MMBTUs of pipeline-quality RNG each year that will be injected into a local natural gas pipeline on the regional distribution system.

In November 2020, Energy Services invested in a utility-scale RNG project in Idaho. The project is expected to produce several hundred MMcf of RNG each year from on-site dairy waste feedstock once it is expanded to reach full production in 2022.

Competition

Our Midstream & Marketing segment competes with other midstream operators to sell gathering, compression, storage and pipeline transportation services. Our Midstream & Marketing segment competes in both the regulated and non-regulated environment against interstate and intrastate pipelines that gather, compress, process, transport and market natural gas. Our Midstream & Marketing segment sells midstream services primarily to producers, marketers and utilities on the basis of price, customer service, flexibility, reliability and operational experience. The competition in the midstream segment is significant and has grown recently in the northeast U.S. as more competitors seek opportunities offered by the development of the Marcellus and Utica Shales.

Our Midstream & Marketing segment also competes with other marketers, consultants and local utilities to sell natural gas, liquid fuels, electric power and related services to customers in its service area principally on the basis of price, customer service and reliability. Midstream & Marketing’s midstream asset business has faced an increase in competition in recent years with the consolidation of companies that have resulted in large, national competitors that can offer a suite of services across all customer segments.

Our electricity generation assets compete with other generation stations on the interface of PJM, a regional transmission organization that coordinates the movement of wholesale electricity in certain states, including the states in which we operate, and bases sales on bid pricing.
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Through our wholly owned subsidiary, GHI, Midstream & Marketing has the capability to source and deliver RNG to customers throughout the U.S. GHI currently delivers RNG to transportation fleets for utilization in their compressed natural gas and LNG fueled vehicles, resulting in the creation and monetization of California Low Carbon Fuel Standard (“LCFS”) and Renewable Fuel Standard (“RFS”) Renewable Identification Numbers (“RINs”).

Government Regulation

FERC has jurisdiction over the rates and terms and conditions of service of wholesale sales of electric capacity and energy, as well as the sales for resale of natural gas and related storage and transportation services.  Energy Services has a tariff on file with FERC, pursuant to which it may make power sales to wholesale customers at market-based rates, to the extent that Energy Services purchases power in excess of its retail customer needs.  Two subsidiaries of Energy Services, UGI LNG, Inc. and UGI Storage Company, currently operate natural gas storage facilities under FERC certificate approvals and offer services to wholesale customers at FERC-approved market-based rates. Two other Energy Services subsidiaries operate natural gas pipelines that are subject to FERC regulation. UGI Mt. Bethel Pipeline Company, LLC operates a 12.5-mile, 12-inch pipeline located in Northampton County, Pennsylvania, and UGI Sunbury, LLC operates the Sunbury Pipeline, a 35-mile, 20-inch diameter pipeline located in central Pennsylvania. Both pipelines offer open-access transportation services at cost-based rates approved by FERC. Energy Services and its subsidiaries undertake various activities to maintain compliance with the FERC Standards of Conduct with respect to pipeline operations. Energy Services is also subject to FERC reporting requirements, market manipulation rules and other FERC enforcement and regulatory powers with respect to its wholesale commodity business.

Midstream & Marketing’s midstream assets include natural gas gathering pipelines and compression and processing in northeastern Pennsylvania, southwestern Pennsylvania, eastern Ohio and the panhandle of West Virginia that are regulated under federal pipeline safety laws and subject to operational oversight by both the Pipeline and Hazardous Materials Safety Administration and the PAPUC.

Certain of our Midstream & Marketing businesses are subject to various federal, state and local environmental, safety and transportation laws and regulations governing the storage, distribution and transportation of propane and the operation of bulk storage LPG terminals. These laws include, among others, the Resource Conservation and Recovery Act, CERCLA, the Clean Air Act, OSHA, the Homeland Security Act of 2002, the Emergency Planning and Community Right-to-Know Act, the Clean Water Act and comparable state statutes. CERCLA imposes joint and several liability on certain classes of persons considered to have contributed to the release or threatened release of a “hazardous substance” into the environment without regard to fault or the legality of the original conduct. With respect to the operation of natural gas gathering and transportation pipelines, Energy Services also is required to comply with the provisions of the Pipeline Safety Improvement Act of 2002 and the regulations of the DOT.

Our Midstream & Marketing’s electricity generation assets own electric generation facilities that are within the control area of PJM and are dispatched in accordance with a FERC-approved open access tariff and associated agreements administered by PJM. UGID receives certain revenues collected by PJM, determined under an approved rate schedule.  Like Energy Services, UGID has a tariff on file with FERC pursuant to which it may make power sales to wholesale customers at market-based rates, and FERC has approved UGID’s market-based rate authority through 2023. UGID is also subject to FERC reporting requirements, market manipulation rules and other FERC enforcement and regulatory powers.

Employees

At September 30, 2021, Midstream & Marketing had over 400 employees.

UGI UTILITIES

GAS UTILITY

Gas Utility consists of the regulated natural gas distribution business of our subsidiary, UGI Utilities, Inc. Gas Utility serves approximately 672,000 customers in eastern and central Pennsylvania and more than 500 customers in portions of one Maryland county. Gas Utility is regulated by the PAPUC and, with respect to its customers in Maryland, the MDPSC.

Service Area; Revenue Analysis

Gas Utility provides natural gas distribution services to approximately 672,000 customers in certificated portions of 46 eastern
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and central Pennsylvania counties through its distribution system. Contemporary materials, such as plastic or coated steel, comprise approximately 91% of Gas Utility’s more than 12,400 miles of gas mains, with bare steel pipe comprising approximately 7% and cast iron pipe comprising approximately 2% of Gas Utility’s gas mains. In accordance with Gas Utility’s agreement with the PAPUC, Gas Utility will replace the cast iron portion of its gas mains by March 2027 and the bare steel portion of its gas mains by September 2041. The service area includes the cities of Allentown, Bethlehem, Easton, Harrisburg, Hazleton, Lancaster, Lebanon, Reading, Scranton, Wilkes-Barre, Lock Haven, Pittston, Pottsville and Williamsport, Pennsylvania, and the borough of Carlisle, Pennsylvania. Located in Gas Utility’s service area are major production centers for basic industries such as specialty metals, aluminum, glass, paper product manufacturing, and several power generation facilities. Gas Utility also distributes natural gas to more than 500 customers in portions of one Maryland county.

System throughput (the total volume of gas sold to or transported for customers within Gas Utility’s distribution system) for Fiscal 2021 was approximately 309 Bcf. System sales of gas accounted for approximately 19% of system throughput, while gas transported for residential, commercial and industrial customers who bought their gas from others accounted for approximately 81% of system throughput.

Sources of Supply and Pipeline Capacity

Gas Utility is permitted to recover all prudently incurred costs of natural gas it sells to its customers. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Market Risk Disclosures” and Note 9 to Consolidated Financial Statements. Gas Utility meets its service requirements by utilizing a diverse mix of natural gas purchase contracts with suppliers, marketers and producers, along with peaking, storage and transportation service contracts. These arrangements enable Gas Utility to purchase gas from Marcellus, Gulf Coast, Mid-Continent, and Appalachian sources as well as peaking facilities and locally produced natural gas connected to the distribution system. For its peaking, transportation and storage services, Gas Utility has long-term agreements with a number of pipeline companies, including Texas Eastern Transmission, LP, Columbia Gas Transmission, LLC, Transcontinental Gas Pipeline Company, LLC, Dominion Transmission, Inc., Tennessee Gas Pipeline Company, L.L.C., and Energy Services and its subsidiaries (including UGI Storage Company).

Gas Supply Contracts

During Fiscal 2021, Gas Utility purchased approximately 86 Bcf of natural gas for sale to retail core-market customers (principally composed of firm- residential, commercial and industrial customers that purchase their gas from Gas Utility) and off-system sales customers. Ninety-seven percent (97%) of the volumes purchased were supplied under agreements with 10 suppliers, with the remaining volumes supplied by 20 producers and marketers. Gas supply contracts for Gas Utility are generally no longer than 12 months. Gas Utility also has long-term contracts with suppliers for natural gas peaking supply during the months of November through March.

Seasonality

Because many of its customers use gas for heating purposes, Gas Utility’s sales are seasonal. For Fiscal 2021, approximately 58% of Gas Utility’s sales volume was supplied, and approximately 91% of Gas Utility’s operating income was earned, during the peak heating season from October through March.

Competition

Natural gas is a fuel that competes with electricity and oil and, to a lesser extent, with propane and coal. Competition among these fuels is primarily a function of their comparative price and the relative cost and efficiency of the equipment. Natural gas generally benefits from a competitive price advantage over oil, electricity and propane. Fuel oil dealers compete for customers in all categories, including industrial customers. Gas Utility responds to this competition with marketing and sales efforts designed to retain, expand, and grow its customer base, including the utilization of flexible negotiated rate structures.

In substantially all of its service territories, Gas Utility is the only regulated gas distribution utility having the right, granted by the PAPUC or by law, to provide gas distribution services. All of Gas Utility’s customers, including core-market customers, have the right to purchase gas supplies from entities other than natural gas distribution utility companies.

A number of Gas Utility’s commercial and industrial customers have the ability to switch to an alternate fuel at any time and, therefore, are served on an interruptible basis under rates that are competitively priced with respect to the service alternates. Margin from these customers, therefore, is affected by the difference or “spread” between the customers’ delivered cost of gas and the customers’ delivered cost of the alternate fuel, the frequency and duration of interruptions, and alternative firm service options. See “Utilities Regulation - State Utility Regulation - Gas Utility.”
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Approximately 50% of Gas Utility’s annual throughput volume for commercial and industrial customers includes non-interruptible customers with firm rates at locations that afford them the opportunity of seeking transportation service directly from interstate pipelines, thereby bypassing Gas Utility. In addition, approximately 14% of Gas Utility’s annual throughput volume for commercial and industrial customers is from customers who are served under interruptible rates and are also in a location near an interstate pipeline. During Fiscal 2021, Gas Utility had 17 such customers, 13 of which have transportation contracts extending beyond Fiscal 2022. The majority of these customers are served under transportation contracts having 3- to 20-year terms and all are among the largest customers for Gas Utility in terms of annual volumes. No single customer represents, or is anticipated to represent, more than 5% of Gas Utility’s total revenues.

Outlook for Gas Service and Supply

Gas Utility anticipates having adequate pipeline capacity, peaking services and other sources of supply available to it to meet the full requirements of all firm customers on its system through Fiscal 2022. Supply mix is diversified, market priced and delivered pursuant to a number of long-term and short-term primary firm transportation and storage arrangements, including transportation contracts held by some of Gas Utility’s larger customers and natural gas suppliers serving customers on Gas Utility’s distribution system.

During Fiscal 2021 Gas Utility supplied transportation service to 11 electric generation facilities and 27 major co-generation facilities. Gas Utility continues to seek new residential, commercial, and industrial customers for both firm and interruptible service. In Fiscal 2021, Gas Utility connected more than 1,350 new commercial and industrial customers. In the residential market sector, Gas Utility added more than 11,000 residential heating customers during Fiscal 2021. Approximately 48% of these customers converted to natural gas heating from other energy sources, mainly oil and electricity. New home construction and existing non-heating gas customers who added gas heating systems to replace other energy sources primarily accounted for the other residential heating connections in Fiscal 2021.

Gas Utility continues to monitor and participate, where appropriate, in rulemaking and individual rate and tariff proceedings before FERC affecting the rates and the terms and conditions under which Gas Utility transports and stores natural gas. Among these proceedings are those arising out of certain FERC orders and/or pipeline filings that relate to (i) the pricing of pipeline services in a competitive energy marketplace, (ii) the flexibility of the terms and conditions of pipeline service tariffs and contracts, and (iii) pipelines’ requests to increase their base rates, or change the terms and conditions of their storage and transportation services.

Gas Utility’s objective in negotiations with providers of gas supply resources, and in proceedings before regulatory agencies, is to ensure availability of supply, transportation and storage alternatives to serve market requirements at the lowest cost possible, taking into account the need for safety, security and reliability of supply. Consistent with that objective, Gas Utility negotiates certain terms of firm transportation capacity on all pipelines serving it, arranges for appropriate storage and peak-shaving resources, negotiates with producers for competitively priced gas purchases and aggressively participates in regulatory proceedings related to transportation rights and costs of service.

At September 30, 2021, Gas Utility had over 1,650 employees.

MOUNTAINEER

In September 2021, we completed the Mountaineer Acquisition, whereby Mountaineer Gas Company became an indirect, wholly owned subsidiary of UGI Corporation. Mountaineer provides a regulated natural gas distribution business to nearly 214,000 customers in 50 of West Virginia’s 55 counties. Mountaineer’s system is comprised of approximately 6,200 miles of distribution, transmission and gathering pipelines. Contemporary materials, such as plastic or coated steel, comprise approximately 74% of Mountaineer’s gas mains, with bare steel pipe comprising the remaining 26%.

As of September 30, 2021, Mountaineer’s customer base was approximately 90% residential and 10% commercial and industrial customers, with throughput volumes consisting of approximately 30% residential, 36% commercial and 34% industrial and other. Because many of its customers use gas for heating purposes, Mountaineer’s sales are seasonal. For Fiscal 2021, approximately 65% of Mountaineer’s sales volume (including transport volumes) was supplied, and more than 140% of Mountaineer’s operating income was earned, during the peak heating season from October through March.

System throughput (the total volume of gas sold to or transported for customers within Mountaineer’s distribution system) for Fiscal 2021 was approximately 46 Bcf. Retail core-market sales of gas accounted for approximately 46% of system throughput, while gas transported for commercial and industrial customers who bought their gas from others accounted for nearly 54% of
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system throughput. Mountaineer anticipates having adequate pipeline capacity, peaking services and other sources of supply available to it to meet the full requirements of all firm customers on its system through Fiscal 2022.

Approximately 29% of Mountaineer’s annual throughput volume for commercial and industrial customers represents customers who are served under interruptible rates and are also in a location near an interstate pipeline. As of September 30, 2021, Mountaineer had 18 such customers, one of which has a transportation contract extending beyond September 30, 2022. The majority of these customers, including ten of Mountaineer’s largest customers in terms of annual volumes, are served under evergreen transportation contracts having a 30- to 180-day termination notice.

Mountaineer meets its service requirements by utilizing a diverse mix of natural gas purchase contracts with marketers and producers, along with storage and transportation service contracts. During Fiscal 2021, Mountaineer purchased approximately 23 Bcf of natural gas for sale to retail core-market customers (principally composed of firm- residential, commercial and industrial customers that purchase their gas from Mountaineer). Approximately 79% of the volume purchased was supplied under agreements with 10 suppliers, with the remaining volumes supplied by various producers and marketers. Gas supply contracts for Mountaineer are generally evergreen agreements with a 30-day termination notice.

At September 30, 2021, Mountaineer had more than 460 employees.

ELECTRIC UTILITY

Electric Utility supplies electric service to approximately 62,500 customers in portions of Luzerne and Wyoming counties in northeastern Pennsylvania through a system consisting of over 2,600 miles of transmission and distribution lines and 14 substations. For Fiscal 2021, approximately 58% of sales volume came from residential customers, 31% from commercial customers, and 11% from industrial and other customers. During Fiscal 2021, 13 retail electric generation suppliers provided energy for customers representing approximately 37% of Electric Utility’s sales volume.  At September 30, 2021, UGI Utilities, Inc.’s electric utility operations had more than 75 employees.

UTILITIES REGULATION

State Utility Regulation

Gas Utility

Gas Utility is subject to regulation by the PAPUC as to rates, terms and conditions of service, accounting matters, issuance of securities, contracts and other arrangements with affiliated entities, gas safety and various other matters. Rates that Gas Utility may charge for gas service come in two forms: (i) rates designed to recover PGCs; and (ii) rates designed to recover costs other than PGCs. Rates designed to recover PGCs are reviewed in PGC proceedings. Rates designed to recover costs other than PGCs are primarily established in general base rate proceedings.

On October 4, 2019, the PAPUC issued a final order approving a settlement of a base rate proceeding by Gas Utility that permitted Gas Utility, effective October 11, 2019, to increase its base distribution revenues by $30 million under a single 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 additional terms of 5 years.

On October 8, 2020, the PAPUC issued a final order approving a settlement of a base rate proceeding by Gas Utility that permitted Gas Utility to utilize a two-step phase-in of a $20 million base distribution revenue increase, with $10 million effective January 1, 2021, and $10 million effective July 1, 2021. The settlement also provides enhanced COVID-19 related consumer protections and allowed Gas Utility future regulatory asset recovery of COVID-19 related costs, such as greater-than-budgeted uncollectible accounts expense and other COVID-19 related operating costs.

Act 11 authorized the PAPUC to permit electric and gas distribution companies, between base rate cases and subject to certain conditions, to recover reasonable and prudent costs incurred to repair, improve or replace eligible property through a DSIC assessed to customers. Among other requirements, DSICs are subject to reconciliation of over-/under- collection, quarterly adjustment and are capped at five percent of total customer charges absent a PAPUC-granted exception. In addition, Act 11 requires affected utilities to obtain approval of LTIIPs from the PAPUC. Act 11 also authorized electric and gas distribution companies to utilize a fully forecasted future test year when establishing rates in base rate cases before the PAPUC.

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On August 21, 2019, Gas Utility filed a consolidated LTIIP designed for the 2020-2024 calendar years (the “Gas LTIIP II”), during which Gas Utility projects spending $1.265 billion on DSIC-eligible property. Gas Utility’s filing was approved by the PAPUC in an order entered December 19, 2019.

With the approval of new base distribution rates on October 8, 2020, the DSIC-eligible property revenue requirement was included in base distribution revenue recovery. The final order issued by the PAPUC approved the settlement of the base rate proceeding and authorized Gas Utility to implement a DSIC once Gas Utility’s total property, plant and equipment less accumulated depreciation reached $2.875 billion. This threshold was achieved in December 2020, and Gas Utility implemented a DSIC effective April 1, 2021. Unless Gas Utility seeks and receives a PAPUC waiver of the statutory 5% rate cap, any future DSIC charges will be capped at 5% of overall Gas Utility annual base revenue.

In addition to base distribution rates and various surcharges designed to recover specified types of costs, Gas Utility’s tariff also includes a uniform PGC rate applicable to firm retail rate schedules for customers who do not obtain natural gas supply service from an alternative supplier. The PGC rate permits recovery of all prudently incurred costs of natural gas that Gas Utility sells to its retail customers. PGC rates are reviewed and approved annually by the PAPUC. Gas Utility may request quarterly or, under certain conditions, monthly adjustments to reflect the actual cost of gas. Quarterly adjustments become effective on one day’s notice to the PAPUC and are subject to review during the next annual PGC filing. Each proposed annual PGC rate is required to be filed with the PAPUC six months prior to its effective date. During this period, the PAPUC investigates and may hold hearings to determine whether the proposed rate reflects a least-cost fuel procurement policy consistent with the obligation to provide safe, adequate and reliable service. After completion of these hearings, the PAPUC issues an order permitting the collection of gas costs at levels that meet such standard. The PGC mechanism also provides for an annual reconciliation and for the payment or collection of interest on over and under collections.

Gas Utility’s gas service tariff also contains a state tax surcharge clause. The surcharge is recomputed whenever any of the tax rates included in their calculation are changed. These clauses protect Gas Utility from the effects of increases in certain of the Pennsylvania taxes to which it is subject.

Mountaineer

Mountaineer is subject to regulation of rates and other aspects of its business by the WVPSC. When necessary, Mountaineer seeks general base rate increases to recover increased operating costs and a fair return on rate base investments. Base rates are determined by the cost-of-service by rate class, and the rate design methodology allocates the majority of operating costs through volumetric charges.

Mountaineer makes routine filings with the WVPSC to reflect changes in the costs of purchased gas. These purchased gas costs are subject to rate recovery through a mechanism that provides dollar-for-dollar recovery of prudently incurred costs. Costs in excess of revenues that are expected to be recovered in future rates are deferred as regulatory assets; conversely, revenues in excess of costs are deferred as a regulatory liability. The PGA filings generally cover a prospective twelve-month period.

As permitted by West Virginia law enacted in 2015, the WVPSC has also approved a standalone cost recovery rider to recover specified costs and a return on infrastructure projects between general base rate cases in accordance with its Infrastructure Replacement and Expansion Plan (“IREP”). Mountaineer makes an annual IREP filing, which is subject to an over/under-recovery mechanism similar to purchased gas costs. In July 2021, Mountaineer submitted its annual IREP filing to the WVPSC requesting a return on its forecasted 2022 calendar year IREP-eligible capital investments of $56 million and recovery of eligible costs. On November 12, 2021, Mountaineer and the intervening parties submitted a joint stipulation and agreement for settlement to the WVPSC for a cumulative revenue requirement of $16 million effective January 1, 2022, with an increase of approximately $5.5 million from the previous year. An order from the WVPSC addressing the stipulation is expected in December 2021.

Electric Utility

Electric Utility is permitted to recover prudently incurred electricity costs, including costs to obtain supply to meet its customers’ energy requirements, pursuant to a supply plan filed with and approved by the PAPUC. Electric Utility distributes electricity that it purchases from wholesale markets and electricity that customers purchase from other suppliers.

In a decision dated January 15, 2020, the Pennsylvania Commonwealth Court affirmed two findings in the PAPUC’s October 25, 2018 Opinion and Order in Electric Utility’s 2018 rate case, thereby approving Electric Utility’s use of a fully projected future test year for ratemaking purposes and its treatment of certain tax benefits achieved through UGI’s consolidated federal tax filings.
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On February 8, 2021, Electric Utility filed for a base rate increase with the PAPUC. On July 19, 2021, Electric Utility filed a joint petition for settlement of the rate case, which includes a revenue increase of approximately $6.2 million. In an order dated October 28, 2021, the PAPUC approved the settlement and authorized the increased rate to become effective November 9, 2021.

Electric Utility’s tariff includes rates, applicable to so-called “default service” customers who do not obtain electric generation service from an alternative supplier, incurred pursuant to a PAPUC-approved supply plan. These default service rates are reconcilable, may be adjusted quarterly, and are designed to permit Electric Utility to recover the full costs of providing default service in a full and timely manner. Electric Utility’s default service rates include recovery of costs associated with compliance with the AEPS Act, which requires Electric Utility to directly or indirectly acquire certain percentages of its supplies from designated alternative energy sources. In an order dated January 14, 2021, the PAPUC authorized Electric Utility to implement its current Default Service plan for the period June 1, 2021 through May 31, 2025, subject to possible, prospectively applied interim modifications that parties to that proceeding may propose in accordance with a settlement filed in that proceeding on October 23, 2020.

Electric Utility’s LTIIP was approved by the PAPUC on December 21, 2017 for the 2018-2022 time period. Electric Utility’s projected annual investment in distribution infrastructure replacement was approximately $7.6 million in Fiscal 2018, and will increase to $8.3 million by Fiscal 2022. On December 19, 2019, the PAPUC approved Electric Utility’s DSIC rate mechanism that now permits it to impose a DSIC surcharge to recover revenue requirements associated with DSIC-eligible plant. With the implementation of new base rates on November 9, 2021 pursuant to the PAPUC’s October 28, 2021 order in the 2021 Electric Utility base rate case, Electric Utility may not charge a DSIC except to reconcile the over/under-recovery of allowable DSIC revenue from periods before the effective date of the new rates until its plant balances reach the level of plant agreed upon in the settlement of the rate case. Unless Electric Utility seeks and receives a PAPUC waiver of the statutory 5% rate cap, any future DSIC charges will be capped at 5% of overall annual base revenue.
Utility Franchises

Gas Utility and Electric Utility hold certificates of public convenience issued by the PAPUC and certain “grandfather rights” predating the adoption of the Pennsylvania Public Utility Code and its predecessor statutes, which authorize it to carry on its business in the territories in which it renders gas service. Under applicable Pennsylvania law, Gas Utility also has certain rights of eminent domain as well as the right to maintain its facilities in public streets and highways in its territories.

Similarly, Mountaineer holds certificates of public convenience issued by the WVPSC, which authorize it to carry on its business in substantially all of the territories in which it now renders gas service. Under applicable West Virginia law, Mountaineer also has certain rights of eminent domain as well as the right to maintain its facilities in public streets and highways in its territories.

Federal Energy Regulation

With the acquisition of Mountaineer on September 1, 2021, UGI and its subsidiaries became subject to FERC regulation under PUHCA 2005 pertaining to record-keeping and affiliate service pricing requirements. UGI provided notice of its non-exempt status on September 17, 2021.

UGI Utilities, Inc. and Mountaineer are subject to Section 4A of the Natural Gas Act, which prohibits the use or employment of any manipulative or deceptive devices or contrivances in connection with the purchase or sale of natural gas or natural gas transportation subject to the jurisdiction of FERC, and FERC regulations that are designed to promote the transparency, efficiency, and integrity of gas markets.

Similarly, UGI Utilities, Inc. and Mountaineer are also subject to Section 222 of the Federal Power Act, which prohibits the use or employment of any manipulative or deceptive devices or contrivances in connection with the purchase or sale of electric energy or transmission service subject to the jurisdiction of FERC, and FERC regulations that are designed to promote the transparency, efficiency, and integrity of electric markets.

FERC has jurisdiction over the rates and terms and conditions of service of electric transmission facilities used for wholesale or retail choice transactions. Electric Utility owns electric transmission facilities that are within the control area of PJM and are dispatched in accordance with a FERC-approved open access tariff and associated agreements administered by PJM. PJM is a regional transmission organization that regulates and coordinates generation, supply and the wholesale delivery of electricity. Electric Utility receives certain revenues collected by PJM, determined under a formulary rate schedule that is adjusted in June
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of each year to reflect annual changes in Electric Utility’s electric transmission revenue requirements, when its transmission facilities are used by third parties. FERC has jurisdiction over the rates and terms and conditions of service of wholesale sales of electric capacity and energy. Electric Utility has a tariff on file with FERC pursuant to which it may make power sales to wholesale customers at market-based rates.

Under provisions of EPACT 2005, Electric Utility is subject to certain electric reliability standards established by FERC and administered by an ERO. Electric Utility anticipates that substantially all the costs of complying with the ERO standards will be recoverable through its PJM formulary electric transmission rate schedule.

EPACT 2005 also granted FERC authority to impose substantial civil penalties for the violation of any regulations, orders or provisions under the Federal Power Act and Natural Gas Act and clarified FERC’s authority over certain utility or holding company mergers or acquisitions of electric utilities or electric transmitting utility property valued at $10 million or more.

Other Government Regulation

In addition to state and federal regulation discussed above, Gas Utility, Mountaineer and Electric Utility are subject to various federal, state and local laws governing environmental matters, occupational health and safety, pipeline safety and other matters. Each is subject to the requirements of the Resource Conservation and Recovery Act, CERCLA and comparable state statutes with respect to the release of hazardous substances. See Note 17 to Consolidated Financial Statements.

BUSINESS SEGMENT INFORMATION

The table stating the amounts of revenues, operating income and identifiable assets attributable to each of UGI’s reportable business segments, and to information regarding the geographic areas in which we operate, for Fiscal 2021, Fiscal 2020 and Fiscal 2019 appears in Note 23 to Consolidated Financial Statements included in Item 15 of this Report and is incorporated herein by reference.


EMPLOYEES

At September 30, 2021, UGI and its subsidiaries had approximately 11,300 employees.

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HUMAN CAPITAL MANAGEMENT

We are committed to the attraction, development, retention and safety of our employees. The following is an overview of some of our key human capital initiatives that are designed to ensure the overall well-being of our employees and other stakeholders as well as to promote workforce diversity.

UGI publishes annual sustainability reports, which are available free of charge on its corporate website under “ESG - Resources - Sustainability Reports.” Information included in these sustainability reports is not intended to be incorporated into this Report.

Workplace Safety

We are committed to maintaining an effective safety culture and to stressing the importance of our employees’ role in identifying, mitigating and communicating safety risks. We believe that the achievement of superior safety performance is both an important short-term and long-term strategic initiative in managing our operations. In this regard, our policies and operational practices promote a culture where all levels of employees are responsible for safety. Safety is generally included as a component of the annual bonus calculation for executives and non-executives, reinforcing our commitment to safety across our organization. For more details as to how we integrate safety performance into our core business activities, please refer to our Health, Safety, Security and the Environment (“HSSE”) Policy, which is available on our website under “Company - Company Policies - HSSE Policy.”

UGI’s Board of Directors oversees safety efforts primarily through its Safety, Environmental, and Regulatory Compliance (“SERC”) Committee, which is responsible for the governance and oversight of all health and safety matters at the Company, including compliance with applicable laws and regulations. The SERC Committee oversees the Company’s maintenance of a culture focused on protecting the health and safety of our employees, contractors, customers, and the public. Additionally, our senior management team is actively engaged in our safety programs and conducts regular reviews of safety performance metrics. These metrics are presented quarterly to the SERC Committee for review and consideration. In addition, each of our business units has a safety team that is responsible for overseeing the safety of our operations, reinforcing our values, providing training and enhancing our safety culture within such business unit.

Our COVID-19 Response

The health, well-being and safety of our employees, customers and communities is our top priority. During Fiscal 2021, we continued to focus on responding to the challenges of the COVID-19 pandemic, particularly as they related to our global workforce. Our senior management team continues to have regular COVID-19 and return-to-office planning sessions to address the critical safety, operational and business risks associated with the pandemic across all geographies. Through these efforts, as well as our continued commitment to monitor, assess and implement guidance and best practices recommended by the WHO and CDC, we have been able to maintain the continuity of the essential services that we provide to our customers, while also promoting the health, well-being and safety of our employees, customers and communities.

Diversity Strategy

Diversity as Part of Our Company Culture

We believe that, by fostering an environment that exemplifies our core value of respect, we gain, as a company, unique perspectives, backgrounds and varying experiences to ensure our continued long-term success. Belonging, inclusion, diversity and equity are essential to our success, and we respect and value all employees.

In alignment with our efforts to promote diversity and inclusion, we introduced the Belonging, Inclusion, Diversity and Equity (“BIDE”) Initiative in Fiscal 2020, which provides the organizational blueprint for achieving greater diversity and promoting respect for uniqueness of individuals and cultures and inclusion for the varied perspectives they provide. The BIDE Initiative embodies and promotes internal policies with respect to setting expectations relating to our work environment, including our Code of Business Conduct and Ethics and our Anti-Discrimination, Anti-Harassment and Human Rights policies. As part of the BIDE Initiative, we have expanded our partnerships with numerous organizations that support underrepresented populations.

UGI also offers a network of employee resource groups that aligns with our efforts to promote diversity and inclusion.

Black Organizational Leadership & Development (“BOLD”) is focused on inclusion, equity, education, and empowerment for black employees and their allies, and assists leadership with communication, talent recruitment, retention, and development opportunities for black employees. BOLD focuses on professional development by
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creating mentoring opportunities, increasing exposure through networking and career development events, broadening outreach to and recruitment of black talent, and sponsoring activities such as lectures featuring distinguished speakers.

The Women’s Impact Network (“WIN”) is an organization that aims to foster an environment for women to be recruited, retained, and developed as leaders throughout UGI. Membership in WIN offers exposure to various professional development opportunities, including speaker series events, group engagement activities, virtual group discussions, and partnerships with local organizations for women and their allies.

The Veteran Employee Team (“VET”) focuses on recruiting and retaining veterans, as well as creating growth for and goodwill towards military veterans. VET members include Active Duty, Reserve, and National Guard veterans of the Army, Navy, Marines, Coast Guard, and Air Force, their families, and partners committed to supporting military veteran employees.

Diversity in Our Leadership

We believe that diversity in our Board of Directors (the “Board”) is critical to effective governance. In assessing Board composition, UGI ensures that our Board has the right mix of background, experience, and diversity of perspectives to support our business. In assessing director candidates, UGI considers a number of qualifications, including independence, knowledge, judgment, character, leadership skills, education, experience, financial literacy, standing in the community and diversity of backgrounds and views, including, but not limited to, gender, race, ethnicity and national origin. We look to complement the Board’s existing strengths, recognizing that diversity is a critical element to enhancing board effectiveness. Our current Board composition includes three female directors and one racially diverse director out of a total of nine independent directors.

Similarly, we believe diversity of management is crucial to position our business for continued success. UGI is proactive in ensuring consideration of diverse candidates for all leadership positions and continues to be committed to ensuring that we are considering all qualified applicants in our hiring process. Females and racially/ethnically diverse individuals represent more than 25% and approximately 20%, respectively, of UGI’s corporate officers.

As part of our continued commitment to enhancing opportunities for diversity in our workforce, all executives have a diversity and inclusion (“D&I”) component in their annual bonus plan effective Fiscal 2021. The executive team will be evaluated on the effectiveness of the Company’s development of a multi-dimensional strategy to deepen and improve the organization’s commitment to D&I, supporting the Company’s BIDE Initiative and establishing a roadmap to achieve excellence in D&I and brand UGI as an employer of choice for diverse candidates.

Diversity in Our Workforce

UGI strives for diverse representation at all levels of our business. During Fiscal 2021, for the first time, we published our workforce demographics (which reflects our EEO-1 reporting data) in our 2020 Sustainability Report. We believe that, by publicly disclosing our workforce demographics, we increase transparency in the composition of our workforce as well as facilitate accountability in ensuring that minority candidates are actively considered for roles throughout the organization. We will continue to report on our progress annually.

Diversity as Part of Our Employee Development

In Fiscal 2021, UGI established a global partnership with the Human Library Organization (the “Human Library”), a global not-for-profit learning platform that hosts personal conversations designed to challenge stigma and stereotypes and create a safe space for dialogue where topics are discussed openly between individuals. The Human Library promotes workplace diversity and inclusion by partnering with companies that are committed to incorporating social understanding and cultural awareness as part of their business model.

UGI has committed to a sponsorship role with the Human Library for the creation of a digital learning platform that will expand the reach of the Human Library’s diversity experiences across the globe. UGI began working with the Human Library in Fiscal 2020 for diversity and inclusion education for its leadership development, supervisor training and new hire onboarding programs. Many of our employees participated in the Human Library “reader sessions” over the past year and we expect that more will participate in the coming year.

Talent Development and Support

Maintaining a robust pipeline of talent is crucial to UGI’s ongoing success and is a key aspect of succession planning efforts across the organization. Our leadership and human resources teams are responsible for attracting and retaining top talent by facilitating an environment where employees feel supported and encouraged in their professional and personal development.
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Competition for attracting and retaining talent has increased in recent years, and UGI understands this challenge and the importance of maintaining competitive compensation, benefits and training that provides growth, developmental opportunities and multiple career paths within our company. Specifically, we promote employee development by reviewing strategic positions regularly and identifying potential internal candidates to fill those positions, evaluating critical job skill sets to identify competency gaps and creating developmental plans to facilitate employee professional growth. We commit to investing in our employees through training and development programs as well as tuition reimbursement to promote continued professional growth.

The following programs are examples of how we promote the professional development of our employees.

UGI University is a leadership development program for emerging leaders across all domestic and international business units. In addition to completing personal assessments and leadership and team effectiveness training, participants engage directly with executive leaders of each business, gaining a broader understanding of UGI and the stakeholders it serves.

UGI Academy is a leadership development program that provides UGI International’s emerging leaders the opportunity to learn more about UGI Corporation, including our culture, values and strategic direction. Participants engage in self-assessments, meet colleagues from across the business, engage with the UGI executive management team and sharpen skills that will equip them for future success.

AmeriGas Accelerated Leadership Program (“ALP”) establishes key leadership competencies, behavioral traits and skills required to be an effective leader at the director level. ALP is a full year program where participants complete a series of training experiences, action learning projects, job shadowing, and a detailed development plan which contributes to their readiness for a position at the director level.

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ITEM 1A. RISK FACTORS

There are many factors that may affect our business, financial condition and results of operations, including the following risks relating to: (1) the demand for our products and services and our ability to grow our customer base; (2) our business operations, including internal and external factors that may impact our operational continuity; (3) our international operations; (4) our supply chain and our ability to obtain and transport adequate quantities of LPG; (5) government regulation and oversight; and (6) general factors that may impact our business and our shareholders.

Risks Relating to the Demand for Our Products and Services and Our Ability to Grow Our Customer Base

Our business is seasonal and decreases in the demand for our energy products and services because of warmer-than-normal heating season weather or unfavorable weather conditions may adversely affect our results of operations.

Because many of our customers rely on our energy products and services to heat their homes and businesses, and for agricultural purposes such as crop drying, our results of operations are adversely affected by warmer-than-normal heating season weather. Weather conditions have a significant impact on the demand for our energy products and services for both heating and agricultural purposes. Accordingly, the volume of our energy products sold is at its highest during the peak heating season of October through March and is directly affected by the severity of the winter weather. For example, historically, approximately 60% to 70% of AmeriGas Propane’s annual retail propane volume, 60% to 70% of UGI International’s annual retail LPG volume, 60% to 70% of Energy Services’ retail natural gas volume and 60% to 70% of Gas Utility’s natural gas throughput (the total volume of gas sold to or transported for customers within our distribution system) has typically been sold during these months. Additionally, as a result of the AmeriGas Merger, an even greater portion of our earnings has been and will continue to be derived during the peak heating season of October through March. There can be no assurance that normal winter weather in our market areas will occur in the future.

In addition, our agricultural customers use LPG for purposes other than heating, including for crop drying, and unfavorable weather conditions, such as lack of precipitation, may impact the demand for LPG. Moreover, harsh weather conditions may at times impede the transportation and delivery of LPG, or restrict our ability to obtain LPG from suppliers. Spikes in demand caused by weather or other factors can stress the supply chain and limit our ability to obtain additional quantities of LPG. Changes in LPG supply costs are normally passed through to customers, but time lags (between when we purchase the LPG and when the customer purchases the LPG) may result in significant gross margin fluctuations that could adversely affect our results of operations.

The potential effects of climate change may affect our business, operations, supply chain and customers, which could adversely impact our financial condition and results of operations.

Shifts and fluctuations in weather patterns and other environmental conditions, including temperature and precipitation levels, may affect consumer demand for our energy products and services. In addition, the potential physical effects of climate change, such as increased frequency and severity of storms, floods and other climatic events, could disrupt our operations and supply chain, and cause us to incur significant costs in preparing for or responding to these effects. These or other meteorological changes could lead to increased operating costs, capital expenses or supply costs. Our commercial and residential customers may also experience the potential physical impacts of climate change and may incur significant costs in preparing for or responding to these efforts, including increasing the mix and resiliency of their energy solutions and supply. The impact of any one or all of the foregoing factors may adversely affect our financial condition and results of operations.

In addition to the direct physical impact that climate change may have on our business, financial condition and results of operations, we may also be adversely impacted by other environmental factors, including: (i) technological advances designed to promote energy efficiency and limit environmental impact; (ii) increased competition from alternative energy sources; (iii) regulatory responses aimed at decreasing GHG emissions; and (iv) litigation or regulatory actions that address the environmental impact of our energy products and services. For more information on these risks, please refer to the following risk factors included elsewhere in this section:

“Energy efficiency and technology advances, as well as price induced customer conservation, may result in reduced demand for our energy products and services”;
“Our operations may be adversely affected by competition from other energy sources”;
“Our need to comply with, and respond to industry-wide changes resulting from, comprehensive, complex, and sometimes unpredictable governmental regulations, including regulatory initiatives aimed at increasing competition
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within our industry, may increase our costs and limit our revenue growth, which may adversely affect our operating results”;
“Our operations, financial results and cash flows may be adversely affected by existing and future global climate change laws and regulations, including with respect to GHG emission restrictions, as well as market responses thereto”; and
“We are subject to operating and litigation risks that may not be covered by insurance.”

Our potential to increase revenues may be affected by the decline in retail volumes of LPG and our ability to retain and grow our customer base.

The retail LPG distribution industry in the U.S. and many of the European countries in which we operate is mature and has been declining over the past several years, with no or modest growth (or decline) in total demand foreseen in the near future. Accordingly, we expect that year-to-year industry volumes will be principally affected by weather patterns. Therefore, our ability to grow within the LPG industry is dependent on our ability to acquire other retail distributors and to achieve internal growth, which includes expansion of the ACE, Cynch and National Accounts programs in the U.S. and expansion in Europe, as well as the success of our sales and marketing programs designed to attract and retain customers. Any failure to retain and grow our customer base and successfully acquire other distributors would have an adverse impact on our results. Acquisitions in the U.S. and Europe may require merger control filings with the Federal Trade Commission and the European Commission, as applicable, and commitments or divestments of assets may be required to obtain clearance. Such commitments or divestments may influence the overall economics and risk profile of the transaction.

Our ability to grow our businesses will be adversely affected if we are not successful in identifying and completing business combinations, asset acquisitions or investments in joint ventures intended to advance our business strategy, or if we are unable to realize the anticipated benefits from such transactions we have completed.

One element of our business strategy is to grow through investments in the U.S. and in international markets, which includes our recent efforts to expand our presence in the renewable energy industry. We may choose to finance such future investments with debt, equity, cash or a combination of the three. We can give no assurances that we will find attractive investment opportunities in the future (including renewable energy opportunities), that we will be able to complete and finance these transactions on economically acceptable terms, that any investments and related transactions will not be dilutive to earnings or that any additional debt incurred to finance such investment will not affect our ability to pay dividends. Moreover, certain investments, including some acquisitions, may require antitrust and other regulatory clearances. We may have to offer commitments (such as agreements not to compete for certain businesses) or divest assets in order to obtain clearance, which may adversely affect the overall economics and risk profile of the contemplated transaction.

To the extent we are successful in executing these transactions, such transactions involve a number of risks. These risks include, but are not limited to, the assumption of material liabilities, environmental liabilities, the diversion of management’s attention from the management of daily operations to the integration of acquired operations, difficulties in the assimilation and retention of employees and difficulties in the assimilation of different cultures and practices and internal controls, challenges with consolidating the operations of acquired companies into our own, as well as in the assimilation of broad and geographically dispersed personnel and operations. Future investments could also result in, among other things, the failure to identify material issues during due diligence, the risk of overpaying for assets, unanticipated capital expenditures, the failure to maintain effective internal control over financial reporting, recording goodwill and other intangible assets at values that ultimately may be subject to impairment charges and fluctuations in quarterly results. There can also be no assurance that our past and future investments, including our recent investments in renewable energy, will deliver the strategic, financial, operational and environmental benefits that we anticipate, nor can we be certain that strategic investments will remain available in the future.

The failure to successfully identify, complete, and implement investments intended to advance our business strategy could have an adverse impact on our business, cash flows, financial condition and results of operations.

Energy efficiency and technology advances, as well as price induced customer conservation, may result in reduced demand for our energy products and services.

The trend toward increased energy efficiency and technological advances, including installation of improved insulation and the development of more efficient boilers and other heating equipment, as well as conservation measures, may reduce the demand for our energy products. Prices for LPG and natural gas are subject to volatile fluctuations as a result of changes in supply and demand as well as other market conditions. During periods of high energy commodity costs, our prices generally increase, which may lead to customer conservation and attrition. A reduction in demand could lower our revenues and, therefore, lower
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our net income and adversely affect our cash flows. State and/or federal regulation may require mandatory conservation measures, which would reduce the demand for our energy products. Additionally, at the international level, EU and local laws and regulations may require mandatory conservation measures, which would reduce the demand for our energy products. For example, in 2018 the EU revised the Energy Performance of Buildings Directive (the “EPBD”), with the goal to create a clear path towards a low and zero-emission and decarbonized building stock in the EU by 2050.  Due to delays resulting from the COVID-19 pandemic, EU countries will now be adopting laws through 2021 to implement the EPBD.  The EU is also adopting further measures to decarbonize electricity generation in order to reduce dependence on fossil fuel imports and achieve its climate change objectives. Over time, these various measures will impact fossil fuel consumption in Europe and the demand for our energy products. We cannot predict the materiality of the effect of future conservation measures or the effect that any technological advances in heating, conservation, energy generation or other devices might have on our operations.

Our operations may be adversely affected by competition from other energy sources.

Our energy products and services face competition from other energy sources, some of which are less costly for equivalent energy value. In addition, we cannot predict the effect that the development of alternative energy sources might have on our operations.

Our LPG distribution businesses compete for customers against suppliers of electricity, fuel oil and natural gas. Electricity is a major competitor of LPG but, except in France, is generally more expensive than LPG on a Btu equivalent basis for space heating, water heating and cooking. However, in Europe and elsewhere, climate change policies favoring electricity from renewable energy sources may cause changes in current relative price relationships. Moreover, notwithstanding cost, the convenience and efficiency of electricity make it an attractive energy source for consumers and developers of new homes. In addition, due to the prevalence of nuclear electric generation in France, the cost of electricity is generally less expensive than that of LPG, particularly when the cost to install new equipment to convert to LPG is considered. Fuel oil, which is also a major competitor of propane, is currently more expensive than propane and is a less environmentally attractive energy source. Furnaces and appliances that burn LPG will not operate on fuel oil and vice versa, and, therefore, a conversion from one fuel to the other requires the installation of new equipment. Our customers generally have an incentive to switch to fuel oil only if fuel oil becomes significantly less expensive than LPG. Except for certain industrial and commercial applications, LPG is generally not competitive with natural gas in areas where natural gas pipelines already exist because natural gas is generally a significantly less expensive source of energy than LPG. The gradual expansion of natural gas distribution systems in our service areas has resulted, and may continue to result, in the availability of natural gas in some areas that previously depended upon LPG. As long as natural gas remains a less expensive energy source than LPG, our LPG business will lose customers in each region into which natural gas distribution systems are expanded.

Our natural gas businesses compete primarily with electricity and fuel oil, and, to a lesser extent, with LPG and coal. Competition among these fuels is primarily a function of their comparative price and the relative cost and efficiency of fuel utilization equipment. There can be no assurance that our natural gas revenues will not be adversely affected by this competition.

The expansion, construction and development of our energy infrastructure assets subjects us to risks.

We seek to grow our business through the expansion, construction and development of our energy infrastructure, including new pipelines, gathering systems, facilities and other assets. These projects are subject to state and federal regulatory oversight and require certain property rights, such as easements and rights-of-way from public and private owners, as well as regulatory approvals, including environmental and other permits and licenses. There is no assurance that we or our project partners, as applicable, will be able to obtain the necessary property rights, permits and licenses in a timely and cost-efficient manner or at all, which may result in a delay or failure to complete a project. We may face opposition to the expansion, construction or development of new or existing pipelines, gathering systems, facilities or other assets from environmental groups, landowners, local groups and other advocates. This opposition could take many forms, including organized protests, attempts to block or sabotage our operations, intervention in regulatory or administrative proceedings involving our assets, or lawsuits or other actions designed to prevent, disrupt, or delay the development or operation of our assets and business. Failure to complete any pending or future infrastructure project may have a materially adverse impact on our financial condition and results of operations.

Even if we are able to successfully complete any pending or future infrastructure project, our revenues may not increase immediately upon the expenditure of funds on a particular project or as anticipated during the lifespan of the project. As a result, there is the risk that new and expanded energy infrastructure may not achieve our expected investment returns, which could have a material adverse effect on our business, financial condition and results of operations.
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Risks Relating to Our Business Operations, Including Internal and External Factors that May Impact Our Operational Continuity

Our efforts to create operational benefits and cost efficiencies through business transformation initiatives at our business units and various corporate services functions may be disruptive and adversely affect our business, financial condition and results of operations. 

We may make adjustments to our workforce in response to management changes, product changes, performance issues, changes in strategy, acquisitions or other internal and external considerations. These adjustments may result in increased costs and temporarily reduced productivity, as well as a disruption in our ability to perform functions critical to our strategy, including, but not limited to, disruptions in customer service. The effects of such adjustments could recur in connection with any current or future business transformation initiatives or we may not achieve or sustain the expected growth or cost savings benefits of any such initiatives, or do so within the expected timeframe. As a result, our business, financial condition and results of operations could be negatively affected.

We have substantially completed transformation initiatives at our AmeriGas and UGI International business units that are designed to achieve operational benefits and cost efficiencies and to leverage technology to provide an enhanced customer experience. Additional initiatives are ongoing in certain of our corporate services functions, including finance, human resources, procurement and information technology, that are designed to standardize processes and activities across our global platform, while leveraging the use of best practices and efficiencies between our businesses. If we are unable to deliver the strategic and financial benefits that we anticipate, the achievement of these benefits is delayed, or the volume and nature of change challenges our available resources, then our business operations and financial results could be materially and adversely impacted. Our ability to successfully manage and execute these initiatives and realize expected savings and benefits in the amounts and at the times anticipated is important to our business success. Any failure to do so, which could result from our inability to successfully execute organizational change and business transformation initiatives, unanticipated costs or charges, loss of key personnel, customer loss and other factors described herein, could have a material adverse effect on our business, financial condition and results of operations. For further information on these initiatives, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Executive Overview - Strategic Initiatives.”

Our information technology systems and those of our third-party vendors have been the target of cyber-security attacks in the past. If we are unable to protect our information technology systems against future service interruption, misappropriation of data, or breaches of security resulting from cyber-security attacks or other events, or if we encounter other unforeseen difficulties in the design, implementation or operation of our information technology systems, or if our third-party vendors or service providers experience compromises to their information technology systems, our operations could be disrupted, our business and reputation may suffer, and our internal controls could be adversely affected.

In the ordinary course of business, we rely on information technology systems, including the Internet and third-party hosted services, to support a variety of business processes and activities and to store sensitive data, including (i) intellectual property, (ii) our proprietary business information and that of our suppliers and business partners, (iii) personally identifiable information of our customers and employees, and (iv) data with respect to invoicing and the collection of payments, accounting, procurement, and supply chain activities. In addition, we rely on our information technology systems to process financial information and results of operations for internal reporting purposes and to comply with financial reporting, legal, and tax requirements.

Cyber-security incidents have recently increased in both frequency and magnitude and have involved malicious software and attempts to gain unauthorized access to data and systems, including ransomware attacks where a target’s access to its information systems is blocked until a ransom has been paid. The White House and various regulators, including the SEC, have accordingly increased their focus on companies’ cybersecurity vulnerabilities and risks. Despite our security measures, our technologies, systems, and networks have been and may continue to be the target of cyber-security attacks or information security breaches that could result in the unauthorized release, misuse, loss or destruction of proprietary and other information, or other disruption of our business operations. Due to increasingly sophisticated threat actors, we may be unable to detect, identify or prevent attacks, and even if detected, we may be unable to adequately stop, investigate or remediate our systems given the tools and techniques being used by threat actors to circumvent controls and to remove or obfuscate forensic evidence. Attacks and incidents may also occur due to malfeasance by employees or contractors, as well as human error as in the case of social engineering and phishing campaigns. As a result of the COVID-19 pandemic, a number of our employees have transitioned to working remotely; as a result, more of our employees are working from locations where our cyber-security program may be less effective and information technology security may be less robust. Similarly, our third-party vendors or service providers have been impacted by cyber-security attacks and incidents and are subject to many if not all of the same risks
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and disruptions as described above. A loss of our information technology systems, or temporary interruptions in the operation of our information technology systems, or those of our third-party vendors or service providers, or any other misappropriation of data, or breaches of security could lead to investigations and fines or penalties, litigation, increased costs for compliance and for remediation or rebuilding of our systems, and could have a material adverse effect on our business, financial condition, results of operations, and reputation. In addition, a cyber-security attack could provide a cyber-intruder with the ability to control or alter our pipeline operations. Such an act could result in critical pipeline failures.

The efficient execution of our businesses is dependent upon the proper design, implementation and functioning of its current and future internal systems, such as the information technology systems that support our underlying business processes. Any significant failure or malfunction of such information technology systems may result in disruptions of our operations. In addition, the effectiveness of our internal controls could be adversely affected if we encounter unforeseen problems with respect to the operation of our information technology systems.

Moreover, as cyber incidents increase in frequency and magnitude, we may be unable to obtain cyber-security insurance in amounts and on terms we view as adequate for our operations, including the agreement to certain indemnification provisions by our insurance providers.

Our utility transmission and distribution systems, our non-utility midstream assets, and the assets of upstream interstate pipelines and other midstream providers may not operate as planned, which may increase our expenses or decrease our revenues and, thus, have an adverse impact on our financial results.

Our ability to manage operational risk with respect to utility distribution and transmission and non-utility midstream assets, and the availability of natural gas delivered by interstate natural gas pipelines and midstream gathering assets is critical to our financial results.  We obtain our supply from local Marcellus and Utica Shale sources, as well as other trading points in the U.S.  If we experience physical capacity constraints on one or more of the interstate or intrastate natural gas pipelines that supply our businesses, we may not be able to supply our customers, which could have an adverse impact on our financial results.  Our businesses also face several risks, including the breakdown or failure of or damage to equipment or processes (especially due to severe weather or natural disasters), accidents and other factors, including as a result of overpressurization of or damage to natural gas pipelines.  Operation of our transmission and distribution systems or our midstream assets below our expectations may result in lost revenues or increased expenses, including higher maintenance costs, civil litigation and the risk of regulatory penalties.

Risks Relating to Our International Operations

Our international operations could be subject to increased risks, which may negatively affect our business results.

We operate LPG distribution and energy marketing businesses in Europe through our subsidiaries and we continue to explore the expansion of our international businesses. As a result, we face risks in conducting business abroad that we do not face domestically. Certain aspects inherent in transacting business internationally could negatively impact our operating results, including:

costs and difficulties in staffing and managing international operations;
potentially adverse tax consequences, including restrictions on repatriating earnings, the threat of “double taxation,” and potential increases to corporate income taxes (including the proposed OECD framework that aims to reform international taxation rules with the goal of ensuring that multinational corporations pay adequate taxes in the jurisdictions in which they operate and other similar proposals);
fluctuations in currency exchange rates, particularly the euro, which can affect demand for our products, increase our costs and adversely affect our profitability and reported results;
new or revised regulatory requirements, including European competition laws that may adversely affect the terms of contracts with customers, including with respect to exclusive supply rights, and stricter regulations applicable to the storage and handling of LPG;
economic and political uncertainty relating to the United Kingdom’s withdrawal from the EU, commonly known as “Brexit,” which may result in, among other things, increased regulatory costs and challenges, greater volatility in the British pound sterling and euro, business disruptions and increased tariffs;
new and inconsistently enforced industry regulatory requirements, which can have an adverse effect on our competitive position;
tariffs and other trade barriers;
difficulties in enforcing contractual rights;
longer payment cycles;
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local political and economic conditions; and
potential violations of federal regulatory requirements, including anti-bribery, anti-corruption, and anti-money laundering law, economic sanctions, the Foreign Corrupt Practices Act of 1977, as amended, and EU regulatory requirements, including the GDPR and Sapin II.

In particular, certain legal and regulatory risks are associated with international business operations. We are subject to various anti-corruption, economic sanctions and trade compliance laws, rules and regulations. For example, the U.S. government imposes restrictions and prohibitions on transactions in certain foreign countries, including restrictions directed at oil and gas activities in Russia. U.S. laws also prohibit the improper offer, payment, promise to pay, or authorization of the payment of money or anything of value to any foreign official or political party, or to any person, knowing that all or a portion of it will be used to influence a foreign official in his or her official duties or to secure an improper advantage. Ensuring compliance with all relevant laws, rules and regulations is a complex task. Violation of one or more of these laws, rules or regulations could lead to loss of import or export privileges, civil or criminal penalties for us or our employees, or potential reputational harm, which could have a material adverse impact on earnings, cash flows and financial condition.

Risks Relating to Our Supply Chain and Our Ability to Obtain Adequate Quantities of LPG

We are dependent on our principal LPG suppliers, which increases the risks from an interruption in supply and transportation.

During Fiscal 2021, AmeriGas Propane purchased approximately 83% of its propane needs from 20 suppliers. If supplies from these sources were interrupted, the cost of procuring replacement supplies and transporting those supplies from alternative locations might be materially higher and, at least on a short-term basis, our earnings could be affected. Additionally, in certain geographic areas, a single supplier may provide more than 50% of AmeriGas Propane’s propane requirements. Disruptions in supply in these geographic areas could also have an adverse impact on our earnings. Our international businesses are similarly dependent upon their LPG suppliers. For example, during Fiscal 2021, UGI International’s business in the United Kingdom purchased approximately 87% of its LPG needs from two suppliers and, in Italy, approximately 52% of its supply was sourced from a single supplier. If supplies from UGI International’s principal LPG sources are interrupted, the cost of procuring replacement supplies and transporting those supplies from alternative locations might be materially higher and our earnings could be adversely affected. There is no assurance that our international businesses will be able to continue to acquire sufficient supplies of LPG to meet demand at prices or within time periods that would allow them to remain competitive.

Our ability to obtain sufficient quantities of LPG is dependent on transportation facilities and providers.

Spikes in demand caused by weather or other factors can limit our access to port terminals and other transportation and storage facilities, disrupt transportation and limit our ability to obtain sufficient quantities of LPG. A significant increase in port and similar fees and fuel prices may also adversely affect our transportation costs and business. Transportation providers (rail and truck) in some circumstances have limited ability to provide additional resources in times of peak demand. Moreover, the ability of our transportation providers to maintain a staff of qualified truck drivers is critical to the success of our business. Regulatory requirements and an improvement in the economy could reduce the number of eligible drivers or require us to pay higher transportation fees as our transportation providers seek to pass on additional labor costs associated with attracting and retaining drivers.

Our profitability is subject to LPG pricing and inventory risk.

The retail LPG business is a “margin-based” business in which gross profits are dependent upon the excess of the sales price over LPG supply costs. LPG is a commodity, and, as such, its unit price is subject to fluctuations in response to changes in supply or other market conditions. We have no control over supplies, commodity prices or market conditions. Consequently, the unit price of the LPG that our subsidiaries and other distributors and marketers purchase can change rapidly over a short period of time. Most of our domestic LPG product supply contracts permit suppliers to charge posted prices at the time of delivery or the current prices established at major U.S. storage points such as Mont Belvieu, Texas or Conway, Kansas. Most of our international LPG supply contracts are based on internationally quoted market prices. We also purchase a portion of our supplies in the spot market. Because our subsidiaries’ profitability is sensitive to changes in wholesale LPG supply costs, it will be adversely affected if we cannot pass on increases in the cost of LPG to our customers, or if there is a delay in passing on such cost increases. Due to competitive pricing in the industry, our subsidiaries may not fully be able to pass on product cost increases to our customers when product costs rise, or when our competitors do not raise their product prices in a timely manner. Finally, market volatility may cause our subsidiaries to sell LPG at less than the price at which they purchased it,
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which would adversely affect our operating results.

We offer our customers various fixed-price LPG programs, and a significant number of our customers utilize our fixed-price programs. In order to manage the price risk from offering these services, we utilize our physical inventory position, supplemented by forward commodity transactions with various third parties having terms and volumes substantially the same as our customer’s contracts, but there can be no assurance that such measures will be effective. In periods of high LPG price volatility, the fixed-price programs create exposure to over or under-supply positions as the demand from customers may significantly exceed or fall short of supply procured. In addition, if LPG prices decline significantly subsequent to customers signing up for a fixed-price program, there is a risk that customers will default on their commitments, adversely affecting our results of operations.

Changes in commodity market prices may have a significant negative effect on our liquidity.
Depending on the terms of our contracts with suppliers as well as our use of financial instruments to reduce volatility in the cost of LPG and natural gas, changes in the market price of LPG and natural gas can create margin payment obligations for us and expose us to increased liquidity risk. In addition, increased demand for domestically produced LPG and natural gas overseas may, depending on production volumes in the U.S., result in higher domestic prices and expose us to additional liquidity risks.

Supplier and derivative counterparty defaults may have a negative effect on our operating results.

When we enter into fixed-price sales contracts with customers, we typically enter into fixed-price purchase contracts with suppliers. Depending on changes in the market prices of products compared to the prices secured in our contracts with suppliers of LPG, natural gas and electricity, a default of or force majeure by one or more of our suppliers under such contracts could cause us to purchase those commodities at higher prices from alternate suppliers, which would have a negative impact on our operating results.

Additionally, we economically hedge the market risk associated with a substantial portion of our supply purchases using certain derivative instruments. Such changes in market prices of the aforementioned commodities could result in material exposures or significant concentrations of balances with derivative counterparties. If certain counterparties were unable to meet the obligations set forth in these derivative contracts and we were unable to fully mitigate this exposure via collateral deposit requirements and master netting arrangements, such outcomes could also result in a negative effect on our operating results.

Our business is dependent on the global supply chain to ensure that equipment, materials and other resources are available to both expand and maintain services in a safe and reliable manner. Moreover, prices of equipment, materials and other resources have increased recently and may continue to increase in the future. Failure to secure equipment, materials and other resources on economically acceptable terms may adversely impact our financial condition and results of operations.

Current domestic and global supply chain issues are delaying the delivery, and in some cases resulting in shortages of, materials, equipment and other resources that are critical to our business operations. Failure to eliminate or manage the constraints in the supply chain may eventually impact the availability of items that are necessary to support normal operations as well as materials that are required for continued infrastructure growth, including the replacement of end-of-life assets.

Moreover, inflation has recently become an area of increasing economic concern, both domestically and internationally. Changes in the costs of providing our energy products and services, including price increases in equipment and materials as well as increases in labor costs, may negatively impact our financial condition and results of operations and/or result in corresponding price increases for the energy products and services we offer our customers.

Risks Relating to Government Regulation and Oversight

Regulators may not approve the rates we request and existing rates may be challenged, which may adversely affect our results of operations.

In our UGI Utilities segment (comprised of UGI Utilities, Inc. and Mountaineer Gas Company), our distribution operations are subject to regulation by the PAPUC, WVPSC and MDPSC, depending on the state in which the operations are located. These regulatory bodies, among other things, approve the rates that UGI Utilities may charge utility customers, thus impacting the returns that UGI Utilities may earn on the assets that are dedicated to its operations. We expect that UGI Utilities will periodically file requests with these regulatory bodies to increase base rates charged to customers in the respective states in which UGI Utilities operates. If UGI Utilities is required in a rate proceeding to reduce the rates it charges its utility customers, or is unable to obtain approval for timely rate increases from the appropriate regulatory body, particularly when necessary to cover increased costs, UGI Utilities’ revenue growth will be limited and earnings may decrease.
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The enactment of proposed or future tax legislation, including the reversal of recently enacted tax legislation that is beneficial to us, may adversely impact our financial condition and results of operations.

On March 27, 2020, the U.S. enacted the CARES Act. Our financial statements for Fiscal 2021 reflect the realized benefits of the CARES Act. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations.” Application of the CARES Act requires significant judgments to be made in the interpretation of the law and significant estimates in the calculation of the provision for income taxes. If our interpretation of the CARES Act differs significantly from the interpretation of governing bodies, or if future administrations choose to repeal or replace the provisions of the CARES Act, our financial condition and results of operations may be adversely impacted.

Additionally, the enactment of future tax legislation (such as the proposed OECD framework that aims to reform international taxation rules with the goal of ensuring that multinational corporations pay adequate taxes in the jurisdictions in which they operate and other similar proposals) could have a material impact on our financial condition and results of operations, including our worldwide income tax provision and accruals reflected in our financial statements. We are also monitoring several tax proposals set forth by the Biden Administration, Senate Finance Committee Chairman Ron Wyden, and the Ways and Means Committee of the U.S. House of Representatives. If enacted into law, these proposals would result in significant changes to U.S. tax laws, including, but not limited to, corporate tax rate increases, corporate minimum tax rates, interest expense deduction limitations, and changes to foreign income taxation. We will continue to evaluate the overall impact of current, future, and proposed regulations and interpretive guidance from tax authorities on our effective tax rate and consolidated balance sheets. We are unable to predict whether any such changes or other proposals will ultimately be enacted. Any future legislative changes could negatively impact our anticipated cash-flow and after-tax results of operations.

Our need to comply with, and respond to, industry-wide changes resulting from, comprehensive, complex, and sometimes unpredictable governmental regulations, including regulatory initiatives aimed at increasing competition within our industry, may increase our costs and limit our revenue growth, which may adversely affect our operating results.

While we generally refer to our UGI Utilities segment as our “regulated segment,” there are many governmental regulations that have an impact on all of our businesses. Currently, we are subject to extensive and changing international, federal, state, and local safety, health, transportation, tax, and environmental laws and regulations governing the marketing, storage, distribution, and transportation of our energy products. Moreover, existing statutes and regulations may be revised or reinterpreted and new laws and regulations may be adopted or become applicable to us that may affect our businesses in ways that we cannot predict.

New regulations, or a change in the interpretation of existing regulations, could result in increased expenditures. In addition, for many of our operations, we are required to obtain permits from regulatory authorities and, in some cases, such regulatory permits could subject our operations to additional regulations and standards of conduct. Failure to obtain or comply with these permits or applicable regulations and standards of conduct could result in civil and criminal fines or the cessation of the operations in violation. Governmental regulations and policies in the U.S. and Europe may provide for subsidies or incentives to customers who use alternative fuels instead of carbon fuels. The EU has committed to cut CO2 emissions by at least 40% by 2030 and EU member states are proposing and implementing a range of subsidies and incentives to achieve the EU’s climate change goals. These subsidies and incentives may result in reduced demand for our energy products and services.

We are investigating and remediating contamination at a number of present and former operating sites in the U.S., including former sites where we or our former subsidiaries operated manufactured gas plants. We have also received claims from third parties that allege that we are responsible for costs to clean up properties where we or our former subsidiaries operated a manufactured gas plant or conducted other operations. Most of the costs we incur to remediate sites outside of Pennsylvania cannot currently be recovered in PAPUC rate proceedings, and insurance may not cover all or even part of these costs. Our actual costs to clean up these sites may exceed our current estimates due to factors beyond our control, such as:

the discovery of presently unknown conditions;
changes in environmental laws and regulations;
judicial rejection of our legal defenses to third-party claims; or
the insolvency of other responsible parties at the sites at which we are involved.

Moreover, if we discover additional contaminated sites, we could be required to incur material costs, which would reduce our net income.

We also may be unable to timely respond to changes within the energy and utility sectors that may result from regulatory
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initiatives to further increase competition within our industry. Such regulatory initiatives may create opportunities for additional competitors to grow their business or enter our markets and, as a result, we may be unable to maintain our revenues or continue to pursue our current business strategy.

Our operations, financial results and cash flows may be adversely affected by existing and future global climate change laws and regulations, including with respect to GHG emission restrictions, as well as market responses thereto.
Climate change continues to attract considerable public and scientific attention in the U.S. and in foreign countries. As a result, numerous proposals have been made and could continue to be made at the international, national, regional, state and local levels of government to monitor and limit GHG emissions and climate impact. These efforts have included consideration of cap-and-trade programs, carbon taxes, GHG reporting and tracking programs, and regulations that directly limit GHG emissions from certain sources. Increased regulation of GHG emissions, or climate impact generally, could have significant additional adverse impacts on us, our suppliers, our vendors, and our customers. The following provides a brief overview of the material climate-related regulatory provisions that may impact our domestic and international businesses, respectively.

Domestic Regulatory Landscape

In September 2009, the EPA issued a final rule establishing a system for mandatory reporting of GHG emissions. In November 2010, the EPA expanded the reach of its GHG reporting requirements to include the petroleum and natural gas industries, which include certain facilities of our natural gas distribution business. These subject facilities have been required to monitor emissions since January 2011 and to submit detailed annual reports beginning in March 2012.

In March 2021, the Biden Administration announced a framework for the "Build Back Better" agenda. The proposed framework included policies to address climate change across the federal government through the tax code, an energy efficiency and clean energy standard, research and development, among other areas of focus. Relatedly, the U.S. House Energy and Commerce Committee released, and has been holding hearings on, the Climate Leadership and Environmental Action for our Nation's ("CLEAN") Future Act, which is expected to influence legislation furthering the "Build Back Better" agenda. The CLEAN Future Act proposes, among other things, a clean electricity standard that would require electricity suppliers to procure and retire clean energy credits offsetting, in aggregate, 80% of the energy sold by 2030 and 100% by 2035. It would establish an auction-based mechanism for these credits and award partial credits to certain types of carbon-emitting generation that have lower-than-average emissions rates.

"Build Back Better" has been on two tracks in Congress, with a bipartisan "core infrastructure” bill that has passed in the Senate and House of Representatives and was signed into law on November 15, 2021, which includes climate provisions focused on transportation and resiliency and an expected multi-trillion budget social spending bill that is being advanced under the reconciliation process to address additional priorities, including the climate impacts of energy production. A Clean Electricity Standard, or similar program, remains a goal of the Biden Administration, despite an unclear political path forward. The reconciliation bill may also include energy tax credits, which are expected to incentivize producers and purchasers of certain forms of energy, such as solar, wind, and nuclear, but not other forms of energy production. Although the social spending bill and Clean Electricity Standard proposals have not yet resulted in any new legislation being enacted or regulations promulgated, we are closely monitoring both legislative and executive agency action.

In April 2021, President Biden announced that the United States' Nationally Defined Contribution to the international Paris Climate Agreement will be an economy-wide reduction in GHG emissions of 50-52% by 2030, relative to 2005 levels. In advance of the November 2021 Conference of the Parties 26 meeting in Glasgow, Scotland, the Biden Administration released details on its strategy to achieve those targets as part of the "Build Back Better" agenda.

In addition to climate-related initiatives at the federal level, some states have adopted provisions designed to regulate GHG emissions for some industry sectors. Examples include (i) the California cap-and-trade program that requires certain covered entities, including propane companies, to purchase GHG emission allowances, and (ii) the Regional Northeast Gas Initiative, in which a number of states in the northeastern U.S. par