EDGAR 10-K Filing

Company CIK: 884614
Filing Year: 2021
Filename: 884614_10-K_2021_0000884614-21-000065.json

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ITEM 1. BUSINESS
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
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.
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
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,
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
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.
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
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
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
880 Trailers 71% 29%
340 Tractors 5% 95%
680 Railroad tank cars 0% 100%
2,470 Bobtail trucks 9% 91%
320 Rack trucks 12% 88%
2,950 Service and delivery trucks 15% 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
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.
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.
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.
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
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.”
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.
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.
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
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.”
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
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.
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.
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
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.
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
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.
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
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
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
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.
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
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;
•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,
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.
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
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. participate and have agreed to establish cap and trade programs to reduce power plant emissions.
International Regulatory Landscape
In the EU, there is a commitment to cut CO2 emissions by at least 40% by 2030 and EU member states have implemented a range of subsidies and incentives to achieve the EU’s climate change goals. Further, emissions are regulated via a number of means, including the European Union Emissions Trading System (the ‘‘EU ETS’’). The EU ETS is a trading system across the
EU for industrial emissions and is expected to become progressively more stringent over time, including by reducing the number of allowances to emit GHGs.
The adoption and implementation of any U.S. federal, state or local laws or regulations or foreign laws or regulations imposing obligations on, or limiting GHG emissions from, our equipment and operations could require us to incur significant costs to reduce GHG emissions associated with our operations or could adversely affect demand for our energy products. The potential increase in our operating costs could include new costs to operate and maintain our facilities, install new emission controls on our facilities, acquire allowances to authorize our GHG emissions, pay taxes related to our GHG emissions, administer and manage a GHG emissions reduction program, and adversely impact the value of certain assets. We may not be able to pass on resulting increases in costs to customers. In addition, changes in regulatory policies that result in a reduction in the demand for hydrocarbon products and carbon-emitting fuel sources that are deemed to contribute to climate change, or restrict the use of such products or fuel sources, may reduce volumes available to us for processing, transportation, marketing and storage and cause potential increases in costs or production disruptions. These developments could have a material adverse effect on our results of operations, financial results, valuation and useful life of assets, and cash flows.
Changes in data privacy and data protection laws and regulations, particularly in Europe and California, or any failure to comply with such laws and regulations, could adversely affect our business and financial results.
There has been increased public attention regarding the use of personal information and data transfers, accompanied by legislation and regulations intended to strengthen data protection, information security and consumer and personal privacy. The laws in these areas continue to develop and the changing nature of data protection, information security and privacy laws in the U.S., the EU and elsewhere could impact our processing of the personal information of our employees, vendors and customers, which could lead to increased operating costs. The EU adopted the GDPR, which became effective in May 2018 and expanded EU data protections, in certain circumstances, to companies outside of the EU processing data of EU residents, regardless of whether the processing occurs in the EU. Similarly, the State of California legislature passed the California Consumer Privacy Act of 2018 (the “CCPA”), effective January 1, 2020, which grants certain rights to California residents with respect to their personal information, and the California electorate recently approved Proposition 24, the California Privacy Rights Act (the “CPRA”), which will expand the CCPA effective January 1, 2023 and grant additional rights to California residents as well as create a new state privacy regulator. We expect that there will continue to be new laws, regulations and industry standards concerning data privacy and data protection in the U.S., the EU and other jurisdictions, and we cannot yet determine the impact such laws, regulations, interpretations and standards may have on our business.
The GDPR requires companies to satisfy extensive requirements regarding the handling of personal information, including its use, protection and the ability of persons whose data is processed to exercise a number of rights with respect to their personal information, such as correcting or requiring deletion of data about themselves. Supervisory authorities from different EU member states may interpret and apply the GDPR somewhat differently, and the GDPR also permits EU member states to create supplemental national laws, which increases the complexity of compliance. Failure to comply with GDPR requirements could result in penalties of up to €20 million or 4% of worldwide revenue, whichever is greater, for a serious breach. Additionally, in July 2020, the Court of Justice of the European Union (the “CJEU”), the EU’s highest court, issued a landmark ruling in which it invalidated the U.S. - EU Privacy Shield framework for transferring the personal data of EU residents to the United States and suggested that the parties to data transfers can only rely on standard contractual clauses as a valid data transfer mechanism on a case-by-case basis. This ruling, and subsequent commentary on it from local European data protection authorities, have raised questions about the continuing viability of existing legal tools to support data transfers to the U.S., and additional regulatory guidance is likely to be forthcoming. Finally, The United Kingdom’s decision to leave the EU, often referred to as “Brexit,” has created uncertainty with regard to data protection regulation in the United Kingdom. In particular, while the European Commission has issued adequacy decisions that have the effect of authorizing data transfers between the United Kingdom and the European Economic Area, it is unclear how data transfers between the United Kingdom and the rest of the world will be regulated now that the United Kingdom has left the EU.
The CCPA requires companies to make new extensive disclosures to consumers about such companies’ data collection, use, and sharing practices and inform consumers of their personal information rights (such as deletion rights), allows consumers to opt out of data sales to third parties, and provides a new cause of action for data breaches. The CPRA will add more disclosure obligations (including an obligation to disclose retention periods or criteria for categories of personal information), grant consumers additional rights (including rights to correct their data, limit the use and disclosure of sensitive personal information, and opt out of the sharing of personal information for certain targeted behavioral advertising purposes), and impose a requirement that a covered business’ use, retention and sharing of personal information of California residents be reasonably necessary and proportionate to the purposes of collection or processing. The CPRA also creates a new California Privacy Protection Agency (CPPA) to serve as California’s chief privacy regulator, which will likely result in greater regulatory activity and enforcement in the privacy area.
Comprehensive privacy laws with some similarities to the CCPA and CPRA have been proposed or passed at the U.S. federal and state levels, including the Virginia Consumer Data Protection Act, which will take effect on January 1, 2023, and the Colorado Privacy Act, which will take effect on July 1, 2023. The State of Nevada also recently amended its online privacy law to allow consumers to submit requests to prevent websites and online service providers from selling personal information that is collected through a website or online service. Additionally, the Federal Trade Commission and many state attorneys general are interpreting federal and state consumer protection laws to impose standards for the online collection, use, dissemination, and security of data as well as requiring disclosures about these practices.
While we have invested significant time and resources in our GDPR compliance program, emerging and changing data privacy and data protection requirements, including CCPA, CPRA, and Virginia’s and Colorado’s new privacy laws, and any new considerations and requirements that emerge from the CJEU’s ruling, may cause us to incur additional substantial costs or require us to change our business practices. Any failure or perceived failure to comply may result in proceedings or actions against us by government entities or individuals. Moreover, any inquiries or investigations, any other government actions, or any actions by individuals, may be costly to comply with, result in negative publicity, increase our operating costs, require significant management time and attention, and subject us to remedies that may harm our business, including fines, demands or orders that we modify or cease existing business practices.
The provisions of the Dodd-Frank Wall Street Reform and Consumer Protection Act (the “Dodd-Frank Act”), related regulations, and the rules adopted thereunder and other regulations, including the European Market Infrastructure Regulation (the “EMIR”), may have an adverse effect on our ability to use derivative instruments to hedge risks associated with our business.
Our derivative hedging activities are subject to Title VII of the Dodd-Frank Act, which regulates the over-the-counter derivatives market and entities that participate in that market. The Dodd-Frank Act requires the CFTC and the federal banking regulators to implement the Dodd-Frank Act’s provisions through rulemaking, including rules regarding mandatory clearing, trade execution and margin requirements. We expect to qualify for and rely upon an exception from mandatory clearing and trade execution requirements for swaps entered into by commercial end-users to hedge commercial risks. In addition to relief from the clearing mandate, we also expect to qualify for an exception for non-financial end-users from the margin requirements on uncleared swaps. If we are not able to do so and have to post margin as to our uncleared swaps in the future, our costs of entering into and maintaining swaps would be increased.
While most of the CFTC’s rules and regulations under the Dodd-Frank Act have been finalized, some additional rules and regulations have yet to be adopted. It is possible that additional rules and regulations under the Dodd-Frank Act (including position limits as described below) may increase our cost of using derivative instruments to hedge risks associated with our business or may reduce the availability of such instruments to protect against risks we encounter. While costs imposed directly on us due to regulatory requirements for derivatives under the Dodd-Frank Act, such as reporting, recordkeeping and electing the end-user exception from mandatory clearing, are relatively minor, costs imposed upon our counterparties may increase the cost of our doing business in the derivatives markets to the extent such costs are passed on to us.
If we become subject to position limits, our ability to hedge risks would be further limited and we would be subject to additional compliance and reporting obligations. The CFTC has re-proposed position limits for certain futures and option contracts in the major energy markets and for swaps that are their economic equivalents, although certain bona fide hedging transactions would be exempt from these position limits. The CFTC has also finalized a rule that requires market participants to aggregate their positions with those of certain other persons under common ownership or control for purposes of determining compliance with applicable position limits. If adopted, the revised position limit rule and its finalized companion rule on aggregation may adversely impact our ability to hedge exposure to price fluctuation of certain commodities. In addition to the CFTC federal position limit regime, designated contract markets also have established position limits and accountability regimes. We may have to modify trading decisions or liquidate positions to avoid exceeding such limits or at the direction of the relevant exchange to comply with accountability levels. Further, any such position limit regime, whether imposed at the federal level or by a designated contract market, may impose added operating costs to monitor compliance with such position limit levels, addressing accountability level concerns and maintaining appropriate exemptions, if applicable.
The EMIR may result in increased costs for over-the-counter derivative counterparties trading in the EU and may also lead to an increase in the costs of, and demand for, the liquid collateral that the EMIR requires central counterparties to accept. Although we expect to qualify as a non-financial counterparty under the EMIR, and thus not be required to post margin under the EMIR, we may still be subject to increased regulatory requirements, including recordkeeping, marking to market, timely confirmations, derivatives reporting, portfolio reconciliation and dispute resolution procedures. Provisions under the EMIR could significantly increase the cost of derivatives contracts, materially alter the terms of derivatives contracts and reduce the
availability of derivatives to protect against risks that we encounter. The increased trading costs and collateral costs may have an adverse impact on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.
Accordingly, our business and operating results may be adversely affected if we are forced to reduce or modify our current use of derivatives as a result of the Dodd-Frank Act and the rules and regulations promulgated thereunder as a result of the EMIR and other similarly applicable rules and regulations.
General Risks that May Impact Our Business and Our Shareholders
The COVID-19 pandemic and the spread of variant strains could adversely impact our business, financial condition and results of operations.
The COVID-19 pandemic, including the spread of variant strains, has resulted in widespread impacts on the global economy and on our employees, customers, third-party business partners and other stakeholders. There is considerable uncertainty regarding the extent to which COVID-19 and variant strains will continue to spread and the extent and duration of domestic and global measures designed to contain the spread, including travel bans and restrictions, quarantines, shelter-in-place orders, vaccination mandates and business and government shutdowns. These restrictions may, among other things:
•negatively impact the financial condition of our customers and their ability to pay for our products and services;
•reduce energy consumption by certain of our customers, which would affect demand for our products;
•disrupt or delay progress in the development and completion of our energy infrastructure projects;
•prolong the time period necessary to perform maintenance of our infrastructure;
•result in operational delays, including delay in the delivery of our products to customers;
•result in temporary or permanent shortages in our workforce;
•result in impairment relating to certain current and long-lived assets;
•delay the timeliness of our ability to source goods; and
•limit or curtail significantly or entirely the ability of public utility commissions to approve or authorize applications and other requests we may make with respect to our regulated businesses.
Additionally, while we have modified or restricted certain business and workforce practices (including employee travel, presence at employee work locations, and physical participation in meetings, events, and conferences) to protect the health and safety of our workforce, and to conform to government orders, as well as regulatory and public health authority guidance, we depend on our workforce to operate our facilities, deliver our products and provide services to customers. If a large portion of our operational workforce were to contract COVID-19 simultaneously, we would rely upon our business continuity plans in an effort to continue operations, but there is no certainty that such measures would be sufficient to mitigate the adverse impact to our operations.
We are also monitoring announcements by the Biden Administration requiring that: (i) certain employees working on or in connection with covered federal government contracts or subcontracts become fully vaccinated against COVID-19, with limited exceptions; and (ii) employers with workforces of more than 100 employees require their employees to either become fully vaccinated for COVID-19 or be subjected to weekly testing. The deadlines for these requirements remain fluid; however, both are currently expected to be effective in January 2022. Failure to comply with these requirements may result in monetary penalties to the employer for each violation. While we are still assessing the potential impact of the foregoing, including monitoring legal challenges to the rules, we may incur monetary costs and/or experience a reduction in our workforce, which may adversely impact our operational continuity, financial condition and/or results of operations.
Finally, if we seek to raise additional capital, our access to and cost of financing will depend on, among other things, global economic conditions, conditions in the financing and equity markets, the availability of sufficient amounts of financing, our prospects and our credit ratings. Our total available liquidity balance as of September 30, 2021 totaled approximately $2.2 billion. Nonetheless, if our credit ratings were to be downgraded, or general market conditions were to ascribe higher risk to our rating levels, our industry, or us, our access to capital and the cost of any future debt financing could be further negatively impacted. In addition, the terms of future debt agreements could include more restrictive covenants, or require incremental collateral, which may further restrict our business operations or conflict with covenant restrictions then in effect. As a result, there is no guarantee that financings will be available in the future to fund our obligations, or that they will be available on terms consistent with our expectations.
The degree to which COVID-19 and variant strains may impact our business operations, financial condition, liquidity and results of operations is unknown at this time and will depend on future developments, including the continued spread of the virus and its variants, the severity of the disease, the duration of the pandemic, actions prescribed or ordered by governmental
authorities, public health authority guidance, and when and to what extent economic and operating conditions can return to pre-pandemic levels.
We may not be able to collect on the accounts of our customers.
We depend on the viability of our customers for collections of accounts receivable and notes receivable. Moreover, our businesses serve numerous retail customers, and as we grow our businesses organically and through acquisitions, our retail customer base is expected to expand. There can be no assurance that our customers will not experience financial difficulties in the future or that we will be able to collect all of our outstanding accounts receivable or notes receivable. Any such nonpayment by our customers could adversely affect our business.
We are subject to operating and litigation risks that may not be covered by insurance.
Our business operations are subject to all of the operating hazards and risks normally incidental to the handling, storage and distribution of combustible products, such as LPG and natural gas, and the generation of electricity. These risks could result in substantial losses due to personal injury and/or loss of life, and severe damage to and destruction of property and equipment arising from explosions and other catastrophic events, including acts of terrorism. As a result of these and other incidents, we are sometimes a defendant in legal proceedings and litigation arising in the ordinary course of business, including regulatory investigations, claims, lawsuits and other proceedings. Additionally, environmental contamination or other incidents resulting in an environmental impact could result in future legal or regulatory proceedings. There can be no assurance that our insurance coverage will be adequate to protect us from all material expenses related to pending and future claims or that such levels of insurance would be available in the future at economical prices. Moreover, defense and settlement costs may be substantial, even with respect to claims and investigations that have no merit. If we cannot resolve these matters favorably, our business, financial condition, results of operations and future prospects may be materially adversely affected.
The risk of natural disasters, pandemics and catastrophic events, including terrorism, may adversely affect the economy and the price and availability of LPG, other refined fuels and natural gas.
Natural disasters, pandemics and catastrophic events, such as fires, earthquakes, explosions, floods, tornadoes, hurricanes, terrorist attacks, political unrest and other similar occurrences, may adversely impact the demand for, price and availability of LPG (including propane), other refined fuels and natural gas, which could adversely impact our financial condition and results of operations, our ability to raise capital and our future growth. The impact that the foregoing may have on our industries in general, and on us in particular, is not known at this time. A natural disaster, pandemic or an act of terror could result in disruptions of crude oil or natural gas supplies and markets (the sources of LPG), cause price volatility in the cost of LPG, fuel oil and natural gas, and our infrastructure facilities could be directly or indirectly impacted. Additionally, if our means of supply transportation, such as rail, truck or pipeline, are delayed or temporarily unavailable due to a natural disaster, pandemic or terrorist activity, we may be unable to transport LPG and other refined fuels in a timely manner or at all. A lower level of economic activity could result in a decline in energy consumption, which could adversely affect our revenues or restrict our future growth. Instability in the financial markets as a result of a natural disaster, pandemic or terrorism could also affect our ability to raise capital. We have opted to purchase insurance coverage for natural disasters and terrorist acts within our property and casualty insurance programs, but we can give no assurance that our insurance coverage would be adequate to fully compensate us for any losses to our business or property resulting from natural disasters or terrorist acts.
Our holding company structure could limit our ability to pay dividends or service debt.
We are a holding company whose material assets are the stock of our subsidiaries. Our ability to pay dividends on our common stock and to pay principal and accrued interest on our debt, if any, depends on the payment of dividends to us by our principal subsidiaries, AmeriGas, Inc., UGI Utilities, Inc., Mountaintop Energy Holdings, LLC and Enterprises (including Energy Services and UGI International’s subsidiaries in Europe, which may be subject to complexities regarding the repatriation of funds to the U.S.). Payments to us by those subsidiaries, in turn, depend upon their consolidated results of operations and cash flows. The operations of our subsidiaries are affected by conditions beyond our control, including weather, regulations, competition in national and international markets we serve, the costs and availability of propane, butane, natural gas, electricity, and other energy sources and capital market conditions. The ability of our subsidiaries to make payments to us is also affected by the level of indebtedness of our subsidiaries, which is substantial, and the restrictions on payments to us imposed under the terms of such indebtedness.
Volatility in credit and capital markets may restrict our ability to grow, increase the likelihood of defaults by our customers and counterparties and adversely affect our operating results.
Volatility in credit and capital markets may create additional risks to our businesses in the future. We are exposed to financial market risk (including refinancing risk) resulting from, among other things, changes in interest rates and conditions in the credit and capital markets. Adverse developments in the credit markets may increase our possible exposure to the liquidity, default and credit risks of our suppliers and vendors, counterparties associated with derivative financial instruments and our customers. Although we believe that current financial market conditions, if they were to continue for the foreseeable future, will not have a significant impact on our ability to fund our existing operations, less favorable market conditions could restrict our ability to grow through acquisitions, limit the scope of major capital projects if access to credit and capital markets is limited, or adversely affect our operating results.
We depend on our intellectual property and failure to protect that intellectual property could adversely affect us.
We seek trademark protection for our brands in each of our businesses, and we invest significant resources in developing our business brands. Failure to maintain our trademarks and brands could adversely affect our customer-facing businesses and our operational results.
Declines in the stock market and a low interest rate environment may negatively impact our pension liability.
Declines in the stock market and a low interest rate environment historically have resulted in a significant impact on our pension liability and funded status. Declines in the stock or bond market and valuation of stocks or bonds, combined with low interest rates, could further impact our pension liability and funded status and increase the amount of required contributions to our pension plans.
Unless we otherwise consent in writing, our Amended and Restated Bylaws designate a state court located in Montgomery County, Pennsylvania or, if no state court located within such county has jurisdiction over such action or proceeding, the federal United States District Court for the Eastern District of Pennsylvania, as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our shareholders, which could discourage lawsuits against us and our directors and officers.
Our Amended and Restated Bylaws provide that, unless we otherwise consent in writing, a state court located in Montgomery County, Pennsylvania or, if no state court located within such county has jurisdiction over such action or proceeding, the federal United States District Court for the Eastern District of Pennsylvania, as the sole and exclusive forum for: (a) any derivative action or proceeding brought on behalf of us; (b) any action or proceeding asserting a claim of breach of duty owed to us or our shareholders by any director, officer, or other employee of ours; (c) any action or proceeding asserting a claim against us or against any of our directors, officers or other employees arising pursuant to, or involving any interpretation or enforcement of, any provision of the Pennsylvania Associations Code, Pennsylvania Business Corporation Law of 1988, or our Amended and Restated Articles of Incorporation or Amended and Restated Bylaws; and (d) any action or proceeding asserting a claim peculiar to the relationship between or among us and our officers, directors, and shareholders, or otherwise governed by or involving the internal affairs doctrine. This exclusive forum provision does not apply to suits brought to enforce a duty or liability created by the Exchange Act or the Securities Act.
This exclusive forum provision may limit the ability of our shareholders to bring a claim in a judicial forum that such shareholders find favorable for disputes with us or our directors or officers, which may discourage such lawsuits against us and our directors and officers. Alternatively, if a court outside of Pennsylvania were to find this exclusive forum provision inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings described above, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our business, results of operations and financial condition.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
ITEM 1B. UNRESOLVED STAFF COMMENTS
None.

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ITEM 2. PROPERTIES

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ITEM 3. LEGAL PROCEEDINGS
ITEM 3. LEGAL PROCEEDINGS
With the exception of those matters set forth in Note 17 to Consolidated Financial Statements included in Item 15 of this Report, no material legal proceedings are pending involving the Company, any of its subsidiaries, or any of their properties, and
no such proceedings are known to be contemplated by governmental authorities other than claims arising in the ordinary course of business.

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ITEM 4. MINE SAFETY DISCLOSURE
ITEM 4. MINE SAFETY DISCLOSURES
None.
EXECUTIVE OFFICERS
Information regarding our executive officers is included in Part III of this Report and is incorporated in Part I by reference.
PART II:

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
ITEM 5.MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
Market Information and Dividend Policy
Our Common Stock is traded on the New York Stock Exchange under the symbol “UGI.” On November 12, 2021, we had 6,569 holders of record of Common Stock.
Payment of dividends is subject to declaration by the Board of Directors. Factors considered in determining dividends include our profitability and expected capital needs. Subject to these qualifications, we presently expect to continue to pay dividends on a quarterly basis.
Equity Compensation Plan Information
Information regarding the securities authorized for issuance under our equity compensation plans can be found under Part III of this Report.
Issuer Purchases of Equity Securities
The Company did not repurchase any shares of its Common Stock during the quarter ended September 30, 2021. As of September 30, 2021, the Company had 5.85 million shares of Common Stock available for repurchase under an extension of a previous share repurchase program announced by the Company on January 25, 2018. The Board of Directors authorized the repurchase of up to 8 million shares of Common Stock over a four-year period expiring January 2022.
Recent Sale of Unregistered Securities
The Company did not sell any unregistered securities during Fiscal 2021.
Performance Graph
The following graph compares the cumulative total shareholder return (stock price appreciation and the reinvestment of dividends) on an investment of $100 in UGI Common Stock, the S&P 500 Index, and the S&P 500 Utilities Index over the five years from September 30, 2016, through September 30, 2021.

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ITEM 6. SELECTED FINANCIAL DATA
ITEM 6.SELECTED FINANCIAL DATA
Intentionally omitted.

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
ITEM 7.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
MD&A discusses our results of operations for Fiscal 2021 and Fiscal 2020, and our financial condition. For discussion of our results of operations and cash flows for Fiscal 2020 compared with Fiscal 2019, refer to “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our Fiscal 2020 Annual Report on Form 10-K, filed with the SEC on November 20, 2020. MD&A should be read in conjunction with Items 1 and 2, “Business and Properties,” Item 1A, “Risk Factors,” and the Consolidated Financial Statements in Item 8 below including “Segment Information” included in Note 23 to Consolidated Financial Statements.
Because most of our businesses sell or distribute energy products used in large part for heating purposes, our results are significantly influenced by temperatures in our service territories, particularly during the heating-season months of October through March. Accordingly, our results of operations, after adjusting for the effects of gains and losses on derivative instruments not associated with current-period transactions as further discussed below, are significantly higher in our first and second fiscal quarters.
Executive Overview
Recent Developments
Acquisition of Mountaineer Gas Company
On September 1, 2021, UGI acquired Mountaineer, the largest natural gas distribution company in West Virginia for a purchase price of $540 million, which includes the assumption of approximately $140 million principal amounts of long-term debt. Mountaineer serves nearly 214,000 customers across 50 of the state’s 55 counties. Mountaineer is subject to regulation by the WVPSC. The Mountaineer Acquisition was funded with cash proceeds from the 2021 UGI Corporation Senior Credit Facility and the issuance of Equity Units and cash on hand. The Mountaineer business is included in the UGI Utilities segment as of the acquisition date. For additional information on the Mountaineer Acquisition and the associated financings, see Notes 5, 6 and 13 to the consolidated financial statements.
COVID-19 Pandemic
In March 2020, the WHO declared a global pandemic attributable to the outbreak and continued spread of COVID-19 that has had a significant impact throughout the global economy. In connection with the mitigation and containment procedures recommended by the WHO, the CDC, and as imposed by federal, state, and local governmental authorities, including shelter-in-place orders, quarantines and similar restrictions, we implemented a variety of procedures to protect our employees, third-party business partners, and customers worldwide. Although our results continue to be impacted by COVID-19, we continue to provide essential products and services to our global customers in a safe and reliable manner and will continue to do so in compliance with mandated restrictions presented by each of the markets we serve. We continue to evaluate and react to the potential effects of a prolonged disruption and the continued impact on our results of operations. These items may include, but are not limited to: the financial condition of our customers; decreased availability and demand for our products and services; realization of accounts receivable; impairment considerations related to certain current assets, long-lived assets and goodwill; delays related to current and future projects; and the effects of government stimulus efforts including tax legislation (see “Interest Expense and Income Taxes” below and Note 7 to the consolidated financial statements) in response to COVID-19.
We cannot predict the duration or total magnitude of the pandemic and the total effects on our business, financial position, results of operations, liquidity or cash flows at this time, but we remain focused on managing our financial condition and liquidity throughout this global crisis.
Strategic Initiatives
Business Transformation Initiatives
Corporate Services. Beginning in Fiscal 2020, we initiated a transformation project focused on our support functions including: finance, procurement, human resources, and information technology. This initiative will standardize processes and
activities across our global platform, while leveraging the use of best practices and efficiencies between our businesses. While this initiative is being coordinated across multiple support functions, each area is at a different stage of transformation and will undergo the required changes over a two to three year period. In connection with these activities, we expect to incur approximately $40 million of non-recurring costs during that time resulting in more than $15 million of ongoing annualized savings by the end of Fiscal 2023.
AmeriGas Propane: At AmeriGas Propane, we began executing on business transformation initiatives during Fiscal 2019 focused on efficiency and effectiveness in the following key areas: customer digital experience; customer relationship management; operating process redesign and specialization; distribution and routing optimization; sales and marketing effectiveness; purchasing and general and administrative efficiencies; and supply and logistics. 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. These benefits will allow us to continue to improve profitability and cash flow through operational efficiencies and expense reductions and enable increased investment into base business customer retention and growth initiatives, including the reduction of margins in select segments of our base business. The total cost of executing on these initiatives, including approximately $110 million of related capital expenditures, will amount to approximately $220 million.
UGI International. At our UGI International LPG business, we launched an initiative in Fiscal 2019 and embarked on a process of identifying operational synergies across all 17 countries in which we currently do business. The goal of this initiative (Project Alliance) 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 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. The total cumulative cost of executing these Project Alliance initiatives, including approximately €10 million related to IT capital expenditures, will amount to approximately €55 million.
Non-GAAP Financial Measures
UGI management uses “adjusted net income attributable to UGI Corporation” and “adjusted diluted earnings per share,” both of which are non-GAAP financial measures, when evaluating UGI’s overall performance. Management believes that these non-GAAP measures provide meaningful information to investors about UGI’s performance because they eliminate gains and losses on commodity and certain foreign currency derivative instruments not associated with current-period transactions and other significant discrete items that can affect the comparison of period-over-period results.
UGI does not designate its commodity and certain foreign currency derivative instruments as hedges under GAAP. Volatility in net income attributable to UGI Corporation can occur as a result of gains and losses on such derivative instruments not associated with current-period transactions. These gains and losses result principally from recording changes in unrealized gains and losses on unsettled commodity and certain foreign currency derivative instruments and, to a much lesser extent, certain realized gains and losses on settled commodity derivative instruments that are not associated with current-period transactions. However, because these derivative instruments economically hedge anticipated future purchases or sales of energy commodities, or in the case of certain foreign currency derivatives, reduce volatility in anticipated future earnings associated with our foreign operations, we expect that such gains or losses will be largely offset by gains or losses on anticipated future energy commodity transactions or mitigate volatility in anticipated future earnings. Non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measures.
The following tables reflect the adjustments referred to above and reconcile net income attributable to UGI Corporation, the most directly comparable GAAP measure, to adjusted net income attributable to UGI Corporation, and reconcile diluted earnings per share, the most comparable GAAP measure, to adjusted diluted earnings per share:
Year Ended September 30,
(Millions of dollars, except per share amounts) 2021 2020
Adjusted net income attributable to UGI Corporation:
AmeriGas Propane $ 168 $ 156
UGI International 221 173
Midstream & Marketing 107 92
UGI Utilities 144 136
Corporate & Other (a) 827 (25)
Net income attributable to UGI Corporation 1,467 532
Net gains on commodity derivative instruments not associated with current-period transactions (net of tax of $389 and $35, respectively) (1,001) (82)
Unrealized (gains) losses on foreign currency derivative instruments (net of tax of $2 and $(10), respectively) (6) 26
Acquisition and integration expenses associated with the CMG Acquisition (net of tax of $0 and $(1), respectively) - 1
Business transformation expenses (net of tax of $(27) and $(17), respectively) 74 45
Loss on disposals of Conemaugh and HVAC (net of tax of $0 and $(15), respectively) - 39
Acquisition and integration expenses associated with the Mountaineer Acquisition (net of tax of $(4) and $0, respectively) 10 -
Impairment of customer relationship intangible (net of tax of $(5) and $0, respectively) 15 -
Impairment of investment in PennEast (net of tax of $0 and $0, respectively) 93 -
Impact of change in Italian tax law (23) -
Total adjustments (a) (b) (838) 29
Adjusted net income attributable to UGI Corporation $ 629 $ 561
Adjusted diluted earnings per share:
AmeriGas Propane $ 0.79 $ 0.74
UGI International 1.04 0.82
Midstream & Marketing 0.51 0.44
UGI Utilities 0.68 0.65
Corporate & Other (a) 3.90 (0.11)
Earnings per share - diluted 6.92 2.54
Net gains on commodity derivative instruments not associated with current-period transactions (4.72) (0.39)
Unrealized (gains) losses on foreign currency derivative instruments (0.03) 0.12
Acquisition and integration expenses associated with the CMG Acquisition - 0.01
Business transformation expenses 0.35 0.21
Loss on disposals of Conemaugh and HVAC - 0.18
Acquisition and integration expenses associated with the Mountaineer Acquisition 0.04 -
Impairment of customer relationship intangible 0.07 -
Impairment of investment in PennEast 0.44 -
Impact of change in Italian tax law (0.11) -
Total adjustments (a) (3.96) 0.13
Adjusted diluted earnings per share $ 2.96 $ 2.67
(a)Corporate & Other includes certain adjustments made to our reporting segments in arriving at net income attributable to UGI Corporation. These adjustments have been excluded from the segment results to align with the measure used by our CODM in assessing segment performance and allocating resources. See Note 23 to Consolidated Financial Statements for additional information related to these adjustments, as well as other items included within Corporate & Other.
(b)Income taxes associated with pre-tax adjustments determined using statutory business unit tax rates.
Fiscal 2021 Compared with Fiscal 2020
Discussion. Net income attributable to UGI Corporation was $1,467 million for Fiscal 2021 (equal to $6.92 per diluted share) compared to $532 million for Fiscal 2020 (equal to $2.54 per diluted share). Net income attributable to UGI Corporation in Fiscal 2021 reflects a $951 million year-over-year increase in net unrealized gains on commodity derivative instruments and certain foreign currency derivative instruments. This increase is primarily attributable to the significant rise in commodity prices during Fiscal 2021, and has contributed to the accumulation of substantial derivative assets related to the Company’s commodity derivative instruments at September 30, 2021. Fiscal 2021 net income attributable to UGI Corporation also reflects higher business transformation expenses, impairments of investments and long-lived assets, and acquisition and integration expenses compared to the prior year, as well as a $23 million tax benefit related to an election made in connection with a tax law change in Italy. Fiscal 2020 net income attributable to UGI Corporation includes a $39 million loss on assets that were disposed of in September 2020.
Adjusted net income attributable to UGI Corporation for Fiscal 2021 was $629 million (equal to $2.96 per diluted share) compared to adjusted net income attributable to UGI Corporation for Fiscal 2020 of $561 million (equal to $2.67 per diluted share). The increase in adjusted net income attributable to UGI Corporation during Fiscal 2021 reflects higher earnings contributions from each of our four business segments including improved margin at UGI International which benefited from colder weather compared to the prior year and the translation effects of stronger foreign currencies. Higher average LPG unit margins including the continued effects of margin management efforts, the increase in base rates at UGI Utilities, Inc. in Fiscal 2021, and the effects of acquisitions and assets placed into service since the fourth quarter of Fiscal 2020 also contributed to the improvement. These positive impacts were partially offset by higher depreciation and amortization expense and a lower benefit under the CARES Act compared to the prior year.
AmeriGas Propane’s adjusted net income attributable to UGI Corporation increased $12 million during Fiscal 2021. This increase principally reflects lower operating and administrative expenses, including partial benefits related to the execution of transformation initiatives, higher other income attributable to customer fees and gains on the early settlement of certain commodity derivative instruments during Fiscal 2021, and lower interest and depreciation and amortization expense compared to the prior year. These positive factors were partially offset by lower retail propane margin primarily attributable to lower volumes.
UGI International’s adjusted net income attributable to UGI Corporation increased $48 million during Fiscal 2021 principally reflecting increased LPG volumes which benefited from colder weather compared to Fiscal 2020, higher average LPG unit margins including effective margin management efforts, and the translation effects of stronger foreign currencies. These positive factors were partially offset by higher operating and administrative expenses reflecting increased maintenance and distribution costs attributable to the stronger LPG volumes compared to Fiscal 2020, as well as the previously mentioned effects of stronger foreign currencies.
Midstream & Marketing adjusted net income in Fiscal 2021 was $15 million higher than the prior year. This increase principally reflects incremental margin from capacity management and renewable energy marketing activities, and lower operating and administrative expenses largely related to the impact of divested assets.
UGI Utilities Fiscal 2021 adjusted net income increased $8 million compared to the prior year. This increase reflects higher natural gas margin largely attributable to the increase in base rates that went into effect in Fiscal 2021 and higher margin from large delivery service customers, and an increase in Electric Utility margin resulting from higher volumes compared to the prior year. These improvements were partially offset by higher operating and administrative expenses attributable to the effects of the Mountaineer Acquisition and increased depreciation expense related to continued capital expenditure activity.
AmeriGas Propane 2021 2020 Increase (Decrease)
(Dollars in millions)
Revenues $ 2,614 $ 2,381 $ 233 10 %
Total margin (a) $ 1,397 $ 1,421 $ (24) (2) %
Operating and administrative expenses $ 869 $ 890 $ (21) (2) %
Operating income / earnings before interest expense and income taxes $ 385 $ 373 $ 12 3 %
Retail gallons sold (millions) 968 987 (19) (2) %
Degree days - % warmer than normal (b) (2.8) % (0.7) % - -
(a)Total margin represents revenues less cost of sales.
(b)Beginning in Fiscal 2021, deviation from average heating degree days is determined on a rolling 10-year period utilizing volume-weighted weather data based on weather statistics provided by NOAA for 344 regions in the United States, excluding Alaska and Hawaii. Prior-period amounts have been restated to conform to the current-period presentation.
Average temperatures during Fiscal 2021 were 2.8% warmer than normal and 2.2% warmer than the prior year. Total retail gallons sold decreased during Fiscal 2021 principally reflecting structural conservation and other residual volume loss and the greater impact of COVID-19 on commercial volumes compared to Fiscal 2020. These decreases were partially offset by higher resale and motor fuel volumes during Fiscal 2021.
Total revenues increased $233 million during Fiscal 2021 largely reflecting higher average propane selling prices ($255 million) and increased wholesale volumes ($26 million) partially offset by the lower retail propane volumes ($39 million) compared to Fiscal 2020. Average daily wholesale propane commodity prices during Fiscal 2021 at Mont Belvieu, Texas, one of the major supply points in the U.S., were approximately 97% higher than such prices during Fiscal 2020. Total cost of sales increased $257 million during Fiscal 2021 largely attributable to the higher average propane product costs ($245 million) and higher wholesale propane volumes ($24 million), partially offset by the lower retail propane volumes ($16 million).
AmeriGas Propane total margin decreased $24 million in Fiscal 2021 largely attributable to the lower retail propane volumes ($24 million) and decreased non-propane margin ($13 million) principally reflecting lower fees and services partially offset by increased cylinder sales. These decreases were partially offset by higher average propane margin ($10 million) resulting from the rising propane cost environment and effective margin management efforts.
Operating income and earnings before interest expense and income taxes increased $12 million during Fiscal 2021 reflecting lower operating and administrative expenses ($21 million) compared to Fiscal 2020, higher other income ($10 million) attributable to customer fees and gains on the early settlement of certain commodity derivative instruments during Fiscal 2021, and lower depreciation and amortization expense ($5 million). These positive impacts were largely offset by the previously mentioned decrease in total margin ($24 million). The decrease in operating and administrative expenses in Fiscal 2021 reflects, among other things, lower employee compensation and benefits-related costs ($26 million), decreased equipment operating and maintenance expenses ($7 million), and lower general insurance costs ($4 million) compared to Fiscal 2020. These decreases were partially offset by increased advertising expenses ($7 million) and higher vehicle lease expense ($4 million) compared to Fiscal 2020. The lower operating and administrative expenses reflect the partial benefits related to the previously mentioned ongoing business transformation initiatives.
UGI International 2021 2020 Increase
(Dollars in millions)
Revenues $ 2,651 $ 2,127 $ 524 25 %
Total margin (a) $ 1,053 $ 908 $ 145 16 %
Operating and administrative expenses $ 622 $ 545 $ 77 14 %
Operating income $ 314 $ 241 $ 73 30 %
Earnings before interest expense and income taxes $ 317 $ 259 $ 58 22 %
LPG retail gallons sold (millions) 792 757 35 5 %
Degree days - % colder (warmer) than normal (b) 0.4 % (12.7) % - -
(a)Total margin represents total revenues less total cost of sales and in Fiscal 2020, LPG cylinder filling costs of $28 million. For financial statement purposes, LPG cylinder filling costs in Fiscal 2020 are included in “Operating and administrative expenses” on the 2020 Consolidated Statement of Income (but are excluded from operating and administrative expenses presented above). LPG cylinder filling costs are included in “Cost of sales” on the 2021 Consolidated Statement of Income.
(b)Beginning in Fiscal 2021, deviation from average heating degree days is determined on a rolling 10-year period utilizing volume-weighted weather data at locations in our UGI International service territories. Prior-period amounts have been restated to conform to the current-period presentation.
Average temperatures during Fiscal 2021 were slightly colder than normal and 14.1% colder than Fiscal 2020. Total LPG retail gallons sold during Fiscal 2021 increased 5% compared to Fiscal 2020 largely attributable to higher bulk volumes reflecting the effects of the colder weather on heating-related bulk sales. These volume improvements also reflect small acquisitions in Switzerland and Finland and the recovery of certain volume decreases attributable to COVID-19 during Fiscal 2021, and were partially offset by the termination of a high-volume, low-margin autogas contract in Italy during Fiscal 2020. Average wholesale prices for propane and butane during Fiscal 2021 in northwest Europe were approximately 52% and 33% higher, respectively, compared to Fiscal 2020.
UGI International base-currency results are translated into U.S. dollars based upon exchange rates experienced during the reporting periods. The functional currency of a significant portion of our UGI International results is the euro and, to a much lesser extent, the British pound sterling. During Fiscal 2021 and Fiscal 2020, the average unweighted euro-to-dollar translation rates were approximately $1.20 and $1.12, respectively, and the average unweighted British pound sterling-to-dollar translation rates were approximately $1.37 and $1.28, respectively. Fluctuations in these foreign currency exchange rates can have a significant impact on the individual financial statement components discussed below. The net effect of changes in foreign currency exchange rates on UGI International’s earnings before interest expense and income taxes resulted in a net benefit of $26 million in Fiscal 2021. However, the impact of these changes is mitigated by the effects of forward foreign currency exchange contracts entered into over a multi-year period intended to substantially offset this volatility. These forward foreign currency exchange contracts resulted in realized net gains of $1 million and $15 million, respectively, in Fiscal 2021 and Fiscal 2020.
UGI International revenues and cost of sales increased $524 million and $379 million, respectively, during Fiscal 2021. The increase in revenues and cost of sales principally reflects the translation effects of stronger foreign currencies (approximately $174 million and $102 million, respectively), the effects of higher average butane and propane selling prices and product costs compared to Fiscal 2020, and the previously mentioned increase in bulk volumes. Energy marketing activities also contributed to the increased revenues and cost of sales during Fiscal 2021 largely related to higher natural gas volumes and prices.
UGI International total margin increased $145 million during Fiscal 2021 reflecting the translation effects of stronger foreign currencies (approximately $72 million), the previously mentioned increase in total LPG volumes, lower costs associated with energy conservation certificates, and higher average LPG unit margins including the continued effects of margin management efforts. These margin improvements include the impact of LPG assets acquired in Fiscal 2021 and higher margin from energy marketing activities principally reflecting increased natural gas volumes.
UGI International operating income and earnings before interest expense and income taxes increased $73 million and $58 million, respectively, during Fiscal 2021. The increase in operating income principally reflects the increase in total margin partially offset by higher operating and administrative expenses ($77 million) which was largely attributable to the effects of stronger foreign currencies ($38 million) compared to Fiscal 2020. The increase in operating and administrative expenses also reflects higher maintenance, distribution and employee compensation costs attributable to the increased volumes. The increase in earnings before interest expense and income taxes in Fiscal 2021 largely reflects the increase in operating income partially
offset by lower realized gains on foreign currency exchange contracts entered into in order to reduce volatility in UGI International earnings resulting from the effects of changes in foreign currency exchange rates ($14 million).
Midstream & Marketing 2021 2020 Increase (Decrease)
(Dollars in millions)
Revenues $ 1,406 $ 1,247 $ 159 13 %
Total margin (a) $ 373 $ 355 $ 18 5 %
Operating and administrative expenses $ 129 $ 140 $ (11) (8) %
Operating income $ 160 $ 140 $ 20 14 %
Earnings before interest expense and income taxes $ 190 $ 168 $ 22 13 %
(a)Total margin represents total revenues less total cost of sales.
Average temperatures across Midstream & Marketing’s energy marketing territory during Fiscal 2021 were 6.9% warmer than normal and 2.6% warmer than the prior year. Midstream & Marketing’s prior year results include contributions from operating activities attributable to its HVAC business and ownership interest in Conemaugh, both of which were sold in September 2020. Losses associated with the disposal of these assets are reflected in “Corporate & Other” (see “Non-GAAP Financial Measures” above).
Midstream & Marketing’s revenues increased $159 million compared to the prior year principally reflecting increased revenues from natural gas ($144 million) and renewable energy ($27 million) marketing activities and higher capacity management revenues ($24 million) which were impacted by the timing of certain mark-to-market contract settlements. Higher revenues associated with electricity marketing ($8 million) and natural gas gathering activities ($6 million) also contributed to the increase. These factors were partially offset by the absence of revenues attributable to its former HVAC business and ownership interest in Conemaugh ($59 million). Midstream & Marketing cost of sales was $1,033 million in Fiscal 2021 compared to $892 million in Fiscal 2020. The $141 million increase principally reflects higher cost of sales related to natural gas ($138 million), renewable energy ($20 million), and electricity ($7 million) marketing activities, partially offset by the absence of costs attributable to HVAC and Conemaugh ($30 million). The increases in both natural gas revenues and cost of sales during Fiscal 2021 are largely attributable to higher average natural gas prices compared to the prior year partially offset by lower volumes attributable to weather that was warmer than the prior year.
Midstream & Marketing total margin increased $18 million in Fiscal 2021 reflecting improved capacity management margin ($24 million), higher margin from renewable energy ($7 million) and natural gas ($5 million) marketing activities, and higher margin from natural gas gathering activities ($6 million). These margin improvements include the impact of acquisitions and new assets placed into service since the fourth quarter of Fiscal 2020, and were partially offset by the absence of margins attributable to HVAC and Conemaugh ($29 million).
Midstream & Marketing operating income and earnings before interest expense and income taxes during Fiscal 2021 increased $20 million and $22 million, respectively, compared to the prior year. The increase in operating income principally reflects the increase in total margin and lower operating and administrative expenses compared to the prior year, partially offset by an adjustment to the contingent consideration related to the GHI acquisition ($9 million). The decrease in operating and administrative expenses was largely related to the absence of the previously mentioned divested assets partially offset by an increase in employee and benefits-related costs and increases related to new assets placed into service. The increase in earnings before interest expense and income taxes reflects the improvement in operating income and incremental equity method earnings related to the investment in Pine Run.
UGI Utilities 2021 2020 Increase
(Dollars in millions)
Revenues $ 1,079 $ 1,030 $ 49 5 %
Total margin (a) $ 616 $ 577 $ 39 7 %
Operating and administrative expenses (a) $ 254 $ 239 $ 15 6 %
Operating income $ 241 $ 229 $ 12 5 %
Earnings before interest expense and income taxes $ 242 $ 229 $ 13 6 %
Natural gas system throughput - bcf
Core market 77 75 2 3 %
Total 311 310 1 - %
Electric Utility distribution sales - gwh 998 978 20 2 %
Natural gas degree days - % warmer than normal (b) (7.9) % (6.9) % - -
(a)Total margin represents total revenues less total cost of sales and revenue-related taxes (i.e. Electric Utility gross receipts taxes) of $5 million in both Fiscal 2021 and Fiscal 2020. For financial statement purposes, revenue-related taxes are included in “Operating and administrative expenses” on the Consolidated Statements of Income (but are excluded from operating expenses presented above).
(b)Beginning in Fiscal 2021, deviation from average heating degree days is determined on a rolling 10-year period utilizing volume-weighted weather data based on weather statistics provided by NOAA for airports located within UGI Utilities natural gas service territory. Prior-period amounts have been restated to conform to the current-period presentation.
Temperatures in UGI Utilities’ natural gas service territory during Fiscal 2021 were 7.9% warmer than normal and slightly warmer than the prior year. UGI Utilities’ core market volumes increased (2 bcf) during Fiscal 2021 reflecting the effects of continued growth in the number of core market customers and the recovery of certain volume decreases attributable to COVID-19 during Fiscal 2021, partially offset by the warmer weather compared to the prior year. Total natural gas distribution system throughput increased slightly during Fiscal 2021 primarily attributable to the impact of the Mountaineer Acquisition and the increase in core market volumes, partially offset by lower large delivery service volumes. Electric Utility distribution sales volumes increased during Fiscal 2021 primarily attributable to customer growth.
UGI Utilities revenues increased $49 million in Fiscal 2021 reflecting a $42 million increase in natural gas revenues and a $7 million increase in Electric Utility revenues. The increase in natural gas revenues principally reflects the increase in base rates that went into effect as part of a phased approach on January 1, 2021 and July 1, 2021, higher revenues from off system sales, and incremental revenues attributable to the Mountaineer acquisition ($9 million) in September 2021. These factors were partially offset by lower PGC rates compared to the prior year. The increase in Electric Utility revenues during Fiscal 2021 is largely attributable to the increased distribution sales volumes and higher DS rates compared to the prior year.
UGI Utilities cost of sales was $458 million in Fiscal 2021 compared with $448 million in Fiscal 2020 reflecting higher natural gas ($8 million) and Electric Utility ($2 million) cost of sales compared to the prior year. Higher natural gas cost of sales associated with off system sales and incremental cost of sales related to Mountaineer were partially offset by lower PGC rates compared to the prior year. Electric Utility cost of sales increased during Fiscal 2021 reflecting the increased volumes and DS rates compared to the prior year.
UGI Utilities total margin increased $39 million during Fiscal 2021 reflecting higher natural gas margin ($34 million) and Electric Utility margin ($5 million). The increase in natural gas margin reflects higher margin from core market customers ($18 million) largely attributable to the previously mentioned increase in base rates, incremental margin attributable to Mountaineer ($6 million), and higher margin from large delivery service customers. The increased natural gas margin also benefited from the implementation of a DSIC effective April 1, 2021 and higher customer account fees compared to the prior year. The increase in Electric Utility margin is largely attributable to the increase in distribution sales volumes compared to the prior year.
UGI Utilities operating income and earnings before interest expense and income taxes during Fiscal 2021 increased $12 million and $13 million, respectively, compared to the prior year. These increases largely reflect the previously mentioned increase in total margin, partially offset by higher operating and administrative expenses ($15 million) and depreciation expense ($14 million) compared to the prior year. The increase in operating and administrative expenses reflects incremental activities related to Mountaineer ($7 million) as well as higher contracted labor expenses and employee costs. The higher depreciation expense compared to the prior year includes the effects of continued distribution system and IT capital expenditure activity and incremental depreciation attributable to Mountaineer.
Interest Expense and Income Taxes
Our consolidated interest expense during Fiscal 2021 was $310 million compared to $322 million during the prior year. The $12 million decrease in interest expense principally reflects lower average short-term borrowings outstanding compared to the prior year, partially offset by incremental interest on the UGI Utilities, Inc.’s senior notes issued during the year.
Our effective income tax rate increased between Fiscal 2021 and Fiscal 2020 due primarily to an increase in the concentration of foreign earnings largely attributable to gains on commodity derivatives reflecting foreign statutory tax rates that exceed the U.S. statutory rate and a lower NOL benefit under the CARES Act compared to the prior year. These items were partially offset by an election made in the current year available under a tax law change in Italy which allowed the Company to step up its tax basis on certain assets in exchange for paying a three percent substitute tax in connection with such election. This election resulted in a $23 million net benefit in the current period resulting in incremental tax basis that will be deductible in future periods. For additional information on our income taxes, including tax law changes, see Note 7 to Consolidated Financial Statements.
Financial Condition and Liquidity
The Company expects to have sufficient liquidity including cash on hand and available borrowing capacity to continue to support long-term commitments and ongoing operations despite uncertainties associated with the outbreak and continued impact of COVID-19. Our total available liquidity balance, comprising cash and cash equivalents and available borrowing capacity on our revolving credit facilities, totaled approximately $2.2 billion and $1.5 billion at September 30, 2021 and 2020, respectively. Our total available liquidity at September 30, 2021 includes $468 million of cash collateral received from derivative counterparties resulting from the impact of rising commodity prices and an accumulation of derivative assets associated with our commodity derivative instruments. The Company does not have any near-term senior note or term loan maturities. While the Company’s operations and financial performance continue to be impacted by COVID-19, it is a rapidly evolving situation and the Company cannot predict the ultimate impact that COVID-19 will have on its liquidity, debt covenants, financial condition or the timing of capital expenditures. UGI and its subsidiaries were in compliance with all debt covenants as of September 30, 2021.
We depend on both internal and external sources of liquidity to provide funds for working capital and to fund capital requirements. Our short-term cash requirements not met by cash generated from operations are generally satisfied with borrowings under credit facilities and, in the case of Midstream & Marketing, also from a Receivables Facility. Long-term cash requirements are generally met through the issuance of long-term debt or equity securities. We believe that each of our business units has sufficient liquidity in the forms of cash and cash equivalents on hand; cash expected to be generated from operations; credit facility and Receivables Facility borrowing capacity; and the ability to obtain long-term financing to meet anticipated contractual and projected cash commitments. Issuances of debt and equity securities in the capital markets and additional credit facilities may not, however, be available to us on acceptable terms.
The primary sources of UGI’s cash and cash equivalents are the dividends and other cash payments made to UGI or its corporate subsidiaries by its principal business units. Our cash and cash equivalents totaled $855 million at September 30, 2021, compared with $336 million at September 30, 2020. Our cash and cash equivalents at September 30, 2021 includes the previously mentioned $468 million of cash collateral deposits received from our derivative instrument counterparties. This is attributable to significant mark-to-market gains on our commodity derivative instruments resulting from the steep rise in commodity prices during Fiscal 2021. This cash could be returned to such counterparties as commodity prices and their impact to our commodity derivative instruments stabilizes or reverses. Excluding these collateral deposits received and cash and cash equivalents that reside at UGI’s operating subsidiaries, at September 30, 2021 and 2020, our cash and cash equivalents totaled $172 million and $112 million, respectively. Such cash is available to pay dividends on UGI Common Stock and for investment purposes.
During Fiscal 2021 and Fiscal 2020, our principal business units paid cash dividends and made other cash payments to UGI and its subsidiaries as follows:
(Millions of dollars) 2021 2020
AmeriGas Propane $ 135 $ 108
UGI International (a) 212 250
Midstream & Marketing 25 50
UGI Utilities 35 50
Total $ 407 $ 458
(a) Represents cash payments to UGI International’s U.S. holding company subsidiary. Cash dividends in Fiscal 2020 were used, in part, to pay down all outstanding revolving credit facility borrowings on the UGI International Credit Facilities Agreement in September 2020.
Common and Preferred Stock
Issuance of Equity Units
On May 25, 2021, the Company issued 2.2 million Equity Units with a total notional value of $220 million. Each Equity Unit has a stated amount of $100 and consists of (1) a 10% undivided beneficial ownership interest in one share of Convertible Preferred Stock with a liquidation preference of $1,000 per share and (2) a 2024 Purchase Contract. The Company received approximately $213 million in proceeds from the issuance of the Equity Units, net of offering expenses and underwriting costs and commissions, and issued 220,000 shares of Convertible Preferred Stock, recording $213 million in “Preferred stock” on the accompanying Consolidated Balance Sheet. The proceeds were used to pay a portion of the purchase price for the Mountaineer Acquisition and related fees and expenses, and for general corporate purposes. For additional information on the Mountaineer Acquisition and the issuance of Equity Units, see Notes 5 and 13 to the Consolidated Financial Statements.
Dividends
Quarterly dividends per share of UGI Common Stock paid during Fiscal 2021 and Fiscal 2020 were as follows:
2021 2020
1st Quarter
$ 0.330 $ 0.325
2nd Quarter
0.330 0.325
3rd Quarter
0.345 0.330
4th Quarter
0.345 0.330
Total $ 1.350 $ 1.310
On November 18, 2021, UGI’s Board of Directors declared a cash dividend equal to $0.345 per common share. The dividend will be payable on January 1, 2022, to shareholders of record on December 15, 2021.
Repurchases of Common Stock
During Fiscal 2020, the Company repurchased 1 million shares at a total purchase price of $38 million. There were no such repurchases during Fiscal 2021. For additional information on the authorization of these repurchases, see Note 13 to the Consolidated Financial Statements.
Long-term Debt and Credit Facilities
The Company’s debt outstanding at September 30, 2021 and 2020, comprises the following:
2021 2020
(Millions of dollars) AmeriGas Propane UGI International Midstream & Marketing UGI Utilities Corp. & Other Total Total
Short-term borrowings $ 170 $ - $ - $ 197 $ - $ 367 $ 347
Long-term debt (including current maturities):
Senior notes $ 2,575 $ 405 $ - $ 1,290 $ - $ 4,270 $ 3,960
Term loans - 347 684 142 765 1,938 1,741
Other long-term debt 1 23 42 25 192 283 380
Unamortized debt issuance costs (16) (5) (10) (6) (5) (42) (47)
Total long-term debt $ 2,560 $ 770 $ 716 $ 1,451 $ 952 $ 6,449 $ 6,034
Total debt $ 2,730 $ 770 $ 716 $ 1,648 $ 952 $ 6,816 $ 6,381
Significant Financing Activities
Mountaineer. As further described in Note 5 to the consolidated financial statements, UGI acquired Mountaineer on September 1, 2021. Mountaineer has a credit facility agreement which provides for borrowings up to $100 million, with an option to increase the maximum borrowing capacity to $200 million. The credit facility agreement is scheduled to expire in November 2024, with the option to extend the maturity for up to two additional one-year periods. Borrowings under this credit facility agreement bear interest at (1) a prime rate plus a margin or (2) an adjusted LIBOR plus a margin. Such margin is dependent upon Mountaineer’s unsecured debt rating.
Mountaineer also has several unsecured senior notes and principal amounts are due in full at maturity. Interest is payable on a semiannual basis in June and December for each of these senior notes. See Note 6 to the Consolidated Financial Statements for further information on these senior notes.
UGI Utilities, Inc.’s Senior Notes. On May 7, 2021, UGI Utilities, Inc. entered into a Note Purchase Agreement with a consortium of lenders. Pursuant to the Note Purchase Agreement, UGI Utilities, Inc. issued $100 million aggregate principal amount of 1.59% Senior Notes due June 15, 2026 and $75 million aggregate principal amount of 1.64% Senior Notes due September 15, 2026 in June and September 2021, respectively. The net proceeds from these issuances were used to reduce short-term borrowings and for general corporate purposes.
2021 UGI Corporation Senior Credit Facility. On May 4, 2021, UGI amended the existing UGI Corporation Senior Credit Facility. The 2021 UGI Corporation Senior Credit Facility (1) extends the maturity date of the previous three-year $300 million term loan included in the existing UGI Corporation Senior Credit Facility, which is now due in May 2025; and (2) includes a new four-year $215 million term loan commitment. Proceeds from new term loan borrowings under the 2021 UGI Corporation Senior Credit Facility were used to finance a portion of the Mountaineer Acquisition and for general corporate purposes.
Borrowings on the new term loan under the 2021 UGI Corporation Senior Credit Facility bear interest subject to our election, at either (1) the associated prime rate plus a margin or (2) an adjusted LIBOR or an alternate benchmark rate plus a margin and are due in their entirety at the maturity date. The applicable margin on the new borrowings, which is dependent upon a ratio of consolidated net indebtedness to consolidated EBITDA, as defined, or UGI’s credit ratings, ranges from 0.125% to 1.50% if the prime rate option is elected and 1.125% to 2.50% if the LIBOR option is elected.
Credit Facilities
Information about the Company’s principal credit agreements (excluding Energy Services’ Receivables Facility, which is discussed below) as of September 30, 2021 and 2020, is presented in the tables below.
(Currency in millions) Expiration Date Total Capacity Borrowings Outstanding Letters of Credit and Guarantees Outstanding Available Borrowing Capacity Weighted Average Interest Rate - End of Year
September 30, 2021
AmeriGas OLP December 2022 $ 600 $ 170 $ 60 $ 370 2.58 %
UGI International, LLC (a) October 2023 € 300 € - € - € 300 N.A.
Energy Services March 2025 $ 260 $ - $ - $ 260 N.A.
UGI Utilities, Inc. June 2024 $ 350 $ 130 $ - $ 220 1.35 %
Mountaineer November 2024 $ 100 $ 67 $ - $ 33 N.M.
UGI Corporation (b) August 2024 $ 300 $ 185 $ - $ 115 3.27 %
September 30, 2020
AmeriGas OLP December 2022 $ 600 $ 186 $ 62 $ 352 2.61 %
UGI International, LLC (a) October 2023 € 300 € - € - € 300 N.A.
Energy Services March 2025 $ 260 $ - $ - $ 260 N.A.
UGI Utilities, Inc. June 2024 $ 350 $ 141 $ - $ 209 1.12 %
UGI Corporation (b) August 2024 $ 300 $ 300 $ - $ - 2.41 %
(a)The UGI International Credit Facilities Agreement permits UGI International, LLC to borrow in euros or dollars.
(b)Borrowings outstanding have been classified as “Long-term debt” on the Consolidated Balance Sheets. In October 2021 and 2020, the Company repaid $70 million and $30 million, respectively, of such borrowings and classified these repayments as “Current maturities of long-term debt” on the Consolidated Balance Sheets.
N.A. - Not applicable
N.M. - Not meaningful
The average daily and peak short-term borrowings under the Company’s principal credit agreements during Fiscal 2021 and Fiscal 2020 are as follows:
2021 2020
(Currency in millions) Average Peak Average Peak
AmeriGas OLP $ 168 $ 293 $ 245 $ 359
UGI International, LLC € - € - € 158 € 179
Energy Services $ 3 $ 32 $ 18 $ 77
UGI Utilities, Inc. $ 186 $ 279 $ 180 $ 324
Mountaineer $ 58 $ 67 $ - $ -
UGI Corporation $ 191 $ 300 $ 285 $ 300
Receivables Facility. Energy Services also has a Receivables Facility with an issuer of receivables-backed commercial paper. On October 22, 2021, the expiration date of the Receivables Facility was extended to October 21, 2022. The Receivables Facility provides Energy Services with the ability to borrow up to $150 million of eligible receivables during the period November through April, and up to $75 million of eligible receivables during the period May through October. Energy Services uses the Receivables Facility to fund working capital, margin calls under commodity futures contracts, capital expenditures, dividends and for general corporate purposes.
At September 30, 2021, the outstanding balance of trade receivables was $61 million, none of which was sold to the bank. At September 30, 2020, the outstanding balance of trade receivables was $50 million of which $19 million was sold to the bank. Amounts sold to the bank are reflected as “Short-term borrowings” on the Consolidated Balance Sheet. During Fiscal 2021 and Fiscal 2020, peak sales of receivables were $87 million and $97 million, respectively. During Fiscal 2021 and Fiscal 2020, average daily amounts sold were $21 million and $45 million, respectively.
For further information on the Company’s long-term debt and credit facilities, see Note 6 to Consolidated Financial Statements.
Cash Flows
Due to the seasonal nature of the Company’s businesses, cash flows from operating activities are generally strongest during the second and third fiscal quarters when customers pay for natural gas, LPG, electricity and other energy products and services consumed during the peak heating season months. Conversely, operating cash flows are generally at their lowest levels during the fourth and first fiscal quarters when the Company’s investment in working capital, principally inventories and accounts receivable, is generally greatest.
Operating Activities:
Year-to-year variations in our cash flows from operating activities can be significantly affected by changes in operating working capital especially during periods with significant changes in energy commodity prices. Cash flows from operating activities in Fiscal 2021 and Fiscal 2020 were $1,481 million and $1,102 million, respectively. Cash flows from operating activities before changes in operating working capital were $1,200 million in Fiscal 2021 and $1,176 million in Fiscal 2020. Changes in operating working capital provided (used) operating cash flow of $281 million in Fiscal 2021 and $(74) million in Fiscal 2020. Changes in operating working capital during Fiscal 2021 reflect cash generated from changes in accounts payable and higher cash received for commodity derivative instrument collateral deposits in the Fiscal 2021 as compared to Fiscal 2020, as well as cash generated from changes in income taxes receivable and other current liabilities. These changes were partially offset by an increase in cash required to fund changes in accounts receivable and inventories due to rising commodity prices during Fiscal 2021, net refunds of deferred fuel and power costs compared to net recoveries during the Fiscal 2020 as well as an increase in cash required to fund changes in other current assets.
Investing Activities:
Investing activity cash flow is principally affected by cash expenditures for property, plant and equipment; cash paid for acquisitions of businesses and assets; investments in equity method investees; and cash proceeds from sales and retirements of property, plant and equipment. Cash expenditures for property, plant and equipment totaled $690 million in Fiscal 2021 and $655 million in Fiscal 2020. Cash payments for property, plant and equipment were higher in Fiscal 2021 compared with Fiscal 2020 reflecting, in part, the return of normal capital spending in the absence of curtailments experienced at the onset of the COVID-19 pandemic in Fiscal 2020. Cash used for acquisitions of businesses and assets in Fiscal 2021 reflects UGI’s acquisition of Mountaineer. Cash used for investments in equity method investees in Fiscal 2021 includes contributions to Pine Run of $56 million to fund the acquisition of Pine Run Midstream, LLC.
Financing Activities:
Changes in cash flow from financing activities are primarily due to issuances and repayments of long-term debt; short-term borrowings; dividends on UGI Common Stock; and issuances or repurchases of equity instruments.
Cash flow provided by financing activities was $166 million in Fiscal 2021 compared to cash used to fund financing activities of $635 million in Fiscal 2020. During Fiscal 2021, the Company received $213 million in net cash proceeds from the issuance of Equity Units and $215 million from the issuance of a new variable rate term loan due in May 2025. These funds were used partially to fund the Mountaineer Acquisition. Also during Fiscal 2021 and Fiscal 2020, UGI Utilities, Inc. issued $175 million of senior notes and $150 million of senior notes, respectively. In Fiscal 2021 and Fiscal 2020, the Company had net repayments on credit facilities and the Receivables Facility of $35 million and $449 million, respectively. Cash used to fund changes in financing activities in Fiscal 2020 includes $38 million of cash paid to repurchase UGI Common Stock.
Capital Expenditures
In the following table, we present capital expenditures (which exclude acquisitions of businesses and assets) for Fiscal 2021 and Fiscal 2020. We also provide amounts we expect to spend in Fiscal 2022. We expect to finance a substantial portion of our Fiscal 2022 capital expenditures from cash generated by operations and cash on hand.
(Millions of dollars) 2022
(estimate) 2021 2020
AmeriGas Propane $ 160 $ 130 $ 135
UGI International 140 107 89
Midstream & Marketing 130 43 93
UGI Utilities 545 394 348
Corporate & Other 15 - -
Total $ 990 $ 674 $ 665
Capital expenditures at Midstream & Marketing declined during Fiscal 2021 primarily due to the use of funds to invest in Pine Run. Increased levels of capital expenditures estimated in Fiscal 2022 reflect natural gas infrastructure expansion and investments in renewable energy projects at Midstream & Marketing; replacement and betterment projects at UGI Utilities, Inc.; and the addition of Mountaineer’s capital expenditure programs.
Contractual Cash Obligations and Commitments
The Company has contractual cash obligations that extend beyond Fiscal 2021. The following table presents contractual cash obligations with non-affiliates under agreements existing as of September 30, 2021:
Payments Due by Period
(Millions of dollars) Total Fiscal
2022 Fiscal
2023 - 2024 Fiscal
2025 - 2026 Thereafter
Long-term debt (a) $ 6,491 $ 110 $ 1,505 $ 3,233 $ 1,643
Interest on long-term fixed-rate debt (a)(b)(c) 1,962 285 534 351 792
Operating leases 446 92 152 99 103
AmeriGas Propane supply contracts 17 17 - - -
UGI International supply contracts 254 254 - - -
Midstream & Marketing supply contracts 1,202 466 252 103 381
UGI Utilities construction, supply, storage and transportation contracts 324 128 129 44 23
Derivative instruments (d) 68 44 23 1 -
Total $ 10,764 $ 1,396 $ 2,595 $ 3,831 $ 2,942
(a)Based upon stated maturity dates for debt outstanding at September 30, 2021.
(b)Based upon stated interest rates adjusted for the effects of interest rate swaps.
(c)Calculated using applicable interest rates or forward interest rate curves, and UGI’s and its subsidiaries’ leverage ratios, as of September 30, 2021.
(d)Represents the sum of amounts due if derivative instrument liabilities were settled at the September 30, 2021 amounts reflected in the Consolidated Balance Sheet (but excluding amounts associated with interest rate contracts).
“Other noncurrent liabilities” included in our Consolidated Balance Sheet at September 30, 2021, principally comprise operating lease liabilities (see Note 16 to Consolidated Financial Statements); regulatory liabilities (see Note 9 to Consolidated Financial Statements); refundable tank and cylinder deposits (as further described in Note 2 to Consolidated Financial Statements under the caption “Refundable Tank and Cylinder Deposits”); litigation, property and casualty liabilities and obligations under environmental remediation agreements (see Note 17 to Consolidated Financial Statements); pension and other postretirement benefit liabilities recorded in accordance with accounting guidance relating to employee retirement plans (see Note 8 to Consolidated Financial Statements); and liabilities associated with executive compensation plans (see Note 14 to Consolidated Financial Statements). These liabilities, with the exception of operating lease liabilities, are not included in the table of Contractual Cash Obligations and Commitments because they are estimates of future payments and not contractually fixed as to timing or amount. Required minimum contributions to the U.S. Pension Plans (as further described below under
“U.S. Pension Plans”) in Fiscal 2022 are not expected to be material. Required minimum contributions to the U.S. Pension Plans in years beyond Fiscal 2022 will depend, in large part, on the impacts of future returns on pension plan assets and interest rates on pension plan liabilities.
U.S. Pension Plans
The U.S. Pension Plans consist 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 noncontributory defined benefit pension plan covering substantially all Mountaineer employees. The fair values of the U.S. Pension Plans’ assets totaled $717 million and $566 million at September 30, 2021 and 2020, respectively. At September 30, 2021 and 2020, the underfunded positions of the U.S. Pension Plans, defined as the excess of the PBO over the U.S. Pension Plans’ assets, were $109 million and $170 million, respectively.
We believe we are in compliance with regulations governing defined benefit pension plans, including the ERISA rules and regulations. Required minimum contributions to the U.S. Pension Plans in Fiscal 2022 are not expected to be material. Pre-tax pension cost associated with the U.S. Pension Plans in Fiscal 2021 was not material. Pre-tax pension cost associated with the U.S. Pension Plans in Fiscal 2022 is not expected to be material.
GAAP guidance associated with pension and other postretirement plans generally requires recognition of an asset or liability in the statement of financial position reflecting the funded status of pension and other postretirement benefit plans with current year changes recognized in shareholders’ equity unless such amounts are subject to regulatory recovery. At September 30, 2021, we have recorded after-tax charges to UGI Corporation’s stockholders’ equity of $8 million and recorded regulatory assets totaling $108 million in order to reflect the funded status of the U.S. Pension Plans. For a more detailed discussion of the U.S. Pension Plans and our other postretirement benefit plans, see Note 8 to Consolidated Financial Statements.
Related Party Transactions
During Fiscal 2021 and Fiscal 2020, we did not enter into any related-party transactions that had a material effect on our financial condition, results of operations or cash flows.
Off-Balance-Sheet Arrangements
UGI primarily enters into guarantee arrangements on behalf of its consolidated subsidiaries. These arrangements are not subject to the recognition and measurement guidance relating to guarantees under GAAP.
We do not have any off-balance-sheet arrangements that are expected to have a material effect on our financial condition, change in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.
Utility Regulatory Matters
Base Rate Filings. On February 8, 2021, Electric Utility filed a rate request with the PAPUC to increase its annual base distribution revenues by $9 million. On October 28, 2021, the PAPUC issued a final Order approving a settlement that permitted Electric Utility, effective November 9, 2021, to increase its base distribution revenues by $6 million.
On January 28, 2020, Gas Utility filed a request with the PAPUC to increase its annual base distribution operating revenues by $75 million annually. On October 8, 2020, the PAPUC issued a final Order approving a settlement that permits Gas Utility to increase its annual base distribution rates by $20 million, through a phased approach, with $10 million beginning January 1, 2021 and an additional $10 million beginning July 1, 2021. Additionally, Gas Utility was authorized to implement a DSIC once Gas Utility total property, plant and equipment less accumulated depreciation reaches $2,875 million. This threshold was achieved in December 2020, and Gas Utility implemented a DSIC effective April 1, 2021. The PAPUC’s final Order also includes enhanced COVID-19 customer assistance measures, including the establishment of an Emergency Relief Program for a defined set of payment troubled customers (“ERP”). Additionally, the PAPUC’s final Order permits Gas Utility to establish a regulatory asset for certain incremental expenses attributable to the ongoing COVID-19 pandemic, most notably expenses related to the ERP and uncollectible accounts expense, through the effective date of rates in the next Gas Utility base rate case, to be recovered and amortized over a 10-year period. In accordance with the terms of the Joint Petition, Gas Utility is not permitted to file a rate case prior to January 1, 2022.
On January 28, 2019, Gas Utility filed a rate request with the PAPUC to increase the base operating revenues for residential, commercial, and industrial customers throughout its Pennsylvania service territory by an aggregate $71 million. On October 4, 2019, the PAPUC issued a final Order approving a settlement that permitted Gas Utility, effective October 11, 2019, to increase
its base distribution revenues by $30 million under a single consolidated tariff, approved a plan for uniform class rates, and permitted Gas Utility to extend its Energy Efficiency and Conservation and Growth Extension Tariff programs by an additional term of five years. The PAPUC’s final Order approved a negative surcharge, to return to customers $24 million of tax benefits experienced by Gas Utility over the period January 1, 2018 to June 30, 2018, plus applicable interest, in accordance with the May 17, 2018 PAPUC Order, which became effective for a twelve-month period beginning on October 11, 2019, the effective date of Gas Utility’s new base rates, subject to final reconciliation of any over- or under-crediting of the tax savings.
Market Risk Disclosures
Our primary market risk exposures are (1) commodity price risk; (2) interest rate risk; and (3) foreign currency exchange rate risk. Although we use derivative financial and commodity instruments to reduce market price risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes.
Commodity Price Risk
The risk associated with fluctuations in the prices the Partnership and our UGI International operations pay for LPG is principally a result of market forces reflecting changes in supply and demand for LPG and other energy commodities. Their profitability is sensitive to changes in LPG supply costs. Increases in supply costs are generally passed on to customers. The Partnership and UGI International may not, however, always be able to pass through product cost increases fully or on a timely basis, particularly when product costs rise rapidly. In order to reduce the volatility of LPG market price risk, the Partnership uses contracts for the forward purchase or sale of propane, propane fixed-price supply agreements and over-the-counter derivative commodity instruments including price swap contracts. Our UGI International operations use over-the-counter derivative commodity instruments and may from time to time enter into other derivative contracts, similar to those used by the Partnership, to reduce market risk associated with a portion of their LPG purchases. Over-the-counter derivative commodity instruments used to economically hedge forecasted purchases of LPG are generally settled at expiration of the contract.
UGI Utilities’ tariffs contain clauses that permit recovery of all prudently incurred costs of natural gas it sells to its retail core-market customers, including the cost of financial instruments used to hedge purchased gas costs. The recovery clauses provide for periodic adjustments for the difference between the total amounts actually billed to customers through PGC and PGA rates and the recoverable costs incurred. Because of this ratemaking mechanism, there is limited commodity price risk associated with our UGI Utilities operations. Gas Utility uses derivative financial instruments, including natural gas futures and option contracts traded on the NYMEX, to reduce volatility in the cost of gas it purchases for its retail core-market customers. The cost of these derivative financial instruments, net of any associated gains or losses, is included in Gas Utility's PGC recovery mechanism.
In order to manage market price risk relating to substantially all of Midstream & Marketing’s fixed-price sale contracts for physical natural gas and electricity, Midstream & Marketing enters into NYMEX, ICE and over-the-counter natural gas and electricity futures and option contracts, and natural gas basis swap contracts or enters into fixed-price supply arrangements. Midstream & Marketing also uses NYMEX and over-the-counter electricity futures contracts to economically hedge a portion of its anticipated sales of electricity from its electricity generation facilities. Although Midstream & Marketing’s fixed-price supply arrangements mitigate most risks associated with its fixed-price sales contracts, should any of the suppliers under these arrangements fail to perform, increases, if any, in the cost of replacement natural gas or electricity would adversely impact Midstream & Marketing’s results. In order to reduce this risk of supplier nonperformance, Midstream & Marketing has diversified its purchases across a number of suppliers. UGI International’s natural gas and electricity marketing businesses also use natural gas and electricity futures and forward contracts to economically hedge market risk associated with fixed-price sales and purchase contracts.
Midstream & Marketing has entered into fixed-price sales agreements for a portion of the electricity expected to be generated by its electric generation assets. In the event that these generation assets would not be able to produce all of the electricity needed to supply electricity under these agreements, Midstream & Marketing would be required to purchase electricity on the spot market or under contract with other electricity suppliers. Accordingly, increases in the cost of replacement power could negatively impact Midstream & Marketing’s results.
Interest Rate Risk
We have both fixed-rate and variable-rate debt. Changes in interest rates impact the cash flows of variable-rate debt but generally do not impact their fair value. Conversely, changes in interest rates impact the fair value of fixed-rate debt but do not impact their cash flows.
Our variable-rate debt at September 30, 2021, includes revolving credit facility borrowings and variable-rate term loans at UGI International, UGI Utilities, Inc., Energy Services and UGI Corporation. These debt agreements have interest rates that are generally indexed to short-term market interest rates. We have entered into pay-fixed, receive-variable interest rate swap agreements on all or a significant portion of the term loans’ principal balances and all or a significant portion of the term loans’ tenor. We have designated these interest rate swaps as cash flow hedges. At September 30, 2021, combined borrowings outstanding under variable-rate debt agreements, excluding the previously mentioned effectively fixed-rate debt, totaled $807 million. Based upon average borrowings outstanding under variable-rate borrowings (excluding effectively fixed-rate term loan debt), an increase in short-term interest rates of 100 basis points (1%) would have increased our Fiscal 2021 interest expense by approximately $7 million. The remainder of our debt outstanding is subject to fixed rates of interest. A 100 basis point increase in market interest rates would result in decreases in the fair value of this fixed-rate debt of approximately $292 million at September 30, 2021. A 100 basis point decrease in market interest rates would result in increases in the fair value of this fixed-rate debt of approximately $249 million at September 30, 2021.
Long-term debt associated with our domestic businesses is typically issued at fixed rates of interest based upon market rates for debt with similar terms and credit ratings. As these long-term debt issues mature, we may refinance such debt with new debt having interest rates reflecting then-current market conditions. In order to reduce interest rate risk associated with near- to medium-term forecasted issuances of fixed rate debt, from time to time we enter into IRPAs.
Foreign Currency Exchange Rate Risk
Our primary currency exchange rate risk is associated with the U.S. dollar versus the euro and, to a lesser extent, the U.S. dollar versus the British pound sterling. The U.S. dollar value of our foreign currency denominated assets and liabilities will fluctuate with changes in the associated foreign currency exchange rates. From time to time, we use derivative instruments to hedge portions of our net investments in foreign subsidiaries. Gains or losses on these net investment hedges remain in AOCI until such foreign operations are sold or liquidated. With respect to our net investments in our UGI International operations, a 10% decline in the value of the associated foreign currencies versus the U.S. dollar would reduce their aggregate net book value at September 30, 2021, by approximately $170 million, which amount would be reflected in other comprehensive income. We have designated certain euro-denominated borrowings as net investment hedges.
In order to reduce the volatility in net income associated with our foreign operations, principally as a result of changes in the U.S. dollar exchange rate between the euro and British pound sterling, we enter into forward foreign currency exchange contracts. We layer in these foreign currency exchange contracts over a multi-year period to eventually equal approximately 90% of anticipated UGI International foreign currency earnings before income taxes.
Derivative Instrument Credit Risk
We are exposed to risk of loss in the event of nonperformance by our derivative instrument counterparties. Our derivative instrument counterparties principally comprise large energy companies and major U.S. and international financial institutions. We maintain credit policies with regard to our counterparties that we believe reduce overall credit risk. These policies include evaluating and monitoring our counterparties’ financial condition, including their credit ratings, and entering into agreements with counterparties that govern credit limits or entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate.
We have concentrations of credit risk associated with derivative instruments and we evaluate the creditworthiness of our derivative counterparties on an ongoing basis. As of September 30, 2021, the maximum amount of loss, based upon the gross fair values of the derivative instruments, we would incur if these counterparties failed to perform according to the terms of their contracts was $1,687 million. In general, many of our over-the-counter derivative instruments and all exchange contracts call for the posting of collateral by the counterparty or by the Company in the forms of letters of credit, parental guarantees or cash. At September 30, 2021, we had received cash collateral from derivative instrument counterparties totaling $468 million. In addition, we may have offsetting derivative liabilities and certain accounts payable balances with certain of these counterparties, which further mitigates the previously mentioned maximum amount of losses. Certain of the Partnership’s derivative contracts have credit-risk-related contingent features that may require the posting of additional collateral in the event of a downgrade of the Partnership’s debt rating. At September 30, 2021, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material.
The following table summarizes the fair values of unsettled market risk sensitive derivative instrument assets (liabilities) held at September 30, 2021 and changes in their fair values due to market risks. Certain of UGI Utilities’ commodity derivative instruments are excluded from the table below because any associated net gains or losses are refundable to or recoverable from customers in accordance with UGI Utilities ratemaking.
Asset (Liability)
(Millions of dollars) Fair Value Change in
Fair Value
September 30, 2021
Commodity price risk (1) $ 1,334 $ (279)
Interest rate risk (2) $ (29) $ (10)
Foreign currency exchange rate risk (3) $ 30 $ (50)
(1)Change in fair value represents a 10% adverse change in the market prices of certain commodities
(2)Change in fair value represents a 50 basis point adverse change in prevailing market interest rates
(3)Change in fair value represents a 10% adverse change in the value of the Euro and the British pound sterling versus the U.S. dollar.
Critical Accounting Policies and Estimates
The accounting policies and estimates discussed in this section are those that we consider to be the most critical to an understanding of our financial statements because they involve significant judgments and uncertainties. The application of these accounting policies and estimates necessarily requires management’s most subjective or complex judgments regarding estimates and projected outcomes of future events. Changes in these policies and estimates could have a material effect on our financial statements. Management has reviewed these critical accounting policies, and the estimates and assumptions associated with them, with the Company’s Audit Committee. Also, see Note 2 to Consolidated Financial Statements which discusses our significant accounting policies.
Goodwill Impairment Evaluation. Our goodwill is the result of business acquisitions. We do not amortize goodwill, but test it at least annually for impairment at the reporting unit level. A reporting unit is an operating segment, or one level below an operating segment (a component), if it constitutes a business for which discrete financial information is available and regularly reviewed by segment management. Components are aggregated into a single reporting unit if they have similar economic characteristics. A reporting unit with goodwill is required to perform an impairment test annually or whenever events or circumstances indicate that the value of goodwill may be impaired.
For certain of our reporting units with goodwill, we assess qualitative factors to determine whether it is more likely than not that the fair value of such reporting unit is less than its carrying amount. For our other reporting units with goodwill, we bypass the qualitative assessment and perform the quantitative assessment by comparing the fair values of the reporting units with their carrying amounts, including goodwill. We determine fair values generally based on a weighting of income and market approaches. For purposes of the income approach, fair values are determined based upon the present value of the reporting unit’s estimated future cash flows, including an estimate of the reporting unit’s terminal value based upon these cash flows, discounted at appropriate risk-adjusted rates. We use our internal forecasts to estimate future cash flows, which may include estimates of long-term future growth rates based upon our most recent reviews of the long-term outlook for each reporting unit. Cash flow estimates used to establish fair values under our income approach involve management judgments based on a broad range of information and historical results. In addition, external economic and competitive conditions can influence future performance. For purposes of the market approach, we use valuation multiples for companies comparable to our reporting units. The market approach requires judgment to determine the appropriate valuation multiples. If the carrying amount of a reporting unit exceeds its fair value, an impairment loss is recognized in an amount equal to such excess but not to exceed the total amount of the goodwill of the reporting unit. As of September 30, 2021, our goodwill totaled $3,770 million. No impairments of goodwill were recorded during any of the periods presented.
Impairment of Long-Lived Assets. An impairment test for long-lived assets (or an asset group) is required when circumstances indicate that such assets may be impaired. If it is determined that a triggering event has occurred, we perform a recoverability test based upon estimated undiscounted cash flow projections expected to be realized over the remaining useful life of the long-lived asset. If the undiscounted cash flows used in the recoverability test are less than the long-lived asset's carrying amount, we determine its fair value. If the fair value is determined to be less than its carrying amount, the long-lived asset is reduced to its estimated fair value and an impairment loss is recognized in an amount equal to such shortfall. When determining whether a long-lived asset has been impaired, management groups assets at the lowest level that has identifiable cash flows. Performing an impairment test on long-lived assets involves judgment in areas such as identifying when a triggering event requiring evaluation occurs; identifying and grouping assets; and, if the undiscounted cash flows used in the recoverability test are less than the long-lived asset's carrying amount, determining the fair value of the long-lived asset. Although cash flow estimates are based upon relevant information at the time the estimates are made, estimates of future cash flows are by nature highly uncertain and contemplate factors that change over time such as the expected use of the asset including future production and sales volumes, expected fluctuations in prices of commodities and expected proceeds from
disposition. See Note 5 to Consolidated Financial Statements for information on the impairment loss associated with the disposal of Conemaugh during the third quarter of Fiscal 2020. No other material provisions for impairments of long-lived assets were recorded during Fiscal 2021 or Fiscal 2020.
Loss Contingencies and Environmental Remediation Liabilities. We are involved in litigation that arises in the normal course of business, and we are subject to risk of loss for general, automobile and product liability and workers’ compensation claims for which we obtain insurance coverage subject to self-insured retentions or deductibles. We are also subject to environmental laws and regulations intended to mitigate or remove the effects of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current or former operating sites.
We establish reserves for loss contingencies including pending litigation, and for pending and incurred but not reported claims associated with general and product liability, automobile and workers’ compensation when it is probable that a liability exists and the amount or range of amounts related to such liability can be reasonably estimated. When no amount within a range of possible loss is a better estimate than any other amount within the range, liabilities recorded are based upon the low end of the range. With respect to unasserted claims arising from unreported incidents, we may use the work of specialists to estimate the ultimate losses to be incurred using actuarially determined loss development factors applied to actual claims data.
The likelihood of a loss with respect to a particular loss contingency is often difficult to predict. In addition, a reasonable estimate of the loss, or a range of possible loss, may not be practicable based upon the information available and the potential effects of future events and decisions by third parties that will determine the ultimate resolution of the loss contingency. Reasonable estimates involve management judgments based on a broad range of information and prior experience. For litigation and pending claims including those covered by insurance policies, the analysis of probable loss is performed on a case by case basis and includes an evaluation of the nature of the claim, the procedural status of the matter, the probability or likelihood of success in prosecuting or defending the claim, the information available with respect to the claim, the opinions and views of outside counsel and other advisors, and past experience in similar matters. These judgments are reviewed quarterly as more information is received, and the amounts reserved are updated as necessary. Our estimated reserves for loss contingencies and for pending and incurred but not reported claims associated with general and product liability, automobile and workers’ compensation may differ materially from the ultimate liability and such reserves may change materially as more information becomes available and estimated reserves are adjusted.
We accrue reserves for environmental remediation when assessments indicate that it is probable a liability has been incurred and an amount can be reasonably estimated. Amounts recorded as environmental liabilities on the Consolidated Balance Sheets represent our best estimate of costs expected to be incurred or, if no best estimate can be made, the minimum liability associated with a range of expected environmental investigation and remediation costs. These estimates are based upon a number of factors including whether the company will be responsible for such remediation, the scope and cost of the remediation work to be performed, the portion of costs that will be shared with other potentially responsible parties, the timing of the remediation and possible impact of changes in technology, and the regulations and requirements of local governmental authorities. Our estimated reserves for environmental remediation may differ materially from the ultimate liability and such reserves may change materially as more information becomes available and estimated reserves are adjusted. Gas Utility receives ratemaking recognition of environmental investigation and remediation costs associated with its in-state environmental sites. This ratemaking recognition balances the accumulated difference between historical costs and rate recoveries with an estimate of future costs associated with the sites.
Regulatory Assets and Liabilities. The accounting for our rate regulated gas and electric utility businesses differs from the accounting for nonregulated operations in that these businesses are required to reflect the effects of rate regulation in the consolidated financial statements. Regulatory practices that assign costs to accounting periods may differ from accounting methods generally applied by nonregulated businesses. When it is probable that regulators will permit the recovery of current costs through future rates charged to customers, these costs that otherwise would be expensed by nonregulated companies are deferred as regulatory assets. Similarly, regulatory liabilities are recognized when it is probable that regulators will require customer refunds through future rates or when revenue is collected from customers for expenditures that have yet to be incurred. We continually assess whether the regulatory assets are probable of future recovery by evaluating the regulatory environment, recent rate orders and public statements issued by the PAPUC, WVPSC and MDPSC, discussions with regulatory authorities and legal counsel. If future recovery of regulatory assets ceases to be probable, the elimination of those regulatory assets would adversely impact our results of operations and cash flows. As of September 30, 2021, our regulatory assets and regulatory liabilities totaled $397 million and $388 million, respectively. For additional information on regulatory assets and liabilities, see Notes 2 and 9 to Consolidated Financial Statements.
Income Taxes. We use the asset and liability method of accounting for income taxes. Under this method, income tax expense is recognized for the amount of taxes payable or refundable for the current year and for deferred tax liabilities and assets for the
future tax consequences of events that have been recognized in our financial statements or tax returns. Positions taken by an entity in its tax returns must satisfy a more-likely-than-not recognition threshold assuming the positions will be examined by tax authorities with full knowledge of relevant information. We use assumptions, judgments and estimates to determine our current provision for income taxes. We also use assumptions, judgments and estimates to determine our deferred tax assets and liabilities and any valuation allowance to be recorded against a deferred tax asset. The interpretation of tax laws involves uncertainty since tax authorities may interpret the laws differently. Our assumptions, judgments and estimates relative to the current provision for income tax give consideration to current tax laws, our interpretation of current tax laws and possible outcomes of current and future audits conducted by foreign and domestic tax authorities. Changes in tax law or our interpretation thereof and the resolution of current and future tax audits could significantly impact the amounts provided for income taxes in our consolidated financial statements. Our assumptions, judgments and estimates relative to the amount of deferred income taxes take into account estimates of the amount of future taxable income. Actual taxable income or future estimates of taxable income could render our current assumptions, judgments and estimates inaccurate. Changes in the assumptions, judgments and estimates mentioned above could cause our actual income tax obligations to differ significantly from our estimates. As of September 30, 2021, our net deferred tax liabilities totaled $1,082 million.
Business Combination Purchase Price Allocations. From time to time, the Company enters into material business combinations. The purchase price is allocated to the various assets acquired and liabilities assumed at their estimated fair value as of the acquisition date with the residual of the purchase price allocated to goodwill. From time to time, we engage third-party valuation experts to assist us in determining the fair values of certain assets acquired and liabilities assumed. Such valuations require management to make significant judgments, estimates and assumptions especially with respect to intangible assets. Management makes estimates of fair value based upon assumptions it believes to be reasonable. These estimates are based upon historical experience and information obtained from the management of the acquired companies and are inherently uncertain. Critical estimates in valuing certain of the intangible assets include, but are not limited to, discount rates and expected future cash flows from and the economic lives of customer relationships, trade names, existing technology, and other intangible assets. Unanticipated events and circumstances may occur, which may affect the accuracy or validity of such assumptions or estimates. The allocation of the purchase price may be modified up to one year after the acquisition date, under certain circumstances, as more information is obtained about the fair value of assets acquired and liabilities assumed.
Recently Issued Accounting Pronouncements
See Note 3 to Consolidated Financial Statements for a discussion of the effects of recently issued accounting guidance.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
“Quantitative and Qualitative Disclosures About Market Risk” are contained in Item 7 - Management’s Discussion and Analysis of Financial Condition and Results of Operations under the caption “Market Risk Disclosures” and are incorporated by reference.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
ITEM 8.FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Management’s Annual Report on Internal Control Over Financial Reporting included in Item 9A and the financial statements and financial statement schedules referred to in the Index contained on page of this Report are incorporated herein by reference.

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
ITEM 9.CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.

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ITEM 9A. CONTROLS AND PROCEDURES
ITEM 9A. CONTROLS AND PROCEDURES
(a)The Company's disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by the Company in reports filed or submitted under the Exchange Act is (i) recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms, and (ii) accumulated and communicated to our management, including the Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure. The Company's management, with the participation of the Company’s Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of the Company's disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, the Chief Executive
Officer and Chief Financial Officer concluded that the Company's disclosure controls and procedures, as of September 30, 2021, were effective at the reasonable assurance level.
(b)Management’s Annual Report on Internal Control over Financial Reporting
Management is responsible for establishing and maintaining adequate internal control over financial reporting for the Company, as such term is defined in Rule 13a-15(f) of the Securities Exchange Act of 1934, as amended. In order to evaluate the effectiveness of internal control over financial reporting, as required by Section 404 of the Sarbanes-Oxley Act of 2002, management has conducted an assessment, including testing, of the Company’s internal control over financial reporting as of September 30, 2021, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (the “COSO criteria”). The scope of that assessment excluded the Mountaineer business acquired on September 1, 2021, by UGI Corporation and the Redeo Energies business acquired by UGI International on June 30, 2021. Mountaineer’s and Redeo Energies’ total assets represented approximately 5% and less than 1%, respectively, of the Company’s consolidated total assets at September 30, 2021. Mountaineer’s and Redeo Energies’ total earnings before taxes represented less than 1% and approximately 3%, respectively, of the Company’s consolidated earnings before taxes for the year then ended. Such exclusions are permitted based upon current guidance of the U.S. Securities & Exchange Commission.
Internal control over financial reporting refers to the process, designed under the supervision and with the participation of management, including our Chief Executive Officer and our Chief Financial Officer, and effected by the Company’s Board of Directors, to provide reasonable, but not absolute, assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with GAAP and includes policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the Company are being made only in accordance with authorizations of management and directors of the Company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate due to changing conditions, or the degree of compliance with the policies or procedures may deteriorate.
Based on its assessment, management has concluded that the Company’s internal control over financial reporting was effective as of September 30, 2021, based on the COSO criteria. The Company’s independent registered public accounting firm, Ernst & Young LLP, has issued an attestation report on the effectiveness of the Company’s internal control over financial reporting as of September 30, 2021. This report is set forth below.
(c)During the most recent fiscal quarter, other than changes resulting from the Mountaineer Acquisition discussed below, no change in the Company’s internal control over financial reporting occurred that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.
On September 1, 2021, UGI acquired Mountaineer. The Company is currently in the process of integrating processes and internal controls. See Note 5 to consolidated financial statements for additional information related to the Mountaineer Acquisition.
Report of Independent Registered Public Accounting Firm
To the Stockholders and the Board of Directors of UGI Corporation
Opinion on Internal Control over Financial Reporting
We have audited UGI Corporation and subsidiaries’ internal control over financial reporting as of September 30, 2021, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO criteria). In our opinion, UGI Corporation and subsidiaries (the Company) maintained, in all material respects, effective internal control over financial reporting as of September 30, 2021, based on the COSO criteria.
As indicated in the accompanying Management’s Annual Report on Internal Control over Financial Reporting, management’s assessment of and conclusion on the effectiveness of internal control over financial reporting did not include the internal controls of Mountaineer Gas Company and Redeo Energies, which are included in the 2021 consolidated financial statements of UGI Corporation and subsidiaries and constituted approximately 5% and 1%, respectively, of total assets as of September 30, 2021 and approximately 1% and 3%, respectively, of total earnings before taxes for the year then ended. Our audit of internal control over financial reporting of UGI Corporation and Subsidiaries also did not include an evaluation of the internal control over financial reporting of Mountaineer Gas Company and Redeo Energies.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of September 30, 2021 and 2020, the related consolidated statements of income, comprehensive income, changes in equity and cash flows for each of the three years in the period ended September 30, 2021, and the related notes and the financial statement schedules listed in the Index at Item 15(a) and our report dated November 19, 2021 expressed an unqualified opinion thereon.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying “Management’s Annual Report on Internal Control over Financial Reporting”. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.
Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ Ernst & Young LLP
Philadelphia, Pennsylvania
November 19, 2021

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ITEM 9B. OTHER INFORMATION
ITEM 9B. OTHER INFORMATION
None.
PART III:

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
ITEMS 10 THROUGH 14.
In accordance with General Instruction G(3), and except as set forth below, the information required by Items 10, 11, 12, 13 and 14 is incorporated in this Report by reference to the following portions of UGI’s Proxy Statement, which will be filed with the SEC by December 31, 2021.
Information Captions of Proxy Statement
Incorporated by Reference
Item 10. Directors, Executive Officers and Corporate Governance Election of Directors - Nominees; Corporate Governance Principles; Director Independence; Board Leadership Structure and Role in Risk Management; Board Meetings and Attendance; Board and Committee Structure; Selection of Board Candidates; Board and Committee Evaluation Process; Investor Outreach; Code of Business Conduct and Ethics; Communications with the Board; Securities Ownership of Certain Beneficial Owners - Security Ownership of Directors and Executive Officers; Report of the Audit Committee of the Board of Directors
The Code of Business Conduct and Ethics is available without charge on the Company’s website, www.ugicorp.com, or by writing to Director, Investor Relations, UGI Corporation, P. O. Box 858, Valley Forge, PA 19482.

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ITEM 11. EXECUTIVE COMPENSATION
Item 11. Executive Compensation Compensation of Directors; Report of the Compensation and Management Development Committee of the Board of Directors; Compensation Discussion and Analysis; Compensation of Executive Officers; Compensation Committee Interlocks and Insider Participation

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters Securities Ownership of Certain Beneficial Owners; Security Ownership of Directors and Executive Officers.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Item 13. Certain Relationships and Related Transactions, and Director Independence Election of Directors - Director Independence and Board and Committee Structure; Policy for Approval of Related Person Transactions

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Item 14. Principal Accounting Fees and Services Our Independent Registered Public Accounting Firm
Equity Compensation Table
The following table sets forth information as of the end of Fiscal 2021 with respect to compensation plans under which our equity securities are authorized for issuance.
Plan category Number of securities to be
issued upon exercise of
outstanding options,
warrants and rights
(a) Weighted average
exercise price of
outstanding options,
warrants and rights
(b) Number of securities
remaining available for future
issuance under equity
compensation plans
(excluding securities reflected
in column (a)) (c)
Equity compensation plans approved by security holders
10,204,836 (1) $ 39.46 20,037,430 (2)
1,124,369 (3) $ 0
Equity compensation plans not approved by security holders
-
Total
11,329,205 $ 39.46 (4)
(1)Represents 10,204,836 stock options under the UGI Corporation 2021 Incentive Award Plan, which supersedes and replaces the UGI Corporation 2013 Omnibus Incentive Compensation Plan. The UGI Corporation 2021 Incentive Award Plan was approved by shareholders on January 29, 2021.
(2)Represents securities remaining for issuance under the UGI Corporation 2021 Incentive Award Plan.
(3)Represents 1,124,369 restricted stock units under the UGI Corporation 2021 Incentive Award Plan.
(4)Weighted-average exercise price of outstanding options; excludes restricted stock units.
The information concerning the Company’s executive officers required by Item 10 is set forth below.
EXECUTIVE OFFICERS
Name Age Position
Roger Perreault 57 President and Chief Executive Officer; Executive Vice President, Global LPG
Ted J. Jastrzebski 60 Chief Financial Officer
Robert F. Beard, Jr. 56 Executive Vice President, Natural Gas, Global Engineering & Construction and Procurement; Chief Executive Officer, UGI Utilities, Inc.
Monica M. Gaudiosi 58 Vice President, General Counsel and Secretary
John Koerwer 61 Chief Information Officer
Jean Felix Tematio Dontsop 45 Vice President - Chief Accounting Officer and Corporate Controller
Judy A. Zagorski 58 Vice President - Chief Human Resources Officer
All officers are elected for a one-year term at the organizational meeting of the Board of Directors held each year.
There are no family relationships between any of the officers or between any of the officers and any of the directors.
Roger Perreault
Mr. Perreault is a Director, President and Chief Executive Officer (since June 2021) and Executive Vice President, Global LPG (since 2018) of UGI Corporation. Mr. Perreault previously served as President - UGI International, LLC (from 2015 to 2021). Prior to joining UGI Corporation, Mr. Perreault held various positions at Air Liquide, an industrial gases company he joined in 1994, and served in various leadership positions from 2008 to 2014, including in a global role as President, Large Industries with international responsibilities and, prior to that, in a role with responsibility for Air Liquide’s North American large industries business. Prior to joining Air Liquide, Mr. Perreault was a chemical engineer and operations manager with I.C.I. in Quebec, Canada.
Ted J. Jastrzebski
Mr. Jastrzebski is Chief Financial Officer of UGI Corporation (since 2018). Mr. Jastrzebski previously served as Principal Financial Officer of AmeriGas Propane, Inc. (2018 to 2019). From 2013 until 2018, Mr. Jastrzebski served as Executive Vice President and Chief Financial Officer of Qurate Retail Group, which is comprised of QVC, HSN, Cornerstone Brands, and Zulily. Previously, Mr. Jastrzebski held various positions at The Hershey Company, including Senior Vice President and President, Hershey Americas (2011 to 2013), Senior Vice President and President, Hershey International (2007 to 2010) and Vice President, Finance, Hershey International (2004 to 2007). Mr. Jastrzebski also served as Senior Vice President, Finance, IT and Administration and Chief Financial Officer of CARE (2002 to 2004) and as Vice President and Chief Financial Officer of Project Hope (1999 to 2002).
Robert F. Beard, Jr.
Mr. Beard is Executive Vice President, Natural Gas, Global Engineering & Construction and Procurement of UGI Corporation (since 2021) and Chief Executive Officer of UGI Utilities, Inc. (since 2011). He held the title of Executive Vice President, Natural Gas of UGI Corporation (2018 to 2021) and previously served as President (2011 to September 2020), Vice President - Marketing, Rates and Gas Supply (2010 to 2011) and Vice President - Southern Region (2008 to 2010) of UGI Utilities, Inc. From 2006 until 2008, Mr. Beard served as Vice President - Operations and Engineering of PPL Gas Utilities Corporation and, from 2002 until 2006, he served as Director - Operations and Engineering of PPL Gas Utilities Corporation.
Monica M. Gaudiosi
Ms. Gaudiosi is the Vice President, General Counsel and Secretary of UGI Corporation and UGI Utilities, Inc. (since 2012). She is also Vice President (since 2012), General Counsel (since 2015) and Secretary (since 2012) of AmeriGas Propane, Inc. Prior to joining UGI Corporation, Ms. Gaudiosi served as Senior Vice President and General Counsel (2007 to 2012) and Senior Vice President and Associate General Counsel (2005 to 2007) of Southern Union Company. Prior to joining Southern Union Company in 2005, Ms. Gaudiosi held various positions with General Electric Capital Corporation (1997 to 2005). Before joining General Electric Capital Corporation, Ms. Gaudiosi was an associate at the law firms of Hunton & Williams (1994 to 1997) and Sutherland, Asbill & Brennan (1988 to 1994).
John Koerwer
Mr. Koerwer is the Chief Information Officer of UGI Corporation (since 2020). Mr. Koerwer joined UGI as Vice President, Information Technology, for UGI International in 2016 and later was named Group CIO for UGI Corporation, responsible for the global IT strategy, operations, products and services to support both the domestic and international businesses units. Previously, Mr. Koerwer served in multiple IT/IS leadership roles for The Linde Group, a multi-national industrial gas company based in Munich, Germany.
Jean Felix Tematio Dontsop
Mr. Tematio Dontsop is the Vice President, Chief Accounting Officer and Controller of UGI Corporation (since July 2021). Mr. Tematio Dontsop most recently served as Vice President of Internal Audit for West Pharmaceuticals Services, Inc. in Exton, Pennsylvania (July 2020 to June 2021). Previously, he held several roles of increasing responsibility over fifteen years with PricewaterhouseCoopers, based in Philadelphia, Pennsylvania and Paris, France, including Audit Director (2019 to 2020) and Audit Senior Manager (2011 to 2019). A native of Cameroon, Mr. Tematio Dontsop also worked earlier in his career as an auditor for KPMG, based in Paris.
Judy A. Zagorski
Ms. Zagorski is the Vice President, Chief Human Resources Officer of UGI Corporation (since 2020). Previously, Ms. Zagorski served as Executive Vice President, Global Human Resources & CHRO at Church & Dwight, a major manufacturer of household products headquartered in Ewing, New Jersey (2017 to 2020). Prior to joining Church & Dwight, Ms. Zagorski held the positions of Senior Vice President - Human Resources and Vice President - Human Resources, Development and Strategy at BASF (2011 to 2017).
PART IV:

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
ITEM 15.EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a)Documents filed as part of this report:
(1)Financial Statements:
Included under Item 8 are the following financial statements and supplementary data:
Management’s Annual Report on Consolidated Financial Statements and Schedules
Report of Independent Registered Public Accounting Firm (on Consolidated Financial Statements and Schedules)
Consolidated Balance Sheets as of September 30, 2021 and 2020
Consolidated Statements of Income for the years ended September 30, 2021, 2020 and 2019
Consolidated Statements of Comprehensive Income for the years ended September 30, 2021, 2020 and 2019
Consolidated Statements of Cash Flows for the years ended September 30, 2021, 2020 and 2019
Consolidated Statements of Changes in Equity for the years ended September 30, 2021, 2020 and 2019
Notes to Consolidated Financial Statements
(2)Financial Statement Schedules:
I - Condensed Financial Information of Registrant (Parent Company)
II - Valuation and Qualifying Accounts for the years ended September 30, 2021, 2020 and 2019
We have omitted all other financial statement schedules because the required information is (1) not present; (2) not present in amounts sufficient to require submission of the schedule; or (3) included elsewhere in the financial statements or related notes.
(3)List of Exhibits:
The exhibits filed as part of this report are as follows (exhibits incorporated by reference are set forth with the name of the registrant, the type of report and registration number or last date of the period for which it was filed, and the exhibit number in such filing):
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
3.1 (Second) Amended and Restated Articles of Incorporation of the Company as amended through June 6, 2005.
UGI Form 10-Q (6/30/05) 3.1
3.2 Articles of Amendment to the Amended and Restated Articles of Incorporation of UGI Corporation.
UGI Form 8-K (7/29/14) 3.1
3.3 Bylaws of UGI Corporation, amended and restated as of July 25, 2017.
UGI Form 8-K (7/31/17) 3.1
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
3.4 Statement with Respect to Shares of the Company with respect to the Convertible Preferred Stock, filed with the Secretary of the Commonwealth of Pennsylvania and effective on May 25, 2021.
UGI Form 8-K
(5/25/21)
3.1
3.5 Statement with Respect to Shares of the Company with respect to the Series B Preferred Stock, filed with the Secretary of the Commonwealth of Pennsylvania and effective on May 25, 2021.
UGI Form 8-K
(5/25/21) 3.2
4.1 Instruments defining the rights of security holders, including indentures. (The Company agrees to furnish to the Commission upon request a copy of any instrument defining the rights of holders of long-term debt not required to be filed pursuant to Item 601(b)(4) of Regulation S-K).
4.2 The description of the Company’s Common Stock contained in the Company’s registration statement filed under the Securities Exchange Act of 1934, as amended. UGI Form 8-B/A (4/17/96) 3.(4)
4.3 UGI Corporation’s (Second) Amended and Restated Articles of Incorporation, as amended, and Bylaws referred to in 3.1, 3.2, and 3.3 above.
4.4 Indenture, dated as of August 1, 1993, by and between UGI Utilities, Inc., as Issuer, and U.S. Bank National Association, as successor trustee, incorporated by reference to the Registration Statement on Form S-3 filed on April 8, 1994. Utilities Registration Statement No. 33-77514
(4/8/94) 4(c)
4.5 Supplemental Indenture, dated as of September 15, 2006, by and between UGI Utilities, Inc., as Issuer, and U.S. Bank National Association, successor trustee to Wachovia Bank, National Association.
Utilities Form 8-K (9/12/06) 4.2
4.6 Form of Note Purchase Agreement dated October 30, 2013 between the Company and the purchasers listed as signatories thereto.
Utilities Form 8-K (10/30/13) 4.1
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
4.7 Note Purchase Agreement dated April 22, 2016 between the Company and the purchasers listed as signatories thereto.
Utilities Form 8-K (4/28/16) 4.1
4.8 Indenture, dated as of June 27, 2016, among AmeriGas Partners, L.P., AmeriGas Finance Corp., and U.S. Bank National Association, as trustee.
AmeriGas
Partners, L.P. Form 8-K (6/27/16) 4.1
4.9 First Supplemental Indenture, dated as of June 27, 2016, among AmeriGas Partners, L.P., AmeriGas Finance Corp., and U.S. Bank National Association, as trustee.
AmeriGas
Partners, L.P. Form 8-K (6/27/16) 4.2
4.10 Second Supplemental Indenture, dated as of December 28, 2016, among AmeriGas Partners, L.P., AmeriGas Finance Corp., and U.S. Bank National Association, as trustee (including form of global note).
AmeriGas
Partners, L.P. Form 8-K (12/28/16) 4.1
4.11 Third Supplemental Indenture, dated as of February 13, 2017, among AmeriGas Partners, L.P., AmeriGas Finance Corp., and U.S. Bank National Association, as trustee (including form of global note).
AmeriGas
Partners, L.P. Form 8-K (2/13/17) 4.1
4.12 Indenture, dated as of October 25, 2018, by and among International, the guarantors named therein, U.S. Bank National Association, as trustee, Elavon Financial Services DAC, as registrar and transfer agent, and Elavon Financial Services DAC, UK Branch, as paying agent (including the form of Note).
UGI Form 8-K
(10/25/18) 4.1
4.13 Form of Note Purchase Agreement dated December 21, 2018 between the Company and the purchasers listed as signatories thereto.
UGI Form 10-Q (12/31/18) 4.1
4.14 Note Purchase Agreement, dated as of March 19, 2020, by and among the Company and the purchasers listed as signatories thereto.
UGI Form 8-K
(3/19/20) 4.1
4.15 Note Purchase Agreement, dated May 7, 2021, by and among UGI Utilities, Inc. and the purchasers listed as signatories thereto.
UGI Form 8-K
(5/4/21) 4.1
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
4.16 Purchase Contract and Pledge Agreement, dated May 25, 2021, between the Company and U.S. Bank National Association, as purchase contract agent, collateral agent, custodial agent and securities intermediary.
UGI Form 8-K
(5/25/21) 4.1
4.17 Form of Corporate Unit (included as Exhibit A to Exhibit 4.16 hereto).
UGI Form 8-K
(5/25/21) 4.2
4.18 Form of Treasury Unit (included as Exhibit B to Exhibit 4.16 hereto).
UGI Form 8-K
(5/25/21) 4.3
4.19 Form of Cash Settled Unit (included as Exhibit C to Exhibit 4.16 hereto).
UGI Form 8-K
(5/25/21) 4.4
4.20 Form of Series A Cumulative Perpetual Convertible Preferred Stock Certificate.
UGI Form 8-K
(5/25/21) 4.5
4.21 Form of Series B Cumulative Perpetual Preferred Stock Certificate.
UGI Form 8-K
(5/25/21) 4.6
*4.22 Description of the Registrant’s Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934.
10.1** AmeriGas Propane, Inc. Non-Qualified Deferred Compensation Plan, as Amended and Restated effective November 22, 2013.
AmeriGas
Partners, L.P. Form 10-Q
(3/31/14) 10.4
10.2** UGI Corporation 2004 Omnibus Equity Compensation Plan Amended and Restated as of September 5, 2014.
UGI Form 10-K
(9/30/16) 10.25
10.3** UGI Corporation 2004 Omnibus Equity Compensation Plan Amended and Restated as of September 5, 2014 - Terms and Conditions as effective January 1, 2016.
UGI Form 10-K
(9/30/16) 10.26
10.4** UGI Corporation 2009 Deferral Plan, as Amended and Restated effective June 15, 2017.
UGI Form 10-Q (6/30/17) 10.6
10.5** UGI Corporation 2009 Supplemental Executive Retirement Plan for New Employees, as Amended and Restated as of June 15, 2017.
UGI Form 10-Q
(6/30/17) 10.1
10.6** AmeriGas Propane, Inc. Supplemental Executive Retirement Plan, as Amended and Restated effective June 15, 2017.
AmeriGas
Partners, L.P. Form 10-Q
(6/30/17) 10.1
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
10.7** UGI Corporation 2013 Omnibus Incentive Compensation Plan, effective as of September 5, 2014.
UGI Form 10-K
(9/30/16) 10.30
10.8** UGI Corporation 2013 Omnibus Incentive Compensation Plan, Terms and Conditions for Non-Employee Directors, effective January 1, 2019.
UGI Form 10-Q (3/31/19) 10.6
10.9** UGI Corporation Supplemental Executive Retirement Plan and Supplemental Savings Plan, as Amended and Restated effective April 1, 2015.
UGI Form 10-K
(9/30/17) 10.26
10.10** UGI Corporation Executive Annual Bonus Plan as amended November 15, 2018.
UGI Form 10-Q (3/31/19) 10.7
10.11** AmeriGas Propane, Inc. Executive Annual Bonus Plan as amended November 15, 2018.
UGI Form 10-Q (3/31/19) 10.10
10.12** UGI Corporation 2021 Incentive Award Plan.
UGI Form S-8
(2/4/21) 4.4
10.13** UGI Corporation Executive Severance Plan, as effective October 1, 2021.
UGI Form 8-K
(9/29/21) 10.1
10.14** Form of UGI Corporation 2013 Omnibus Incentive Compensation Plan, Nonqualified Stock Option Grant Letter for all US Employees.
UGI Form 10-Q
(3/31/21) 10.1
10.15** Form of UGI Corporation 2013 Omnibus Incentive Compensation Plan Performance Unit Grant Letter for all US Employees.
UGI Form 10-Q
(3/31/21) 10.2
10.16** Form of UGI Corporation 2013 Omnibus Incentive Compensation Plan Stock Unit Grant Letter for all US Employees.
UGI Form 10-Q
(3/31/21) 10.3
10.17** Form of UGI Corporation 2013 Omnibus Incentive Compensation Plan, Nonqualified Stock Option Grant Letter for Non-Employee Directors.
UGI Form 10-Q
(3/31/21) 10.4
10.18** Form of UGI Corporation 2013 Omnibus Incentive Compensation Plan Stock Unit Grant Letter for Non-Employee Directors.
UGI Form 10-Q
(3/31/21) 10.5
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
10.19** Form of UGI Corporation 2021 Incentive Award Plan Nonqualified Stock Option Grant Letter for all US Employees.
UGI Form 10-Q
(6/30/21) 10.1
10.20** Form of UGI Corporation 2021 Incentive Award Plan Performance Unit Grant Letter for all US Employees.
UGI Form 10-Q
(6/30/21) 10.2
10.21** Form of UGI Corporation 2021 Incentive Award Plan Stock Unit Grant Letter for all US Employees.
UGI Form 10-Q
(6/30/21) 10.3
10.22** Change in Control Agreement for Monica M. Gaudiosi dated as of April 23, 2012.
UGI Form 10-Q (6/30/12) 10.1
10.23** Amended and Restated Change in Control Agreement, dated December 6, 2019, between UGI Corporation and Mr. John L. Walsh.
UGI Form 10-Q (12/31/19) 10.1
10.24** Form of Confidentiality, Non-Competition and Non-Solicitation Agreement between UGI Corporation and Ted J. Jastrzebski.
UGI Form 10-Q
(6/30/18) 10.1
10.25** Form of Confidentiality, Non-Competition and Non-Solicitation Agreement between AmeriGas Propane, Inc. and Mr. Hugh J. Gallagher.
AmeriGas
Partners, L.P. Form 10-Q
(12/31/18) 10.1
10.26** Form of Confidentiality, Non-Competition and Non-Solicitation Agreement between UGI Corporation and Mr. Roger Perreault.
UGI Form 10-Q
(6/30/21) 10.4
10.27** Form of Change in Control Agreement, Amended and Restated, between AmeriGas Propane, Inc. and Mr. Hugh J. Gallagher.
AmeriGas
Partners, L.P. Form 10-Q
(12/31/18) 10.2
10.28** Form of Change in Control Agreement between UGI Corporation and Mr. Roger Perreault.
UGI Form 10-Q
(6/30/21) 10.5
10.29** Form of Confidentiality, Non-Competition and Non-Solicitation Agreement between UGI Corporation and Mr. Robert F. Beard.
UGI Form 10-K
(9/30/20) 10.27
10.30** Form of Change in Control Agreement between UGI Utilities, Inc. and Mr. Robert F. Beard.
UGI Form 10-K
(9/30/20) 10.28
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
*10.31** Form of Confidentiality, Non-Competition and Non-Solicitation Agreement between UGI Corporation and Ms. Judy Zagorski.
*10.32** Form of Change in Control Agreement between UGI Corporation and Ms. Judy Zagorski.
10.33 Trademark License Agreement dated April 19, 1995 among UGI Corporation, AmeriGas, Inc., AmeriGas Propane, Inc., AmeriGas Partners, L.P. and AmeriGas Propane, L.P.
UGI Form 10-K (9/30/10) 10.37
10.34 First Amendment, dated as of November 18, 2015, to Trademark License Agreement, dated April 19, 1995, by and among UGI Corporation, AmeriGas, Inc., AmeriGas Propane, Inc., AmeriGas Partners, L.P., and AmeriGas Propane, L.P.
AmeriGas
Partners, L.P. Form 10-K
(9/30/15) 10.4
10.35 Trademark License Agreement, dated April 19, 1995 among AmeriGas Propane, Inc., AmeriGas Partners, L.P. and AmeriGas Propane, L.P.
AmeriGas
Partners, L.P. Form 10-Q (12/31/10) 10.1
10.36 Form of Receivables Purchase Agreement, dated as of November 30, 2001, as amended through and including Amendment No. 18 thereto dated October 27, 2017, by and among UGI Energy Services, LLC, as servicer, Energy Services Funding Corporation, as seller, and PNC Bank, National Association, as issuer and administrator.
UGI Form 10-K
(9/30/17) 10.38
10.37 Amendment No. 19, dated as of October 26, 2018, to Receivables Purchase Agreement, dated as of November 30, 2001 (as amended, supplemented or modified from time to time), by and among UGI Energy Services, LLC, as servicer, Energy Services Funding Corporation, as seller, and PNC Bank, National Association, as issuer and administrator.
UGI Form 8-K
(10/26/18) 10.1
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
10.38 Amendment No. 20, dated as of October 25, 2019, to Receivables Purchase Agreement, dated as of November 30, 2001 (as amended, supplemented or modified from time to time), by and among UGI Energy Services, LLC, as servicer, Energy Services Funding Corporation, as seller, and PNC Bank, National Association, as issuer and administrator.
UGI Form 8-K (10/25/19) 10.1
10.39 Amendment No. 21, dated as of October 23, 2020, to Receivables Purchase Agreement, dated as of November 30, 2001, by and among UGI Energy Services, LLC, as servicer, Energy Services Funding Corporation, as seller, and PNC Bank, National Association, as issuer and administrator.
UGI Form 8-K
(10/23/20) 10.1
10.40 Amendment No. 22, dated as of October 22, 2021, to Receivables Purchase Agreement, dated as of November 30, 2001, by and among UGI Energy Services, LLC, as servicer, Energy Services Funding Corporation, as seller, and PNC Bank, National Association, as issuer and administrator.
UGI Form 8-K
(10/22/21) 10.1
10.41 Form of Purchase and Sale Agreement, dated as of November 30, 2001, as amended through and including Amendment No. 4 thereto dated October 1, 2013, by and between UGI Energy Services, LLC and Energy Services Funding Corporation.
UGI Form 10-K
(9/30/17) 10.39
10.42 FSS Service Agreement No. 79028 effective as of December 1, 2019 by and between Columbia Gas Transmission, LLC and UGI Utilities, Inc.
UGI Form 10-K
(9/30/19) 10.40
10.43 SST Service Agreement No. 79133 effective as of December 1, 2019 by and between Columbia Gas Transmission, LLC and UGI Utilities, Inc.
UGI Form 10-K
(9/30/19) 10.41
10.44 Gas Supply and Delivery Service Agreement between UGI Utilities, Inc. and UGI Energy Services, LLC, effective November 1, 2015.
Utilities Form 10-K (9/30/16) 10.19
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
10.45 First Amendment, dated November 1, 2020, to Gas Supply and Delivery Service Agreement First Amendment, dated November 1, 2020, to Gas Supply and Delivery Service Agreement between UGI Utilities, Inc. and UGI Energy Services, LLC, effective November 1, 2015. UGI Utilities, Inc. and UGI Energy Services, LLC, effective November 1, 2015.
UGI Form 10-K
(9/30/20) 10.41
10.46 Gas Supply and Delivery Service Agreement between UGI Utilities, Inc. and UGI Energy Services, LLC, effective November 1, 2020.
UGI Form 10-K
(9/30/20) 10.42
*10.47 Gas Supply and Delivery Service Agreement between UGI Utilities, Inc. and UGI Energy Services, LLC, effective November 1, 2021.
10.48 Credit Agreement, dated as of June 27, 2019, by and among UGI Utilities, Inc., as borrower, PNC Bank, National Association, as administrative agent, Citizens Bank, N.A., as syndication agent, and the lenders party thereto.
UGI Form 10-Q
(6/30/19) 10.1
10.49 Second Amended and Restated Credit Agreement dated as of December 15, 2017 by and among AmeriGas Propane, L.P., as Borrower, AmeriGas Propane, Inc., as a Guarantor, Wells Fargo Bank, National Association, as Administrative Agent, Swingline Lender, and Issuing Lender, Wells Fargo Securities, LLC, as Sole Lead Arranger and Sole Bookrunner, and the other financial institutions from time to time party thereto.
AmeriGas
Partners, L.P.
Form 8-K (12/15/17) 10.1
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
10.50 First Amendment, dated as of December 17, 2019, to Second Amended and Restated Credit Agreement, dated as of December 15, 2017, by and among AmeriGas Propane, L.P., as Borrower, AmeriGas Propane, Inc., as a Guarantor, Wells Fargo Bank, National Association, as Administrative Agent, Swingline Lender, and Issuing Lender, Wells Fargo Securities, LLC, as Sole Lead Arranger and Sole Bookrunner, and the other financial institutions from time to time party thereto.
UGI Form 10-Q
(12/31/19) 10.3
10.51 Multicurrency Facilities Agreement, effective October 25, 2018, among International, as borrower, Natixis, as agent, mandated lead arranger, bookrunner and coordinator, Barclays Bank Plc, BNP Paribas, Credit Agricole Corporate and Investment Bank, HSBC France, ING Bank N.V., French Branch, Mediobanca International (Luxembourg) S.A., Raiffeisen Bank International AG and Societe Generale Corporate and Investment Banking, as mandated lead arrangers, and certain other lenders.
UGI Form 8-K
(10/25/18) 4.2
10.52 Credit Agreement, dated as of August 13, 2019, by and among UGI Energy Services, LLC, as borrower, Credit Suisse AG, Cayman Islands Branch, as administrative agent and collateral agent, and the lenders party thereto.
UGI Form 8-K (8/13/19) 10.1
10.53 Third Amended and Restated Credit Agreement, dated as of March 6, 2020, by and among UGI Energy Services, LLC, as borrower, JPMorgan Chase Bank, N.A., as administrative agent, PNC Bank, National Association, as syndication agent, and Wells Fargo Bank, National Association, as documentation agent.
UGI Form 8-K
(3/6/20) 10.1
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
10.54 Amended and Restated Credit Agreement, dated as of May 4, 2021, by and among UGI Corporation and JPMorgan Chase Bank, N.A., as administrative agent, Citizens Bank, N.A., PNC Bank, National Association and Wells Fargo Bank, National Association, as co-documentation agents, and the other financial institutions from time to time party thereto.
UGI Form 8-K
(5/4/21) 10.1
10.55 First Amendment to the Amended and Restated Credit Agreement, dated as of June 23, 2021, by and among UGI Corporation, as borrower, JPMorgan Chase Bank, N.A., as administrative agent, and the lenders party thereto.
UGI Form 10-Q
(6/30/21) 10.6
*14 Code of Business Conduct and Ethics.
*21 Subsidiaries of the Registrant.
*23 Consent of Ernst & Young LLP
*31.1 Certification by the Chief Executive Officer relating to the Registrant’s Report on Form 10-K for the fiscal year ended September 30, 2021 pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*31.2 Certification by the Chief Financial Officer relating to the Registrant’s Report on Form 10-K for the fiscal year ended September 30, 2021 pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*32 Certification by the Chief Executive Officer and the Chief Financial Officer relating to the Registrant’s Report on Form 10-K for the fiscal year ended September 30, 2021, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*101.INS XBRL Instance - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
*101.SCH XBRL Taxonomy Extension Schema
*101.CAL XBRL Taxonomy Extension Calculation Linkbase
Incorporation by Reference
Exhibit No. Exhibit Registrant Filing Exhibit
*101.DEF XBRL Taxonomy Extension Definition Linkbase
*101.LAB XBRL Taxonomy Extension Labels Linkbase
*101.PRE XBRL Taxonomy Extension Presentation Linkbase
* Filed herewith.
** As required by Item 15(a)(3), this exhibit is identified as a compensatory plan or arrangement.