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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

	
 	
FORM 10-K
ANNUAL REPORT PURSUANT TO SECTIONS 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED SEPTEMBER 30, 2013
Commission file number 1-11071
UGI CORPORATION
(Exact name of registrant as specified in its charter)

			
Pennsylvania	 	23-2668356	
(State or Other Jurisdiction of
Incorporation or Organization)	 	(I.R.S. Employer Identification No.)	
460 North Gulph Road, King of Prussia, PA 19406
(Address of Principal Executive Offices) (Zip Code)
(610) 337-7000
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:

			
Title of Each Class	 	Name of each Exchange
on Which Registered	
Common Stock, without par value	 	New York Stock Exchange, Inc.	
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes þ No o
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes o No þ
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
Yes þ No o
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. þ
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

				
Large accelerated filer þ	Accelerated filer o	Non-accelerated filer o	Smaller reporting company o	
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes o No þ
The aggregate market value of UGI Corporation Common Stock held by non-affiliates of the registrant on March 31, 2013 was $4,362,169,553 .
At November 29, 2013 , there were 114,478,990 shares of UGI Corporation Common Stock issued and outstanding.
Portions of the Proxy Statement for the Annual Meeting of Shareholders to be held on January 30, 2014 are incorporated by reference into Part III of this Form 10-K.

	

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TABLE OF CONTENTS

		
 	Page	
Forward-Looking Information	2	
PART I:	 	
Items 1. and 2. Business and Properties	2	
Item 1A. Risk Factors	19	
Item 1B. Unresolved Staff Comments	25	
Item 3. Legal Proceedings	25	
Item 4. Mine Safety Disclosures	25	
PART II:	 	
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	26	
Item 6. Selected Financial Data	27	
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations	28	
Item 7A. Quantitative and Qualitative Disclosures About Market Risk	53	
Item 8. Financial Statements and Supplementary Data	54	
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	54	
Item 9A. Controls and Procedures	54	
Item 9B. Other Information	54	
PART III:	 	
Item 10. Directors, Executive Officers and Corporate Governance	55	
Item 11. Executive Compensation	55	
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	55	
Item 13. Certain Relationships and Related Transactions and Director Independence	55	
Item 14. Principal Accounting Fees and Services	55	
PART IV:	 	
Item 15. Exhibits and Financial Statement Schedules	58	
Signatures	73	
 	 	
Index to Financial Statements and Financial Statement Schedules	F-2	

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FORWARD-LOOKING INFORMATION

Information contained in this Annual Report on Form 10-K may contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Such statements use forward-looking words such as “believe,” “plan,” “anticipate,” “continue,” “estimate,” “expect,” “may,” or other similar words. These statements discuss plans, strategies, events or developments that we expect or anticipate will or may occur in the future.

A forward-looking statement may include a statement of the assumptions or bases underlying the forward-looking statement. We believe that we have chosen these assumptions or bases in good faith and that they are reasonable. However, we caution you that actual results almost always vary from assumed facts or bases, and the differences between actual results and assumed facts or bases can be material, depending on the circumstances. When considering forward-looking statements, you should keep in mind the following important factors which could affect our future results and could cause those results to differ materially from those expressed in our forward-looking statements: (1) adverse weather conditions resulting in reduced demand; (2) cost volatility and availability of propane and other liquefied petroleum gases, oil, electricity, and natural gas and the capacity to transport product to our customers; (3) changes in domestic and foreign laws and regulations, including safety, tax, consumer protection and accounting matters; (4) inability to timely recover costs through utility rate proceedings; (5) the impact of pending and future legal proceedings; (6) competitive pressures from the same and alternative energy sources; (7) failure to acquire new customers and retain current customers thereby reducing or limiting any increase in revenues; (8) liability for environmental claims; (9) increased customer conservation measures due to high energy prices and improvements in energy efficiency and technology resulting in reduced demand; (10) adverse labor relations; (11) large customer, counterparty or supplier defaults; (12) liability in excess of insurance coverage for personal injury and property damage arising from explosions and other catastrophic events, including acts of terrorism, resulting from operating hazards and risks incidental to generating and distributing electricity and transporting, storing and distributing natural gas and liquefied petroleum gases; (13) political, regulatory and economic conditions in the United States and in foreign countries, including foreign currency exchange rate fluctuations, particularly the euro; (14) capital market conditions, including reduced access to capital markets and interest rate fluctuations; (15) changes in commodity market prices resulting in significantly higher cash collateral requirements; (16) reduced distributions from subsidiaries; (17) the timing of development of Marcellus Shale gas production; (18) the timing and success of our acquisitions, commercial initiatives and investments to grow our businesses; and (19) our ability to successfully integrate acquired businesses and achieve anticipated synergies.

These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other unknown or unpredictable factors could also have material adverse effects on future results. We undertake no obligation to update publicly any forward-looking statement whether as a result of new information or future events except as required by the federal securities laws.

PART I:

ITEMS 1. AND 2. BUSINESS AND PROPERTIES
CORPORATE OVERVIEW

UGI Corporation (the “Company”) is a holding company that, through subsidiaries, distributes, stores, transports and markets energy products and related services. We are a domestic and international retail distributor of propane and butane (which are liquefied petroleum gases (“LPG”)); a provider of natural gas and electric service through regulated local distribution utilities; a generator of electricity; a regional marketer of energy commodities; an owner and manager of midstream assets; and a regional provider of heating, ventilation, air conditioning, refrigeration and electrical contracting services. Our subsidiaries and affiliates operate principally in the following six business segments:

•	AmeriGas Propane	
		
•	UGI International - Antargaz	
		
•	UGI International - Flaga & Other	
		
•	Energy Services	
		
•	Electric Generation	
		
•	Gas Utility	

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The AmeriGas Propane segment consists of the propane distribution business of AmeriGas Partners, L.P. (“AmeriGas Partners”), which is the nation’s largest retail propane distributor, and, prior to its merger with and into AmeriGas Propane, L.P. (“AmeriGas OLP”) on July 1, 2013, Heritage Operating, L.P. (“HOLP” and, together with AmeriGas Partners, the “Partnership”). The Partnership’s sole general partner is our subsidiary, AmeriGas Propane, Inc. (“AmeriGas Propane” or the “General Partner”). The common units of AmeriGas Partners represent limited partner interests in a Delaware limited partnership and they trade on the New York Stock Exchange under the symbol “APU.” We have an effective 26% ownership interest in the Partnership; Energy Transfer Partners, L.P., a Delaware limited partnership (“ETP”), has an effective 24% ownership interest in the Partnership and the remaining interest is publicly held. See Note 1 to Consolidated Financial Statements.

The UGI International - Antargaz segment consists of the LPG distribution business of our wholly owned subsidiary Antargaz, a French société anonyme, and our LPG distribution businesses in the Benelux countries (consisting of Belgium, the Netherlands, and Luxembourg) (collectively, “Antargaz”). Antargaz is one of the largest retail distributors of LPG in France and the Netherlands and the largest retail distributor of LPG in Belgium and Luxembourg.

The UGI International - Flaga & Other segment consists of the LPG distribution businesses of (i) Flaga GmbH, an Austrian limited liability company, and its subsidiaries (collectively, “Flaga”), (ii) AvantiGas Limited, a United Kingdom private limited company (“AvantiGas”), and (iii) ChinaGas Partners, L.P., a majority-owned Delaware limited partnership. Flaga is the largest retail LPG distributor in Austria and Denmark and one of the largest in Poland, the Czech Republic, Hungary, Slovakia, Norway, Sweden, and Finland. Flaga also distributes LPG in Romania and Switzerland. AvantiGas is an LPG distributor in the United Kingdom. ChinaGas Partners is an LPG distributor in the Nantong region of China. The UGI International - Antargaz and UGI International - Flaga & Other segments are collectively referred to as “UGI International.”

The Energy Services segment consists of energy-related businesses conducted by our wholly owned subsidiary, UGI Energy Services, LLC, which was formerly known as UGI Energy Services, Inc., and its subsidiaries. UGI Energy Services, Inc. was merged with and into UGI Energy Services, LLC, effective October 1, 2013 (“Energy Services”). These businesses include (i) energy marketing in the Mid-Atlantic region of the United States, (ii) operating and owning a natural gas liquefaction, storage and vaporization facility and propane-air mixing assets, (iii) managing natural gas pipeline and storage contracts, and (iv) developing, owning and operating pipelines, gathering infrastructure and gas storage facilities in the Marcellus Shale region of Pennsylvania.

The Electric Generation segment consists of electric generation facilities conducted by Energy Services’ wholly owned subsidiary, UGI Development Company (“UGID”). UGID has an approximate 5.97% (approximately 102 megawatt) ownership interest in a coal-fired generation station in Pennsylvania. UGID also owns and operates (i) a 130 megawatt natural gas-fueled generating station in Pennsylvania, (ii) an 11 megawatt landfill gas-fueled generation plant in Pennsylvania, and (iii) 9.41 megawatts of solar-powered generation capacity in Pennsylvania, Maryland and New Jersey. The Energy Services and Electric Generation segments are collectively referred to as “Midstream & Marketing.”

The Gas Utility segment (“Gas Utility”) consists of the regulated natural gas distribution businesses of our subsidiary, UGI Utilities, Inc. (“UGI Utilities”), and UGI Utilities’ subsidiaries, UGI Penn Natural Gas, Inc. (“PNG”) and UGI Central Penn Gas, Inc. (“CPG”). Gas Utility serves approximately 600,000 customers in eastern and central Pennsylvania and several hundred customers in portions of one Maryland county. UGI Utilities’ natural gas distribution utility is referred to as “UGI Gas.” Gas Utility is regulated by the Pennsylvania Public Utility Commission (“PUC”) and, with respect to its several hundred customers in Maryland, the Maryland Public Service Commission.

In addition to the segments set forth herein, UGI Corporation also owns and operates (i) a regulated electric distribution business in Pennsylvania through UGI Utilities (“Electric Utility”) and (ii) a heating, ventilation, air-conditioning, refrigeration and electrical contracting service business in the Mid-Atlantic region of the United States through UGI HVAC Enterprises, Inc. (“HVAC”).

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 are utilizing our core competencies from our existing businesses and our national scope, international experience, extensive asset base and access to customers to accelerate both internal growth and growth through acquisitions in our existing businesses, as well as in related and complementary businesses. During Fiscal 2013, we completed a number of transactions in pursuit of this strategy and made progress on larger internally generated capital projects, including infrastructure projects to support the development of natural gas in the Marcellus Shale region of Pennsylvania. A few of these transactions and projects are described below.

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During the last fiscal quarter of Fiscal 2013, Flaga expanded its LPG business in Poland by purchasing an LPG distribution business that distributed more than 150 million gallons in Fiscal 2012 in Poland. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and Note 5 to Consolidated Financial Statements.

During Fiscal 2013, Energy Services commenced a (i) pipeline project to extend a gathering system in the Marcellus Shale region of Pennsylvania, and (ii) a project to increase liquefaction capacity at its natural gas liquefaction, storage, and vaporization facility in Temple, Pennsylvania.  The pipeline extension project was completed during the first quarter of Fiscal 2014 and the liquefaction project in Temple, Pennsylvania is expected to be completed during Fiscal 2014.

In January of 2012, the Partnership acquired the subsidiaries of ETP that operated ETP’s propane distribution business (“Heritage Propane”) and completed the integration of Heritage Propane into the Partnership’s business during Fiscal 2013. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”
    
Corporate Information

UGI Corporation was incorporated in Pennsylvania in 1991. UGI Corporation is not subject to regulation by the PUC. UGI Corporation is a “holding company” under the Public Utility Holding Company Act of 2005 (“PUHCA 2005”). PUHCA 2005 and the implementing regulations of the Federal Energy Regulatory Commission (“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. Pursuant to a waiver granted in accordance with FERC’s regulations on the basis of UGI Corporation’s status as a single-state holding company system, UGI Corporation is not subject to certain of the accounting, record-keeping, and reporting requirements prescribed by FERC’s regulations.

Our executive offices are located at 460 North Gulph Road, King of Prussia, Pennsylvania 19406, and our telephone number is (610) 337-7000. In this report, the terms “Company” and “UGI,” as well as the terms “our,” “we,” and “its,” are sometimes used as abbreviated references to UGI Corporation or, collectively, UGI Corporation and its consolidated subsidiaries. Similarly, the terms “AmeriGas Partners” and the “Partnership” are sometimes used as abbreviated references to AmeriGas Partners, L.P. or, collectively, AmeriGas Partners, L.P. and its subsidiaries and the term “UGI Utilities” is sometimes used as an abbreviated reference to UGI Utilities, Inc. or, collectively, UGI Utilities, Inc. and its subsidiaries. The terms “Fiscal 2013” and “Fiscal 2012” refer to the fiscal years ended September 30, 2013 and September 30, 2012, respectively.

The Company’s corporate website can be found at www.ugicorp.com. Information on our website is not intended to be incorporated into this report. The Company makes available free of charge at this website (under the “Investor Relations and Corporate Governance - SEC Filings” 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, Code of Ethics for the Chief Executive Officer and Senior Financial Officers, Code of Business Conduct and Ethics for Directors, Officers and Employees, and charters of the Corporate Governance, Audit, Compensation and Management Development, and Safety, Environmental and Regulatory Compliance Committees of the Board of Directors are also available on the Company’s website, under the captions “Investor Relations - Corporate Governance - Committees.” All of these documents are also available free of charge by writing to Treasurer, 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 Partners. AmeriGas Propane is responsible for managing the Partnership. The Partnership serves over 2 million customers in all 50 states from over 2,500 propane distribution locations. In addition to distributing propane, the Partnership also sells, installs and services propane appliances, including heating systems. Typically, the Partnership’s locations are in suburban and rural areas where natural gas is not readily available. Our district offices generally consist of a business office, appliance showroom, warehouse, and service facilities, with one or more 18,000 to 30,000 gallon storage tanks on the premises. As part of its overall transportation and distribution infrastructure, the Partnership operates as an interstate carrier in 48 states throughout the continental United States. It is also licensed as a carrier in the Canadian Provinces of Ontario, British Columbia and Quebec.

The Partnership sells propane primarily to residential, commercial/industrial, motor fuel, agricultural and wholesale customers. The Partnership distributed nearly 1.4 billion gallons of propane in Fiscal 2013. Approximately 92% of the Partnership’s Fiscal 2013 sales (based on gallons sold) were to retail accounts and approximately 8% were to wholesale customers. Sales to

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residential customers in Fiscal 2013 represented approximately 42% of retail gallons sold; commercial/industrial customers 33%; motor fuel customers 12%; and agricultural customers 8%. Transport gallons, which are large-scale deliveries to retail customers other than residential, accounted for 5% of Fiscal 2013 retail gallons. No single customer represents, or is anticipated to represent, more than 5% of the Partnership’s consolidated revenues.

The Partnership continues to expand its AmeriGas Cylinder Exchange (“ACE”) program. At September 30, 2013, ACE cylinders were available at nearly 47,500 retail locations throughout the United States. Sales of our ACE cylinders to retailers are included in commercial/industrial sales. The ACE program enables consumers to purchase propane cylinders or exchange their empty propane cylinders at various retail locations such as home centers, gas stations, mass merchandisers and grocery and convenience stores. We also supply retailers with large propane tanks to enable retailers to replenish customers’ propane cylinders directly at the retailer’s location.

Residential customers use propane primarily for home heating, water heating and cooking purposes. Commercial users, which include hotels, restaurants, churches, warehouses and retail stores, generally use propane for the same purposes as residential customers. 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 who 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 over-the-road vehicles, forklifts, commercial lawn mowers, and stationary engines. Agricultural uses include tobacco curing, chicken brooding, and crop drying. In its wholesale operations, the Partnership 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. The Partnership 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. The Partnership also delivers propane in portable cylinders, including ACE cylinders. Some of these deliveries are made to the customer’s location, where empty cylinders are either picked up or replenished in place.

Propane Supply and Storage

The Partnership has approximately 250 domestic and international sources of supply, including the spot market. Supplies of propane from the Partnership’s sources historically have been readily available. During Fiscal 2013, approximately 90% of the Partnership’s propane supply was purchased under supply agreements with terms of 1 to 3 years. The availability of propane supply is 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 imported supply. 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 year 2014. 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. Enterprise Products Partners, L.P., Plains Marketing, and Targa Liquids Marketing & Trade supplied approximately 51% of the Partnership’s Fiscal 2013 propane supply. No other single supplier provided more than 10% of the Partnership’s total propane supply in Fiscal 2013. In certain geographical areas, however, a single supplier provides more than 50% of the Partnership’s requirements. Disruptions in supply in these areas could also have an adverse impact on the Partnership’s margins.

The Partnership’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 as determined by the General Partner. The Partnership 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. The Partnership stores propane at various storage facilities and terminals located in strategic areas across the United States.

Because the Partnership’s profitability is sensitive to changes in wholesale propane costs, the Partnership generally seeks to pass on increases in the cost of propane to customers. There is no assurance, however, that the Partnership will always be able to pass on product cost increases fully, 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. The General Partner has adopted 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 options and propane price swaps. See “Management’s Discussion and Analysis

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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 5 fiscal years at Mont Belvieu, Texas, a major storage area.
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 currently more expensive than propane, but the convenience of electricity makes it an attractive energy source for consumers. Fuel oil is also a major competitor of propane and is generally more expensive than propane. 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, liquefied natural gas 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, the Partnership’s ability to grow within the industry is dependent on its ability to acquire

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other retail distributors and to achieve internal growth, which includes expansion of the ACE program and the National Accounts program (through which the Partnership encourages multi-location propane users to enter into a supply agreement with it rather than with many suppliers), as well as the success of its sales and marketing programs designed to attract and retain customers. The failure of the Partnership 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. The Partnership competes in this business with other large propane marketers, including other full-service marketers, and thousands of small independent operators. Some rural electric cooperatives and fuel oil distributors have expanded their businesses to include propane distribution and the Partnership 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. The Partnership 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 2013, the Partnership’s retail propane sales totaled over 1.2 billion gallons. Based on the most recent annual survey by the American Petroleum Institute, 2011 domestic retail propane sales (annual sales for other than chemical uses) in the United States totaled approximately 8.9 billion gallons. Based on LP-GAS magazine rankings, 2011 sales volume of the ten largest propane companies (including AmeriGas Partners) represented approximately 40% of domestic retail sales.

Properties

As of September 30, 2013, the Partnership owned over 90% of its approximately 950 district 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, 2013, the Partnership operated a transportation fleet with the following assets:

				
Approximate Quantity & Equipment Type	% Owned	% Leased	
750	Trailers	85%	15%	
360	Tractors	13%	87%	
360	Railroad tank cars	4%	96%	
4,000	Bobtail trucks	49%	51%	
350	Rack trucks	6%	94%	
4,100	Service and delivery trucks	61%	39%	

Other assets owned at September 30, 2013 included approximately 1.8 million stationary storage tanks with typical capacities of more than 120 gallons and approximately 4.5 million portable propane cylinders with typical capacities of 1 to 120 gallons.

Trade Names, Trade and Service Marks

The Partnership markets propane principally under the “AmeriGas®”, “America’s Propane Company®”, “Heritage Propane®”, “Titan Propane” and “Relationships Matter®” trade names and related service marks. The Partnership also markets propane under other various trade names throughout the United States. 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 Gas 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 (on 12 months prior notice in the case of UGI), without penalty, if the General Partner is removed as general partner of the Partnership other than for cause. If the General Partner ceases to serve as the general partner of the Partnership for cause, the General Partner has the option to terminate its license agreement upon payment of a fee to UGI 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 the General Partner.

Seasonality

Because many customers use propane for heating purposes, the Partnership’s retail sales volume is seasonal. During Fiscal 2013, approximately 65% of the Partnership’s retail sales volume occurred, and substantially all of the Partnership’s operating income was earned, during the peak heating season from October through March. As a result of this seasonality, sales are typically higher in the Partnership’s first and second fiscal quarters (October 1 through March 31). Cash receipts are generally greatest

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during the second and third fiscal quarters when customers pay for propane purchased during the winter heating season.

Sales volume for the Partnership 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

The Partnership 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. Generally, these 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 federal Resource Conservation and Recovery Act, the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”), the Clean Air Act, the Occupational Safety and Health 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. We incur expenses associated with compliance with our obligations under federal and state environmental laws and regulations, and we believe that we are in material compliance with all of our obligations. We maintain various permits that are necessary to operate our facilities, some of which may be material to our operations. We continually monitor our operations with respect to potential environmental issues, including changes in legal requirements.

Hazardous Substances and Wastes

The Partnership is 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. 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 federal and most state environmental laws.

Health and Safety
The Partnership 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, state and local governmental authorities and responders, and local citizens in accordance with applicable federal and state Emergency Planning and Community Right-to-Know Act requirements. The Partnership’s operations are also subject to the safety hazard communication requirements and reporting obligations set forth in federal workplace standards.

All states in which the Partnership operates have adopted fire safety codes that regulate the storage and distribution of propane. In some states, these laws are administered by state agencies, and in others they are administered on a municipal level. The Partnership conducts training programs to help ensure that its operations are in compliance with applicable governmental regulations. With respect to general operations, National Fire Protection Association (“NFPA”) Pamphlets No. 54 and No. 58 and/or one or more of various international codes (including international fire, building and fuel gas codes) establish rules and procedures governing the safe handling of propane, or comparable regulations, which have been adopted by all states in which the Partnership operates. Management believes that the policies and procedures currently in effect at all of its facilities for the handling, storage and distribution of propane are consistent with industry standards and are in compliance in all material respects with applicable environmental, health and safety laws.

With respect to the transportation of propane by truck, the Partnership is subject to regulations promulgated under federal legislation, including the Federal Motor Carrier Safety Act and the Homeland Security Act of 2002. Regulations under these statutes cover the security and transportation of hazardous materials and are administered by the United States Department of Transportation (“DOT”), Pipeline and Hazardous Materials Safety Administration. 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, among other things, to a propane gas system that supplies 10 or more residential customers or 2 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

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in effect at all of the Partnership’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 greenhouse gas (“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, we anticipate that this will provide us 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 the Partnership, suppliers and customers. The impact of new legislation and regulations will depend on a number of factors, including (i) which industry sectors would be impacted, (ii) the timing of required compliance, (iii) the overall GHG emissions cap level, (iv) the allocation of emission allowances to specific sources, and (v) the costs and opportunities associated with compliance.

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, 2013, the General Partner had nearly 8,500 employees, including nearly 600 part-time, seasonal and temporary employees, working on behalf of the Partnership. UGI also performs certain financial and administrative services for the General Partner on behalf of the Partnership and is reimbursed by the Partnership.

UGI INTERNATIONAL - ANTARGAZ

Our UGI International - Antargaz LPG distribution business is conducted in France and the Benelux countries (consisting of Belgium, the Netherlands, and Luxembourg). Antargaz also operates a natural gas marketing business in France and the Benelux countries and sold approximately 4.8 million dekatherms of natural gas during Fiscal 2013.

Products, Services and Marketing

During Fiscal 2013, Antargaz sold approximately 258 million gallons of LPG in France and approximately 50 million gallons of LPG in the Benelux countries. Antargaz is one of the largest LPG distributors in France and the Netherlands and the largest LPG distributor in Belgium and Luxembourg. Antargaz’ customer base consists of residential, commercial, agricultural and motor fuel customer accounts that use LPG for space heating, cooking, water heating, process heat and transportation. Antargaz sells LPG in cylinders, and in small, medium and large tanks. Sales of LPG are also made to service stations to accommodate vehicles that run on LPG. Antargaz sells LPG in cylinders to approximately 16,000 retail outlets, such as supermarkets, individually owned stores and gas stations. Supermarket sales represented approximately 77% of butane cylinder sales volume and approximately 14% of propane cylinder sales volume in Fiscal 2013. At September 30, 2013, Antargaz had approximately 223,000 bulk customers, approximately 8,000 natural gas customers and over 9 million cylinders in circulation. Approximately 63% of Antargaz’ Fiscal 2013 sales (based on volumes) were cylinder and small bulk, 16% medium bulk, 18% large bulk and 3% to service stations for automobiles. Antargaz also engages in wholesale sales of LPG and provides logistic, storage and other services to third-party LPG distributors. In addition, Antargaz operates a natural gas marketing business in France and the Benelux countries that services both commercial and residential customers. No single customer represents, or is anticipated to represent, more than 5% of total revenues for Antargaz.

Sales to small bulk customers represent the largest segment of Antargaz’ business in terms of volume, revenue and total margin. Small bulk customers are primarily residential and small business users, such as restaurants, that use LPG mainly for heating and cooking. Small bulk customers also include municipalities, which use LPG for heating certain sports facilities and swimming pools, and the poultry industry for use in chicken brooding.

Medium bulk customers use propane only, and consist mainly of large residential developments such as housing developments, hospitals, municipalities and medium-sized industrial enterprises, and poultry brooders. Large bulk customers include agricultural companies and companies that use LPG in their industrial processes.

The principal end-users of cylinders are residential customers who use LPG supplied in this form for domestic applications such as cooking and heating. Butane cylinders accounted for approximately 54% of all LPG cylinders sold in Fiscal 2013, with propane cylinders accounting for the remainder. Propane cylinders are also used to supply fuel for forklift trucks. The market demand for cylinders has been declining, due primarily to customers gradually changing to other household energy sources for

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cooking and heating, such as natural gas and electricity.

LPG Supply and Storage

Antargaz has an agreement with Totalgaz for the supply of butane in France, with pricing based on internationally quoted market prices. Under this agreement, approximately 50% of Antargaz’ requirements for butane are guaranteed until September 2015. Requirements are fixed annually and Antargaz has developed other sources of supply. In Fiscal 2013, Antargaz purchased more than 50% of its butane requirements in France from SHV, TOTSA, and GUNVOR and purchased substantially all of its propane supply for its operations in France from SHV and TOTSA. In the Benelux countries, Antargaz purchased substantially all of its butane and propane requirements from SHV and GUNVOR during Fiscal 2013. Antargaz also purchases propane on the international market and on the domestic market, under term agreements with international oil and gas trading companies. In addition, purchases are made on the spot market from international oil and gas companies and to a lesser extent from domestic refineries, including those operated by Ineos and Esso SAF.

Antargaz has three primary storage facilities in operation that are located at deep sea harbor facilities, and 29 secondary storage facilities. It also manages an extensive logistics and transportation network. Access to seaborne facilities allows Antargaz to diversify its LPG supplies through imports. LPG stored in primary storage facilities is transported to smaller storage facilities by rail, sea and road. At secondary storage facilities, LPG is filled into cylinders or trucks equipped with tanks and then delivered to customers.

Competition and Seasonality

The LPG markets in France and the Benelux countries are mature, with modest declines in total demand due to competition with other fuels and other energy sources, conservation and the economic climate. Sales volumes are affected principally by the severity of the weather and customer migration to alternative energy forms, including natural gas and electricity. Because Antargaz’ profitability is sensitive to changes in wholesale LPG costs, Antargaz generally seeks to pass on increases in the cost of LPG to customers. There is no assurance, however, that Antargaz will always be able to pass on product cost increases fully 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. High LPG prices may result in slower than expected growth due to customer conservation and customers seeking less expensive alternative energy sources. France derives a significant portion of its electricity from nuclear power plants. Due to the nuclear power plants, as well as the regulation of electricity prices by the French government, electricity prices in France are generally less expensive than LPG. As a result, electricity has increasingly become a more significant competitor to LPG in France than in other countries where we operate. In addition, government policies and incentives that favor alternative energy sources can result in customers migrating to energy sources other than LPG in both France and the Benelux countries.

In France, Antargaz competes in all of its product markets on a national level principally with three LPG distribution companies, Totalgaz (owned by Total France), Butagaz (owned by Societe des Petroles Shell) and Compagnie des Gaz de Petrole Primagaz (owned by SHV Holding NV), as well as with a regional competitor, Vitogaz. In recent years, competition has increased as supermarkets affiliate with LPG distributors to offer their own brands of cylinders and they are now competitors of Antargaz. Antargaz has partnered with one supermarket chain in France in this market. If Antargaz is unsuccessful in expanding its services to other supermarket chains, its market share through supermarket sales may decline in France. In the Benelux countries, Antargaz competes in all of its product markets on a national level, principally with Compagnie des Gaz de Petrole Primagaz, as well as with several regional competitors. In recent years, competition has increased in the Benelux countries as small competitors have reduced their price offerings. In the Netherlands, several LPG distributors offer their own brands of cylinders. Antargaz seeks to increase demand for its butane and propane cylinders through marketing and product innovations. Some of Antargaz’ competitors are affiliates of its LPG suppliers. As a result, its competitors may obtain product at more competitive prices.

Because many of Antargaz’ customers use LPG for heating, sales volume is affected principally by the severity of the temperatures during the heating season months and traditionally fluctuate from year-to-year in response to variations in weather, prices and other factors, such as conservation efforts and the challenging economic climate. Demand for LPG is higher during the colder months of the year. During Fiscal 2013, approximately 65% of Antargaz’ retail sales volume occurred, and substantially all of Antargaz’ operating income was earned, during the six months from October through March. For historical information on weather statistics for Antargaz, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

Government Regulation

Antargaz’ business is subject to various laws and regulations at the national and European levels with respect to matters such as protection of the environment, the storage and handling of hazardous materials and flammable substances, the discharge

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of contaminants into the environment and the safety of persons and property. In Belgium and Luxembourg, Antargaz is also subject to price regulations that permit Antargaz to increase the price of LPG sold to small bulk, medium bulk, large bulk and cylinder customers (up to a defined maximum price) when Antargaz’ costs fluctuate.

Properties

Antargaz has 3 primary storage facilities in operation. One of these is a refrigerated facility. In addition, Antargaz is able to use 30,000 cubic meters of capacity of a storage facility, Donges, by virtue of Antargaz’ 50% ownership of Donges GIE. The table below sets forth details of Antargaz’ 3 primary storage facilities:

	
									
 	Ownership %	 	Antargaz
Storage Capacity -
Propane
(m3) (1)	 	Antargaz
Storage Capacity -
Butane
(m3) (1)	
GIE Norgal	52.7		 	22,600		 	8,900		
Geogaz Lavera	16.7		 	17,400		 	32,500		
Cobogal	15.0		 	1,300		 	450		
_________________
		
(1)	Cubic meters (1 cubic meter is equivalent to approximately 264 gallons).	

Antargaz has 29 secondary storage facilities, 19 of which are wholly owned. The others are partially owned through joint ventures.
Employees

At September 30, 2013, Antargaz had approximately 1,140 employees.

UGI INTERNATIONAL - FLAGA & OTHER

During Fiscal 2013, our UGI International - Flaga & Other LPG distribution business was conducted principally in Europe through our wholly owned subsidiaries, Flaga and AvantiGas, and in China through our majority owned partnership, ChinaGas Partners, L.P. Flaga is referred to in this section collectively with its subsidiaries as “Flaga” unless the context otherwise requires. Flaga operates in Austria, the Czech Republic, Denmark, Finland, Hungary, Norway, Poland, Romania, Slovakia, Sweden and Switzerland and expanded its operations in Poland through an acquisition in the last quarter of Fiscal 2013. AvantiGas operates in the United Kingdom.

During Fiscal 2013, Flaga sold approximately 239 million gallons of LPG. Flaga is the largest distributor of LPG in Austria and Denmark and one of the largest distributors of LPG in Poland, the Czech Republic, Hungary, Slovakia, Norway, Sweden, and Finland. During Fiscal 2013, AvantiGas sold approximately 145 million gallons of LPG and our majority-owned partnership in China sold approximately 9 million gallons of LPG.

FLAGA

Products, Services and Marketing

During Fiscal 2013, Flaga sold approximately 239 million gallons of LPG (of which approximately 15 million gallons were to wholesale customers). Flaga serves customers that use LPG for residential, commercial, industrial, agricultural, resale, and automobile fuel (“auto gas”) purposes. Flaga’s customers primarily use LPG for heating, cooking, motor fuel (including forklifts), leisure activities, construction work, manufacturing, crop drying, power generation and irrigation. Flaga sells LPG in cylinders and in small, medium, and large bulk tanks. At September 30, 2013, Flaga had over 70,000 customers and 5.5 million cylinders in circulation. Approximately 27% of Flaga’s Fiscal 2013 sales (based on volumes) were cylinder and small bulk, 21% auto gas, 46% large bulk, and 6% medium bulk.

Flaga has a total of 18 sales offices throughout the countries it serves, although it does not have sales offices in Norway, Sweden or Finland, largely due to the commercial and industrial nature of Flaga’s business in those countries. Sales offices generally consist of an office location where customers can directly purchase LPG. Except for Poland, no single country’s total gallons of LPG sold during Fiscal 2013 represented more than 13% of Flaga’s total gallons in Fiscal 2013. Flaga distributes cylinders directly to its customers and through the use of distributors who resell the cylinders to end users under the distributor’s

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pricing and terms. No single customer represents or is anticipated to represent more than 5% of total revenues for Flaga, with the exception of one auto gas customer that represented approximately 7% of Flaga’s total revenues in Fiscal 2013.

LPG Supply and Storage

Flaga typically enters into an annual LPG supply agreement with TCO/Chevron. During Fiscal 2013, TCO/Chevron supplied approximately 33% of Flaga’s LPG requirements, with pricing based on internationally quoted market prices. Flaga also purchases LPG on the international market and on the domestic markets, under annual term agreements with international oil and gas trading companies, including Vitol and Orlen Gas, and from domestic refineries, primarily OMV, Shell and Statoil. In addition, LPG purchases are made on the spot market from international oil and gas traders. During Fiscal 2013, 80 suppliers accounted for approximately 67% of Flaga’s LPG supply.

Flaga operates 12 main storage facilities, including one in Denmark that is located at a deep sea harbor facility, one LPG import terminal in Poland, and 60 secondary storage facilities. Flaga manages a widespread logistics and transportation network including approximately 203 leased railcars, and also maintains various transloading and filling agreements with third parties. LPG stored in primary storage facilities is transported to smaller storage facilities by rail or truck.

Competition and Seasonality

The retail propane industry in the Western European countries in which Flaga operates is mature, with slight declines in overall demand in recent years, due primarily to the expansion of natural gas, customer conservation and economic conditions. In the Eastern European countries in which Flaga operates, the demand for LPG is expected to grow. Competition for customers is based on contract terms as well as on product prices. Flaga competes with other LPG marketers, including competitors located in other European countries, and also competes with providers of other sources of energy, principally natural gas, electricity and wood.

Because many of Flaga’s customers use LPG for heating, sales volumes in Flaga’s sales territories are affected principally by the severity of the temperatures during the heating season months and traditionally fluctuate from year-to-year in response to variations in weather, prices and other factors, such as conservation efforts and the economic climate. Because Flaga’s profitability is sensitive to changes in wholesale LPG costs, Flaga generally seeks to pass on increases in the cost of LPG to customers. There is no assurance, however, that Flaga will always be able to pass on product cost increases fully when product costs rise rapidly. In parts of Flaga’s sales territories, it is particularly difficult to pass on rapid increases in the price of LPG due to the low per capita income of customers in several of its territories and the intensity of competition. 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. High LPG prices may result in slower than expected growth due to customer conservation and customers seeking less expensive alternative energy sources. In many of Flaga’s sales territories, government policies and incentives that favor alternative energy sources may result in customers migrating to energy sources other than LPG. Rules and regulations applicable to LPG industry operations in many of the Eastern European countries where Flaga operates are still evolving, or are not consistently enforced, causing intensified competitive conditions in those areas.

Government Regulation

Flaga’s business is subject to various laws and regulations at both the national and European levels with respect to matters such as protection of the environment and the storage and handling of hazardous materials and flammable substances.

Employees

At September 30, 2013, Flaga had approximately 975 employees.

AVANTIGAS

Products, Services and Marketing

During Fiscal 2013, AvantiGas sold approximately 145 million gallons of LPG (of which approximately 83 million gallons were wholesale gallons). At September 30, 2013, AvantiGas had approximately 14,600 customers. AvantiGas serves customers that use LPG for wholesale, aerosol, agricultural, residential, commercial, industrial, and auto gas purposes. AvantiGas’ customers primarily use LPG for heating, cooking, motor fuel (including forklifts), leisure activities, industrial processes and aerosol propellant. AvantiGas sells LPG in small, medium, and large bulk tanks with small bulk sales representing approximately 6% of Fiscal 2013 sales (based on volumes), medium bulk sales representing approximately 36% of Fiscal 2013 sales and large

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bulk sales representing approximately 58% of Fiscal 2013 sales.

AvantiGas serves its customer base through a centralized customer service center and, therefore, does not have sales offices in the United Kingdom. Sales to wholesale customers represented approximately 58% of gallons sold; aerosol customers 20%; agricultural customers 7%; residential customers 6%; and commercial, industrial and autogas 9%. Three wholesale customers and one aerosol customer collectively represented over 46% of AvantiGas’ total revenues in Fiscal 2013. No other customer represents or is anticipated to represent more than 5% of total revenues for AvantiGas.

LPG Supply and Storage

AvantiGas has five-year agreements, which will terminate during the 2016 fiscal year, with Essar Energy plc’s Stanlow refinery and STASCO’s Mossmorran terminal for the supply of an aggregate of approximately 93% of AvantiGas’ LPG requirements, with pricing based on internationally quoted market prices. AvantiGas purchased the remainder of its LPG requirements from other third party suppliers.

AvantiGas operates 8 main storage facilities in England, Scotland and Wales. AvantiGas manages a logistics and transportation network, consisting of approximately 38 trucks, and also maintains various transportation agreements with third parties. LPG stored in primary storage facilities is transported to smaller storage facilities or customers by truck.

Competition and Seasonality

The retail propane industry in the United Kingdom is highly concentrated and is mature, with slight declines in overall demand in recent years, due primarily to the expansion of natural gas, customer conservation and challenging economic conditions. Competition for customers is based on contract terms as well as on product prices. AvantiGas competes with other LPG marketers in the United Kingdom.

Because many of AvantiGas’ customers use gas for heating purposes, sales volumes in AvantiGas’ sales territories are affected principally by the severity of the temperatures during the heating season months and traditionally fluctuate from year-to-year in response to variations in weather, prices and other factors, such as energy conservation efforts and the economic climate. During Fiscal 2013, over 55% of AvantiGas’ retail sales volume occurred, and approximately 70% of AvantiGas’ operating income was earned, during the peak heating season where AvantiGas operates. Because AvantiGas’ profitability is sensitive to changes in wholesale LPG costs, AvantiGas generally seeks to pass on increases in the cost of LPG to customers. There is no assurance, however, that AvantiGas will always be able to pass on product cost increases fully 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. High LPG prices may result in slower than expected growth due to customer conservation and customers seeking less expensive alternative energy sources.

Government Regulation

AvantiGas’ business is subject to various laws and regulations at both the national and European levels with respect to matters such as competition, protection of the environment and the storage and handling of hazardous materials and flammable substances.

Employees

At September 30, 2013, AvantiGas had approximately 175 employees.

ENERGY SERVICES

Retail Energy Marketing

Energy Services sells natural gas, liquid fuels and electricity to approximately 17,000 commercial and industrial customers at approximately 41,000 locations. Energy Services serves customers in all or portions of Pennsylvania, New Jersey, Delaware, New York, Ohio, Maryland, Massachusetts, Virginia, North Carolina and the District of Columbia. Energy Services distributes natural gas through the use of the distribution systems of 36 local gas utilities. It supplies power to customers through the use of the transmission systems 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

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a specified period, and to pay for the product 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 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 the New York Mercantile Exchange, (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

Energy Services operates a natural gas liquefaction, storage and vaporization facility in Temple, Pennsylvania (“Temple Facility”), and propane storage and propane-air mixing stations in Bethlehem, Reading, Hunlock Creek, and White Deer, Pennsylvania. It also operates propane storage, rail transshipment terminals, and propane-air mixing stations in Steelton and Williamsport, Pennsylvania. These assets are used in Energy Services’ energy peaking business that provides supplemental energy, primarily liquefied natural gas and propane-air mixtures, to gas utilities on interstate pipelines at times of high demand (generally during periods of coldest winter weather). In Fiscal 2013, Energy Services expanded its energy peaking services at the Temple Facility and sold liquefied natural gas to customers for use by trucks, drilling rigs, other motor vehicles and facilities located off the gas grid. Energy Services also manages natural gas pipeline and storage contracts for UGI Utilities, subject to a competitive bid process, as well as storage capacity owned by Energy Services.

A wholly owned subsidiary of Energy Services owns and operates underground natural gas storage and related high pressure pipeline facilities formerly owned by CPG, which have FERC approval to sell storage services at market-based rates. The storage facilities are located in the Marcellus Shale region of Pennsylvania and have a total storage capacity of 15 million decatherms and a maximum daily withdrawal quantity of 224,000 decatherms. In Fiscal 2013, Energy Services leased more than 70% of the capacity at its underground natural gas facilities to third parties.

In Fiscal 2013, Energy Services began operating a new compressor station and is now able to receive natural gas from the Tennessee Gas Pipeline for injection into the storage facility on a firm basis throughout the year.

In Fiscal 2013, Energy Services continued making investments in infrastructure projects to support the development of natural gas in the Marcellus Shale region of Pennsylvania. During Fiscal 2013, Energy Services invested capital to extend its gathering system to transport natural gas from Wyoming County, Pennsylvania through a newly constructed pipeline to an interstate pipeline in Luzerne County, Pennsylvania. This project was completed during the first quarter of Fiscal 2014. The gathering system will provide for (i) expanded capacity through additional compression; and (ii) additional delivery options by connecting the region served by PNG and two interstate pipelines with Marcellus producers.

Future planned investments are expected to cover a range of midstream asset opportunities, including interstate pipelines, local gathering systems and gas storage facilities and complementary and related investments in natural gas exploration, production and refining.

Competition

Energy Services competes with other midstream operators to sell gathering, compression, storage, and pipeline transportation services. Energy Services competes in both the regulated and non-regulated environment against interstate and intrastate pipelines that gather, compress, process, transport, and market natural gas. Energy Services 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.

Energy Services 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. Energy Services has faced an increase in competition as new markets for natural gas, liquid fuels, electric power, and related services have emerged.

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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. Energy Services also has market-based rate authority for power sales to wholesale customers to the extent that Energy Services purchases power in excess of its retail customer needs.  Two subsidiaries of Energy Services operate natural gas storage facilities under FERC certificate approvals and offer services to wholesale customers at FERC-approved market-based rates.  Energy Services is also subject to FERC reporting requirements, market manipulation rules and other FERC enforcement and regulatory powers.

Energy Services is 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. Energy Services also is required to comply with the provisions of the Pipeline Safety Act and the regulations of the U.S. DOT with respect to the operation of natural gas gathering and transportation pipelines.

Employees

At September 30, 2013, Energy Services had approximately 185 employees.

ELECTRIC GENERATION
Products and Services

UGID has an approximate 5.97% (approximately 102 megawatt) ownership interest in the Conemaugh generation station (“Conemaugh”), a 1,711 megawatt, coal-fired generation station located near Johnstown, Pennsylvania. Conemaugh is owned by a consortium of energy companies and operated by a unit of NRG Energy. UGID also owns and operates the Hunlock Station located near Wilkes-Barre, Pennsylvania, a 130-megawatt natural gas-fueled generating station.

UGID also owns and operates a landfill gas-fueled generation plant near Hegins, Pennsylvania, with gross generating capacity of 11 megawatts. The plant qualifies for renewable energy credits.

UGID also owns and operates 9.41 megawatts of solar-powered generation capacity in Pennsylvania, Maryland and New Jersey. Several other solar generation projects are in development.

Competition

UGID competes with other generation stations on the interface of PJM Interconnection, LLC (“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. Generally, each power generator has a small share of the total market on PJM.

Government Regulation

UGID owns 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.  UGID is also subject to FERC reporting requirements, market manipulation rules and other FERC enforcement and regulatory powers.

Employees

At September 30, 2013, UGID had approximately 25 employees.

GAS UTILITY

Gas Utility consists of the regulated natural gas distribution businesses of our subsidiary, UGI Utilities, and UGI Utilities’ subsidiaries, PNG and CPG. Gas Utility serves approximately 600,000 customers in eastern and central Pennsylvania and several hundred customers in portions of one Maryland county. Gas Utility is regulated by the PUC and, with respect to its several hundred

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customers in Maryland, the Maryland Public Service Commission.

Service Area; Revenue Analysis

Gas Utility is authorized to distribute natural gas to approximately 600,000 customers in portions of 46 eastern and central Pennsylvania counties through its distribution system of approximately 12,000 miles of gas mains. Contemporary materials, such as plastic or coated steel, comprise approximately 85% of Gas Utility’s 12,000 miles of gas mains, with bare steel pipe comprising approximately 11% and cast iron pipe comprising approximately 4% of Gas Utility’s gas mains. In accordance with Gas Utility’s agreement with the PUC, Gas Utility will replace the cast iron portion of its gas mains by March of 2027 and the bare steel portion by March of 2043. 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 boroughs of Honesdale and Milford, Pennsylvania. Located in Gas Utility’s service area are major production centers for basic industries such as specialty metals, aluminum, glass and paper product manufacturing. Gas Utility also distributes natural gas to several hundred 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 2013 was approximately 192.1 billion cubic feet (“bcf”). System sales of gas accounted for approximately 29% of system throughput, while gas transported for residential, commercial and industrial customers who bought their gas from others accounted for approximately 71% of system throughput.

Sources of Supply and Pipeline Capacity

Gas Utility is permitted to recover 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 marketers and producers, along with storage and transportation service contracts. These arrangements enable Gas Utility to purchase gas from Gulf Coast, Mid-Continent, Appalachian and Canadian sources. For the transportation and storage function, Gas Utility has long-term agreements with a number of pipeline companies, including Texas Eastern Transmission Corporation, Columbia Gas Transmission, LLC, Transcontinental Gas Pipeline Company, LLC, Dominion Transmission, Inc., ANR Pipeline Company, and Tennessee Gas Pipeline Company, L.L.C.

Gas Supply Contracts

During Fiscal 2013, Gas Utility purchased approximately 77.7 bcf of natural gas for sale to core-market customers (principally comprised of firm- residential, commercial and industrial customers that purchase their gas from Gas Utility (“retail core market”)) and off-system sales customers. Approximately 74% of the volumes purchased were supplied under agreements with 10 suppliers. The remaining 26% of gas purchased by Gas Utility was supplied by approximately 36 producers and marketers. Gas supply contracts for Gas Utility are generally no longer than 1 year. 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. During Fiscal 2013, nearly 65% of Gas Utility’s sales volume was supplied, and over 85% 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.

In substantially all of its service territories, Gas Utility is the only regulated gas distribution utility having the right, granted by the PUC or by law, to provide gas distribution services. Since the 1980s, larger commercial and industrial customers have been able to purchase gas supplies from entities other than natural gas distribution utility companies. As a result of Pennsylvania’s Natural Gas Choice and Competition Act, effective July 1, 1999, all of Gas Utility’s customers, including core-market customers, have been afforded this opportunity.

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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 alternate fuel. 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, as well as the frequency and duration of interruptions. See “Gas Utility Regulation and Rates - Pennsylvania Public Utility Commission Jurisdiction and Gas Utility Rates.”

Approximately 34% of Gas Utility’s commercial and industrial customers’ annual throughput volume, including certain customers served under interruptible rates, have locations that afford them the opportunity of seeking transportation service directly from interstate pipelines, thereby bypassing Gas Utility. Gas Utility has approximately 30 of such customers with transportation contracts extending beyond Fiscal 2013. 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 year 2014. Supply mix is diversified, market priced, and delivered pursuant to a number of long-term and short-term firm transportation and storage arrangements, including transportation contracts held by some of Gas Utility’s larger customers.

During Fiscal 2013, Gas Utility supplied transportation service to 4 major co-generation installations and 6 electric generation facilities. Gas Utility continues to seek new residential, commercial and industrial customers for both firm and interruptible service. In Fiscal 2013, Gas Utility connected approximately 1,900 new commercial and industrial customers. In the residential market sector, Gas Utility connected over 15,000 residential heating customers during Fiscal 2013. Nearly 8,800 of these customers converted to natural gas from other energy sources, mainly oil and electricity. New home construction customers 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 2013.

UGI Utilities 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.

UGI Utilities’ objective in negotiations with interstate pipeline and natural gas suppliers, and in proceedings before regulatory agencies, is to assure availability of supply, transportation and storage alternatives to serve market requirements at the lowest cost possible, taking into account the need for security of supply. Consistent with that objective, UGI Utilities negotiates the 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.

GAS UTILITY REGULATION AND RATES

Pennsylvania Public Utility Commission Jurisdiction and Gas Utility Rates

Gas Utility is subject to regulation by the PUC as to rates, terms and conditions of service, accounting matters, issuance of securities, contracts and other arrangements with affiliated entities, and various other matters. Rates that Gas Utility may charge for gas service come in two forms: (1) rates designed to recover PGCs; and (2) 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.

UGI Gas has two PGC rates: (1) applicable to small, firm, retail core-market customers consisting of the residential and small commercial and industrial classes; and (2) applicable to firm, contractual, high-load factor customers served on three separate rates. The most recent general base rate increase for UGI Gas became effective in 1995. In accordance with a statutory mechanism, a rate increase for UGI Gas’ retail core-market customers became effective October 1, 2000 along with a PGC variable credit equal to a portion of the margin received from customers served under interruptible rates to the extent such interruptible customers use third-party pipeline capacity contracted for by UGI Gas for retail core-market customers.

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PNG and CPG each have one PGC rate applicable to all customers. On August 11, 2011, the PUC approved CPG’s base rate case settlement agreement, which resulted in an $8.9 million base rate operating revenue increase for CPG. The increase became effective on August 30, 2011. On June 21, 2012, the PUC reversed its earlier decision solely related to the $0.9 million increase in revenues associated with the Energy Efficiency and Conservation Plan filed by CPG as part of the August 11, 2011 base rate case settlement. As a result, $0.9 million of base rate operating revenue that was collected as part of this plan has been refunded to customers. On August 27, 2009, the PUC approved PNG’s base rate case settlement agreement, which resulted in a $19.75 million base rate operating revenue increase for PNG, effective August 28, 2009.

The gas service tariffs for UGI Gas, PNG and CPG contain PGC rates applicable to firm retail rate schedules. These PGC rates permit recovery of substantially all of the prudently incurred costs of natural gas that UGI Gas, PNG, and CPG sell to their customers. PGC rates are reviewed and approved annually by the PUC. UGI Gas, PNG, and CPG may request quarterly or, under certain conditions, monthly adjustments to reflect the actual cost of gas. Quarterly adjustments become effective on 1 day’s notice to the PUC and are subject to review during the next annual PGC filing. Each proposed annual PGC rate is required to be filed with the PUC 6 months prior to its effective date. During this period, the PUC holds 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 PUC issues an order permitting the collection of gas costs at levels that meet that standard. The PGC mechanism also provides for an annual reconciliation.

FERC Market Manipulation Rules and Other FERC Enforcement and Regulatory Powers

Gas Utility is subject to Section 4A of the Natural Gas Act and Section 222 of the Federal Power Act, which prohibit 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.

State Tax Surcharge Clauses

UGI Utilities’ gas service tariffs contain state tax surcharge clauses. The surcharges are recomputed whenever any of the tax rates included in their calculation are changed. These clauses protect UGI Utilities from the effects of increases in most of the Pennsylvania taxes to which it is subject.

Utility Franchises

UGI Utilities, PNG and CPG each hold certificates of public convenience issued by the PUC and certain “grandfather rights” predating the adoption of the Pennsylvania Public Utility Code and its predecessor statutes, which each of them believes are adequate to authorize them to carry on their business in substantially all of the territories to which they now render gas service. Under applicable Pennsylvania law, UGI Utilities, PNG and CPG also have certain rights of eminent domain as well as the right to maintain their facilities in streets and highways in their territories.

Other Government Regulation

In addition to regulation by the PUC and FERC, Gas Utility is subject to various federal, state and local laws governing environmental matters, occupational health and safety, pipeline safety and other matters. Gas Utility is subject to the requirements of the federal Resource Conservation and Recovery Act, CERCLA and comparable state statutes with respect to the release of hazardous substances on property owned or operated by Gas Utility. See Note 9 to Consolidated Financial Statements.

Employees

At September 30, 2013, Gas Utility had approximately 1,335 employees.

ELECTRIC UTILITY AND HVAC

ELECTRIC UTILITY

Electric Utility supplies electric service to approximately 62,000 customers in portions of Luzerne and Wyoming counties in northeastern Pennsylvania through a system consisting of over 1,900 miles of lines and 13 substations. At September 30, 2013, UGI Utilities’ electric utility operations had approximately 70 employees.

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In accordance with Electric Utility’s default service settlement with the PUC effective January 1, 2010, 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 the PUC. UGI Utilities’ electric utility operations are subject to regulation by the PUC as to rates, terms and conditions of service, accounting matters, issuance of securities, contracts and other arrangements with affiliated entities, and various other matters. The most recent general base rate increase for Electric Utility became effective in 1996. PUC default service regulations became applicable to Electric Utility’s provision of default service effective January 1, 2010 and Electric Utility, consistent with these regulations, has received PUC approval through May 31, 2017 of (1) default service tariff rules, (2) a reconcilable default service cost rate recovery mechanism to recover the cost of acquiring default service supplies, (3) a plan for meeting the post-2009 requirements of the Alternative Energy Portfolio Standards Act (“AEPS Act”), which requires Electric Utility to directly or indirectly acquire certain percentages of its supplies from designated alternative energy sources, and (4) a reconcilable AEPS Act cost recovery rate mechanism to recover the costs of complying with AEPS Act requirements applicable to default service supplies for service rendered through May 31, 2017. Under these rules, default service rates for most customers are adjusted quarterly.

In an order entered on February 15, 2013, the PUC announced that it plans to seek legislative changes that would end the default service obligations of Pennsylvania electric distribution companies.  In October 2013, a Senate bill was proposed to terminate default service obligations in Pennsylvania effective June 1, 2015.  Under the proposed legislation, customers who do not select a retail electricity supplier would be assigned a supplier. 

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.

HVAC

We conduct our heating, ventilation, air-conditioning, refrigeration and electrical contracting service business through HVAC, which serves portions of eastern Pennsylvania and the Mid-Atlantic region, including the Philadelphia suburbs and portions of New Jersey and northern Delaware. This business serves more than 90,000 customers in residential, commercial, industrial and new construction markets. During Fiscal 2013, HVAC generated approximately $84 million in revenues and had approximately 450 employees.
BUSINESS SEGMENT INFORMATION

The table stating the amounts of revenues, operating income (loss) and identifiable assets attributable to each of UGI’s reportable business segments, and to the geographic areas in which we operate, for the 2013, 2012 and 2011 fiscal years appears in Note 22 to Consolidated Financial Statements included in Item 8 of this Report and is incorporated herein by reference.

EMPLOYEES

At September 30, 2013, UGI and its subsidiaries had over 12,800 employees.
ITEM 1A. RISK FACTORS

There are many factors that may affect our business and results of operations. Additional discussion regarding factors that may affect our business and operating results is included elsewhere in this Report.

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Decreases in the demand for our energy products and services because of warmer-than-normal heating season weather 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, 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 Partners’ annual retail propane volume and Antargaz’ annual retail LPG volume, and 60% to 65% of Gas Utility’s natural gas throughput (the total volume of gas sold to or transported for customers within our distribution system) has been sold during these months. There can be no assurance that normal winter weather in our market areas will occur in the future.

Our holding company structure could limit our ability to pay dividends or debt service.

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. and UGI Enterprises, Inc. (including Antargaz). 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, 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.

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 the LPG supply costs. LPG is a commodity, and, as such, its unit price is subject to volatile fluctuations in response to changes in supply or other market conditions. We have no control over these market conditions. Consequently, the unit price of the LPG that our subsidiaries and other 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. Because our subsidiaries’ profitability is sensitive to changes in wholesale propane supply costs, it will be adversely affected if we cannot pass on increases in the cost of propane to our customers. Due to competitive pricing in the industry, our subsidiaries may not be able to pass on product cost increases to our customers when product costs rise rapidly, or when our competitors do not raise their product prices. 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.

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 conservation and technological advances, including installation of improved insulation and the development of more efficient furnaces and other heating devices, may reduce the demand for energy products. Prices for LPG and natural gas are subject to volatile fluctuations in response to changes in supply and 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. 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.

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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.

The 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. Developments in the credit markets during the past few years increase our possible exposure to the liquidity, default and credit risks of our suppliers, 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, such market conditions could restrict our ability to grow through acquisitions, could limit the scope of major capital projects if access to credit and capital markets is limited, or adversely affect our operating results.

Economic recession, volatility in the stock market and the low interest rate environment may negatively impact our pension liability.

Economic recession, volatility in the stock market and the low interest rate environment have had 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 continued low interest rates, could further impact our pension liability and funded status and increase the amount of required contributions to our pension plans.
The adoption of financial reform legislation by the United States Congress and related regulations may have an adverse effect on our ability to use derivative instruments to hedge risks associated with our business.
Congress adopted the Dodd-Frank Wall Street Reform and Consumer Protection Act in 2010, which contains comprehensive financial reform legislation. That act imposes regulation on the over-the-counter derivatives market and entities that participate in that market. The act requires the Commodities Futures Trading Commission (“CFTC”), the U.S. Securities and Exchange Commission (“SEC”) and other regulators to implement the act’s provisions. Some rules and regulations under the act have been finalized but additional rules and regulations have yet to be adopted. While the effect on the Company of existing and future rules and regulations under the act cannot be determined at this time, it is possible that the rules and regulations under the act 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. Increased costs may arise from any new margin, clearing and trade-execution requirements imposed upon individual transactions, as well as from new capital, reporting, recordkeeping, compliance and business conduct requirements imposed upon our counterparties to the extent those costs are passed through to us. Position limits may be imposed that could further limit our ability to hedge risks. To the extent new rules and regulations require more collateral or margin for individual transactions, our available liquidity may be adversely affected. Additionally, new rules and regulations may restrict our ability to monetize or restructure existing derivative contracts and require us to restructure portions of our energy marketing and trading business. Accordingly, our business and operating results may be adversely affected if, as a result of the act and the rules and regulations promulgated under the act, we are forced to reduce or modify our current use of derivatives.

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

When the Company enters into fixed-price sales contracts with customers, it typically enters 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 one or more of our suppliers under such contracts could cause us to purchase those commodities at higher prices, which would have a negative impact on our operating results.

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

During Fiscal 2013, AmeriGas Propane purchased over 90% of its propane needs from twenty 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 areas, a single supplier may provide more than 50% of AmeriGas Propane’s propane requirements. Disruptions in supply in these areas could also have an adverse impact on our earnings. Our international businesses are similarly dependent upon their suppliers. 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.

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Changes in commodity market prices may have a significant negative effect on our liquidity.

Depending on the terms of our contracts with suppliers and some large customers, as well as our use of financial instruments to reduce volatility in the cost of LPG, electricity or natural gas, and for all of our contracts with the New York Mercantile Exchange, changes in the market price of LPG, electricity and natural gas can create margin payment obligations for the Company or one of its subsidiaries and expose us to significant liquidity risks.

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 propane businesses compete for customers against suppliers of electricity, fuel oil and natural gas. Electricity is a major competitor of propane and, except in France, is currently more expensive than propane for space heating, water heating and cooking. The convenience of electricity makes it an attractive energy source for consumers. Fuel oil is also a major competitor of propane and is generally more expensive than propane. 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. Our customers generally have an incentive to switch to fuel oil only if fuel oil becomes significantly less expensive than propane. Except for certain industrial and commercial applications, propane 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 propane. 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 propane. As long as natural gas remains a less expensive energy source than propane, our propane business will lose customers in each region into which natural gas distribution systems are expanded. In France, the state-owned natural gas monopoly, Gaz de France, has in the past extended France’s natural gas grid. 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.

Our natural gas businesses compete primarily with electricity and fuel 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 fuel utilization equipment. There can be no assurance that our natural gas revenues will not be adversely affected by this competition.

Our ability to increase revenues is adversely affected by the decline of the retail LPG industry.

The retail LPG distribution industry in the U.S. and each of the European countries in which we operate is mature and has been declining over the past several years in the United States, with no or modest growth in total demand foreseen. Given this forecast, 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 domestic ACE and National Accounts programs in the U.S., 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 would have an adverse effect on our business, financial condition and results of operations.

Our ability to grow our businesses will be adversely affected if we are not successful in making acquisitions or integrating the acquisitions we have made.

One of our strategies is to grow through acquisitions in the United States and in international markets. We may choose to finance future acquisitions with debt, equity, cash or a combination of the three. We can give no assurances that we will find attractive acquisition candidates in the future, that we will be able to acquire such candidates on economically acceptable terms, that we will be able to finance acquisitions on economically acceptable terms, that any acquisitions will not be dilutive to earnings or that any additional debt incurred to finance an acquisition will not affect our ability to pay dividends.

In addition, the restructuring of the energy markets in the United States and internationally, including the privatization of government-owned utilities and the sale of utility-owned assets, is creating opportunities for, and competition from, well-capitalized competitors, which may affect our ability to achieve our business strategy.

To the extent we are successful in making acquisitions, such acquisitions involve a number of risks. These risks include, but are not limited to, the assumption of material liabilities, the diversion of management’s attention from the management of daily operations to the integration of operations, difficulties in the assimilation and retention of employees and difficulties in the assimilation of different cultures and practices and internal controls, as well as in the assimilation of broad and geographically

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dispersed personnel and operations. The failure to successfully integrate acquisitions could have an adverse effect on our business, financial condition and results of operations.

Expanding our midstream asset business by constructing new facilities subjects us to risks.

One of the ways we seek to grow our midstream asset business is by constructing new pipelines and gathering systems, expanding our LNG facility and improving our gas storage facilities. These construction projects involve numerous regulatory, environmental, political and legal uncertainties beyond our control and require the expenditure of significant amounts of capital. These projects may not be completed on schedule, or at all, or at the anticipated costs. Moreover, our revenues may not increase immediately upon the expenditure of funds on a particular project. We may construct facilities to capture anticipated future growth in production and demand in an area in which anticipated growth and demand does not materialize. As a result, there is the risk that new and expanded facilities may not be able to attract enough customers to achieve our expected investment returns, which could have a material adverse effect on our business, financial condition and results of operations.

Our need to comply with comprehensive, complex, and sometimes unpredictable government regulations may increase our costs and limit our revenue growth, which may result in reduced earnings.

While we generally refer to our Gas Utility and Electric Utility segments as our “regulated segments,” there are many governmental regulations that have an impact on our businesses. Existing statutes and regulations may be revised or reinterpreted and new laws and regulations may be adopted or become applicable to the Company that may affect our businesses in ways that we cannot predict.

Regulators may not allow timely recovery of costs for UGI Utilities and its Subsidiaries in the future, which may adversely affect our results of operations.

In our Gas Utility and Electric Utility segments, our distribution operations are subject to regulation by the PUC. The PUC, among other things, approves the rates that UGI Utilities and its subsidiaries, PNG and CPG, may charge their utility customers, thus impacting the returns that UGI Utilities and its subsidiaries may earn on the assets that are dedicated to those operations. We expect that UGI Utilities will periodically file requests with the PUC to increase base rates that each company charges customers. If UGI Utilities is required in a rate proceeding to reduce the rates it charges its utility customers, or if UGI Utilities is unable to obtain approval for timely rate increases from the PUC, particularly when necessary to cover increased costs, UGI Utilities’ revenue growth will be limited and earnings may decrease.

We are subject to operating and litigation risks that may not be covered by insurance.

Our business operations in the U.S. and other countries are subject to all of the operating hazards and risks normally incidental to the handling, storage and distribution of combustible products, such as LPG, propane 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, we are sometimes a defendant in legal proceedings and litigation arising in the ordinary course of business. There can be no assurance that our insurance will be adequate to protect us from all material expenses related to pending and future claims or that such levels of insurance will be available in the future at economical prices.

We may be unable to respond effectively to competition, which may adversely affect our operating results.

We 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 enter our markets and, as a result, we may be unable to maintain our revenues or continue to pursue our current business strategy.

Our net income and earnings will decrease if we are required to incur additional costs to comply with new governmental safety, health, transportation, tax and environmental regulations.

We are subject to extensive and changing international, federal, state and local safety, health, transportation, tax and environmental laws and regulations governing the storage, distribution and transportation of our energy products.

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. Failure to obtain or comply with these permits or applicable laws could result in civil and criminal fines or the cessation of the operations in violation.

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Governmental regulations and policies in the United States and Europe may provide for subsidies or incentives to customers who use alternative fuels instead of carbon fuels. 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. Costs we incur to remediate sites outside of Pennsylvania cannot currently be recovered in PUC 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 the third-party claims; or	
		
•	the insolvency of other responsible parties at the sites at which we are involved.	

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

Our operations, capital expenditures and financial results may be affected by regulatory changes and/or market responses to global climate change.
There continues to be concern, both nationally and internationally, about climate change and the contribution of greenhouse gas (“GHG”) emissions, most notably carbon dioxide, to global warming. While some states have adopted laws and regulations regulating the emission of GHGs for some industry sectors, there is currently no federal or regional legislation mandating the reduction of GHG emissions in the United States. Although Congress has not enacted federal climate change legislation, the EPA has begun adopting and implementing regulations to restrict emissions of GHGs from motor vehicles and certain large stationary sources, and to require reporting of GHG emissions by certain regulated facilities on an annual basis. For the most part, our facilities are not currently subject to these regulations, but the potential increased costs of regulatory compliance and mandatory reporting by our customers and suppliers could have an effect on our operations or financial condition. The adoption of additional federal or state climate change legislation or regulatory programs to reduce emissions of GHGs could require us or our suppliers to incur increased capital and operating costs, with resulting impact on product price and demand. The impact of new legislation and regulations will depend on a number of factors, including (i) which industry sectors would be impacted, (ii) the timing of required compliance, (iii) the overall GHG emissions cap level, (iv) the allocation of emission allowances to specific sources, and (v) the costs and opportunities associated with compliance. At this time, we cannot predict the effect that climate change regulation may have on our business, financial condition or operations in the future.

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

We currently operate LPG distribution businesses in Europe through our subsidiaries and we continue to explore the expansion of our international businesses. As a result, we face risks in doing 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;	
		
•	tariffs and other trade barriers;	
		
•	difficulties in enforcing contractual rights;	
		
•	longer payment cycles;	
		
•	local political and economic conditions, including the current financial downturn in the euro zone;	
		
•	potentially adverse tax consequences, including restrictions on repatriating earnings and the threat of “double taxation”;	
		
•	fluctuations in currency exchange rates, which can affect demand and increase our costs;	
		
•	internal control and risk management practices and policies;	
		
•	regulatory requirements and changes in regulatory requirements, including Norwegian, Swiss and EU 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; and	
		
•	new and inconsistently enforced LPG industry regulatory requirements, which can have an adverse effect on our competitive position.	

In addition, there is new proposed tax legislation in France that would limit Antargaz’ ability to deduct interest expense for tax purposes under certain financing structures. If adopted, the proposed legislation would be applied retroactively to tax years ending

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on or after September 25, 2013. If the proposed tax legislation is adopted as currently drafted and our current financing structure at Antargaz remains unchanged, the amount of income tax benefits that Antargaz would receive with respect to certain financing arrangements will decrease. As a result, the proposed tax legislation could have an adverse effect on our net income.

Unforeseen difficulties with the operation of our information systems could adversely affect our internal controls and our businesses.

We contracted with third-party consultants to assist us with the design and implementation of an information system that supports the Partnership’s Order-to-Cash business processes. The efficient execution of the Partnership’s business is dependent upon the proper functioning of its internal systems. Any significant failure or malfunction of the Partnership’s or our other business units’ information systems may result in disruptions of their operations. Our results of operations could be adversely affected if we encounter unforeseen problems with respect to the operation of our information systems.
ITEM 1B. UNRESOLVED STAFF COMMENTS

None.
ITEM 3. LEGAL PROCEEDINGS

With the exception of those matters set forth in Note 16 to Consolidated Financial Statements included in Item 8 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.
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.

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PART II:

ITEM 5.	MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES	
Market Information

Our Common Stock is traded on the New York Stock Exchange under the symbol “UGI.” The following table sets forth the high and low sales prices for the Common Stock on the New York Stock Exchange Composite Transactions tape as reported in The Wall Street Journal for each full quarterly period within the two most recent fiscal years:

									
2013 Fiscal Year	 	High	 	Low	
4th Quarter	 	$	43.16		 	$	38.02		
3rd Quarter	 	42.11		 	36.43		
2nd Quarter	 	38.46		 	32.90		
1st Quarter	 	33.58		 	30.15		

	
									
2012 Fiscal Year	 	High	 	Low	
4th Quarter	 	$	31.87		 	$	29.52		
3rd Quarter	 	29.77		 	26.30		
2nd Quarter	 	30.25		 	26.01		
1st Quarter	 	30.22		 	24.07		

Dividends

Quarterly dividends on our Common Stock were paid in Fiscal 2013 and Fiscal 2012 as follows:

					
2013 Fiscal Year	 	Amount	
4th Quarter	 	$	0.2825		
3rd Quarter	 	0.27		
2nd Quarter	 	0.27		
1st Quarter	 	0.27		

	
					
2012 Fiscal Year	 	Amount	
4th Quarter	 	$	0.27		
3rd Quarter	 	0.26		
2nd Quarter	 	0.26		
1st Quarter	 	0.26		

Record Holders

On November 29, 2013, UGI had 6,839 holders of record of Common Stock.

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ITEM 6.	SELECTED FINANCIAL DATA	

																					
 	 	Year Ended September 30,	
(Dollars in millions, except per share amounts)	 	2013	 	2012 (a)	 	2011 (a)	 	2010 (b)	 	2009 (b)	
FOR THE PERIOD:	 	 	 	 	 	 	 	 	 	 	
Income statement data:	 	 	 	 	 	 	 	 	 	 	
Revenues	 	$	7,194.7		 	$	6,521.3		 	$	6,090.9		 	$	5,591.1		 	$	5,739.3		
Net income	 	$	427.6		 	$	197.7		 	$	320.0		 	$	346.6		 	$	385.5		
(Deduct net income) add net loss attributable to noncontrolling interests, principally in AmeriGas Partners	 	(149.5	)	 	12.5		 	(74.6	)	 	(94.8	)	 	(124.5	)	
Net income attributable to UGI Corporation	 	$	278.1		 	$	210.2		 	$	245.4		 	$	251.8		 	$	261.0		
Earnings per common share attributable to UGI stockholders:	 	 	 	 	 	 	 	 	 	 	
Basic	 	$	2.44		 	$	1.87		 	$	2.20		 	$	2.30		 	$	2.41		
Diluted	 	$	2.41		 	$	1.85		 	$	2.17		 	$	2.28		 	$	2.39		
Cash dividends declared per common share	 	$	1.105		 	$	1.06		 	$	1.02		 	$	0.90		 	$	0.785		
AT PERIOD END:	 	 	 	 	 	 	 	 	 	 	
Balance sheet data:	 	 	 	 	 	 	 	 	 	 	
Total assets	 	$	10,008.8		 	$	9,676.9		 	$	6,660.9		 	$	6,373.6		 	$	6,041.9		
Capitalization:	 	 	 	 	 	 	 	 	 	 	
Debt:	 	 	 	 	 	 	 	 	 	 	
Bank loans — UGI Utilities	 	$	17.5		 	$	9.2		 	$	—		 	$	17.0		 	$	154.0		
Bank loans — AmeriGas Propane	 	116.9		 	49.9		 	95.5		 	91.0		 	—		
Bank loans — UGI International	 	6.5		 	21.0		 	18.9		 	92.4		 	9.1		
Bank loans — other	 	87.0		 	85.0		 	24.3		 	—		 	—		
Long-term debt (including current maturities):	 	 	 	 	 	 	 	 	 	 	
AmeriGas Propane	 	2,300.1		 	2,328.0		 	933.5		 	791.4		 	865.6		
UGI International	 	654.4		 	573.9		 	571.3		 	561.1		 	613.8		
UGI Utilities	 	642.0		 	600.0		 	640.0		 	640.0		 	640.0		
Other	 	12.9		 	12.4		 	12.9		 	13.3		 	13.7		
Total debt	 	3,837.3		 	3,679.4		 	2,296.4		 	2,206.2		 	2,296.2		
UGI Corporation stockholders’ equity	 	2,492.5		 	2,229.8		 	1,973.5		 	1,824.0		 	1,567.3		
Noncontrolling interests, principally in AmeriGas Partners	 	1,055.4		 	1,085.6		 	213.0		 	237.4		 	225.6		
Total capitalization	 	$	7,385.2		 	$	6,994.8		 	$	4,482.9		 	$	4,267.6		 	$	4,089.1		
Ratio of capitalization:	 	 	 	 	 	 	 	 	 	 	
Total debt	 	52.0	%	 	52.6	%	 	51.2	%	 	51.7	%	 	56.2	%	
UGI Corporation stockholders’ equity	 	33.7	%	 	31.9	%	 	44.0	%	 	42.7	%	 	38.3	%	
Noncontrolling interests, principally in AmeriGas Partners	 	14.3	%	 	15.5	%	 	4.8	%	 	5.6	%	 	5.5	%	
 	 	100.0	%	 	100.0	%	 	100.0	%	 	100.0	%	 	100.0	%	
(a) Reflects revisions to correct an error in accounting for commodity derivative instruments at Midstream & Marketing and certain other immaterial errors. See Note 3, “Revisions and Restatements of Consolidated Financial Statements,” of Notes to Consolidated Financial Statements included elsewhere in this Report on Form 10-K.
(b) The Selected Financial Data for the years ended September 30, 2010 and 2009 have been revised to correct an error in the accounting for commodity derivative instruments at Midstream & Marketing and certain other immaterial corrections. For general information on the nature of the errors resulting in the corrections, see Note 3 to Consolidated Financial Statements included elsewhere in this Report on Form 10-K.

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ITEM 7.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	
Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) discusses our results of operations and our financial condition. MD&A should be read in conjunction with our Items 1 & 2, “Business and Properties,” our Item 1A, “Risk Factors,” and our Consolidated Financial Statements in Item 8 below including “Segment Information” included in Note 22 to Consolidated Financial Statements.
Revisions and Restatements of Previously Issued Financial Statements

Historically, the Company used what is commonly referred to as critical terms match to qualify certain of its derivative instruments used in commodity energy transactions by Midstream & Marketing’s reportable segments (comprising Energy Services and Electric Generation) as cash flow hedges under accounting principles generally accepted in the United States of America (“GAAP”). During the preparation of the Fiscal 2013 consolidated financial statements, management concluded that it had incorrectly accounted for these derivative instruments as cash flow hedges. Management had incorrectly applied the hedge accounting criteria when designating these derivative instruments as cash flow hedges largely because its intended plans for supply fulfilment at the time of the hedge inception were not met when we later chose to optimize supply for those hedged transactions. As a result, changes in the fair values of these derivative instruments for which the associated forecasted transaction had not yet occurred have been reported as a component of cost of sales or revenues in the Consolidated Statements of Income rather than in other comprehensive income. Management has discontinued the use of hedge accounting for substantially all of Midstream & Marketing’s commodity derivative instruments and has reported changes in the fair values of unsettled commodity derivative instruments, and gains and losses on settled commodity derivative instruments for which the associated forecasted transactions have not yet occurred, in net income in the consolidated financial statements included in this Report on Form 10-K.

Although the impact of the error was not material to the Company’s historical annual consolidated financial statements, the Company decided to revise its consolidated financial statements and disclosures to correct this error in accounting for Fiscal 2012 and Fiscal 2011 and to record certain other immaterial corrections. Because management concluded that the error in accounting for derivative instruments used in commodity derivative transactions by Midstream & Marketing’s reportable segments and the other corrections were material to its consolidated financial statements for the fiscal quarters ended March 31, 2013, June 30, 2012 and December 31, 2011, it is restating the Company’s financial statements for those periods while the Company’s consolidated financial statements for other quarterly periods within Fiscal 2013 and Fiscal 2012 have been revised. As a result of the revisions and restatements, changes in the fair values of unsettled derivatives and gains and losses on settled derivative instruments not associated with current period transactions are recorded in revenues or cost of sales in the Consolidated Statements of Income. This change has no effect on the Company’s financial condition, day-to-day operations, cash flow or liquidity. For further information on the effects of the revisions and restatements, see Note 3 and Note 21 to the Consolidated Financial Statements.

The following MD&A gives effect to the revisions to the Fiscal 2012 and Fiscal 2011 Consolidated Financial Statements as discussed in Note 3 to the Consolidated Financial Statements.

Executive Overview

We recorded net income attributable to UGI Corporation of $278.1 million , equal to $2.41 per diluted share, for Fiscal 2013 compared to $210.2 million , equal to $1.85 per diluted share, for Fiscal 2012. Operating results in Fiscal 2013 were higher at each of our businesses due in large part to winter heating season and early spring temperatures that were closer to normal compared to temperatures that were substantially warmer than normal in Fiscal 2012. The improved Fiscal 2013 results also reflect the full-year operations of Heritage Propane, which was acquired on January 12, 2012, the full-year benefits from the integration of the Shell LPG businesses acquired in early Fiscal 2012 at UGI International, and the completion of the Heritage Propane integration during Fiscal 2013 (see Note 5 to Consolidated Financial Statements for further information on the Heritage Propane and Shell acquisitions).

At AmeriGas Propane, temperatures based upon heating degree days were approximately 4.9% warmer than normal but approximately 16% colder than the prior year. The significantly colder weather, the full-year operations of Heritage Propane and the benefits of lower propane supply prices resulted in a $32.1 million increase in net income attributable to UGI Corporation from AmeriGas Propane. At UGI International, significantly improved results at Antargaz, the result of a return to near normal weather and higher unit margins, and improved results at Flaga and AvantiGas due in large part to colder weather and lower net operating costs, resulted in an $17.5 million year-over-year increase in net income attributable to UGI Corporation. Fiscal 2013 Gas Utility results were also significantly higher than the prior year reflecting the effects of colder Fiscal 2013 weather and, to a much lesser extent, customer growth principally due to customer conversions from oil. Midstream & Marketing's Energy Services business also benefited in Fiscal 2013 from the effects of colder weather on natural gas marketing and midstream asset activities,

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while Midstream & Marketing's Electric Generation business benefited from higher electricity volumes, increased electricity spot market prices and higher capacity revenues. The improved Electric Generation volumes in Fiscal 2013 reflect the full availability of our Hunlock Creek electricity generating station and greater production from the Conemaugh electricity generating station in which we own a 5.97% interest.
We believe that each of our business units has sufficient liquidity in the forms of revolving credit facilities, and with respect to Energy Services also an accounts receivable securitization facility, to fund business operations in Fiscal 2014 (see Financial Condition and Liquidity below).
Looking ahead, our results in Fiscal 2014 will be influenced by a number of factors including heating-season temperatures, the level and volatility of commodity prices for natural gas, LPG, electricity and oil, and economic conditions in the U.S. and Europe. We have made substantial progress on growth initiatives that will fuel earnings growth in the future. The integration efforts at AmeriGas Propane and UGI International are complete and we recently expanded our presence in Poland with the September 2013 acquisition of BP’s LPG distribution business in that country. Acquisition activity in Europe over the last several years makes us an attractive supply partner and creates new business opportunities. At Gas Utility, we expect to experience continued strong growth from conversions from oil as a result of sustained low natural gas prices. We have also made excellent progress on Midstream & Marketing’s Marcellus Shale initiatives in Pennsylvania including the Auburn II pipeline extension project, our storage compressor station project and our Fiscal 2013 acquisition of working interests in natural gas wells. To the extent normal weather patterns have returned, we hope to reap the benefits from these growth initiatives in Fiscal 2014 and beyond.

Non-GAAP Financial Measures - Adjusted Net Income Attributable to UGI and Adjusted Earnings Per Diluted Share

UGI management uses “adjusted net income attributable to UGI” and “adjusted earnings per diluted share,” both of which are non-GAAP financial measures, when evaluating UGI’s overall performance. Adjusted net income attributable to UGI is net income attributable to UGI excluding changes in the fair values of Midstream & Marketing’s unsettled commodity derivative instruments as well as gains and losses on settled commodity derivative instruments not associated with current period transactions. UGI accounts for these commodity derivative instruments at fair value with changes in fair value included in earnings as a component of cost of sales or revenues on the Consolidated Statements of Income. Volatility in net income at UGI can occur as a result of changes in the fair values of unsettled commodity derivative instruments as well as timing differences between the settlement of commodity derivative instruments and the income statement impact of the purchase or sale of the associated commodity. 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. Management believes that these non-GAAP measures provide meaningful information about UGI’s performance because they eliminate the impact of changes in the fair values of Midstream & Marketing’s unsettled commodity derivative instruments as well as gains and losses on settled commodity derivative instruments not associated with current period transactions that are required, under GAAP, to be recorded in current period earnings.
The following table reconciles consolidated net income attributable to UGI Corporation, the most directly comparable GAAP measure, to adjusted net income attributable to UGI, and reconciles diluted earnings per share, the most comparable GAAP measure, to adjusted diluted earnings per share, to reflect adjustments relating to changes in the fair values of Midstream & Marketing’s commodity derivative instruments and certain gains and losses on settled commodity derivative instruments:

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(Millions of dollars, except per share)	 	 	 	 	 	
 	2013	 	2012	 	2011	
Adjusted net income attributable to UGI Corporation:	 	 	 	 	 	
Net income attributable to UGI Corporation	$	278.1		 	$	210.2		 	$	245.4		
Adjust: Net unrealized (gains) losses on Midstream & Marketing’s unsettled commodity derivative instruments	(0.1)	 	(10.1)	 	(11.4)	
Adjust: Net (gains) losses on certain Midstream & Marketing settled commodity derivative instruments	(4.2	)	 	1.2		 	(6.0	)	
Adjusted net income attributable to UGI Corporation	$	273.8		 	$	201.3		 	$	228.0		
 	 	 	 	 	 	
Adjusted diluted earnings per share:	 	 	 	 	 	
UGI Corporation earnings per share - diluted	$	2.41		 	$	1.85		 	$	2.17		
Adjust: Net unrealized (gains) losses on Midstream & Marketing’s unsettled commodity derivative instruments	0.00	 	(0.09)	 	(0.10)	
Adjust: Net (gains) losses on certain Midstream & Marketing settled commodity derivative instruments	(0.04)	 	0.01	 	(0.05)	
Adjusted diluted earnings per share	$	2.37		 	$	1.77		 	$	2.02		

Results of Operations
The following analyses compare the Company’s results of operations for (1) Fiscal 2013 with Fiscal 2012 and (2) Fiscal 2012 with the year ended September 30, 2011 (“Fiscal 2011 ”).
Fiscal 2013 Compared with Fiscal 2012
Consolidated Results
Net Income Attributable to UGI Corporation by Business Unit:

	
																						
 	 	2013	 	2012	 	Variance - Favorable
(Unfavorable)	
(Dollars in millions)	 	Amount	 	% of
Total	 	Amount	 	% of
Total	 	Amount	 	% Change	
AmeriGas Propane	 	$	47.5		 	17.1	%	 	$	15.4		 	7.3	%	 	$	32.1		 	208.4	%	
UGI International	 	82.7		 	29.7	%	 	65.2		 	31.0	%	 	17.5		 	26.8	%	
Gas Utility	 	94.3		 	33.9	%	 	81.6		 	38.8	%	 	12.7		 	15.6	%	
Midstream & Marketing	 	52.5		 	18.9	%	 	37.7		 	17.9	%	 	14.8		 	39.3	%	
Corporate & Other (a)	 	1.1		 	0.4	%	 	10.3		 	5.0	%	 	(9.2	)	 	N.M.		
Net income attributable to UGI Corporation	 	$	278.1		 	100.0	%	 	$	210.2		 	100.0	%	 	$	67.9		 	32.3	%	

(a) Includes changes in the fair values of Midstream & Marketing’s unsettled commodity derivative instruments and gains and
losses on settled commodity derivative instruments not associated with current period transactions of $4.3 million and $8.9 million in Fiscal 2013 and Fiscal 2012, respectively.
N.M. — Variance is not meaningful.
Highlights — Fiscal 2013 versus Fiscal 2012
		
•	Net income increased significantly in Fiscal 2013 due primarily to a return to more normal winter weather patterns and cooler spring temperatures.	

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•	Fiscal 2013 results include the full-year effects of AmeriGas Partners’ January 2012 acquisition of Heritage Propane and the benefits from the integrations of Heritage Propane and Shell’s LPG distribution businesses in the United Kingdom, Belgium, the Netherlands, Luxembourg, Denmark, Finland, Norway and Sweden acquired in October 2011 (the “Shell Transaction”).	
		
•	Fiscal 2013 results include Heritage Propane transition expenses of $26.5 million (after-tax impact to UGI of $(4.4) million equal to $(0.04) per diluted share). Fiscal 2012 results include combined Heritage Propane and Shell pre-tax acquisition and transition expenses totaling approximately $53 million (after-tax impact to UGI of $(13.3) million equal to $(0.12) per diluted share).	
		
•	Fiscal 2013 LPG unit margins at AmeriGas Propane and UGI International were higher principally reflecting the benefit of lower average LPG commodity costs.	
		
•	Midstream & Marketing’s Energy Services business benefited from the the colder weather including higher income from winter peaking and capacity management activities. Additionally, Midstream & Marketing’s Electric Generation business results improved on higher generation volumes and higher average unit margins.	
		
•	Gas Utility continued to experience record numbers of customer conversions to natural gas from alternative fuels.	
		
•	AmeriGas Propane Fiscal 2012 results include a $2.2 million after-tax loss ($0.02 per diluted share) on extinguishments of debt.	

																
AmeriGas Propane	 	2013	 	2012	 	Increase	
(Dollars in millions)	 	 	 	 	 	 	 	 	
Revenues	 	$	3,168.8		 	$	2,921.5		 	$	247.3		 	8.5	%	
Total margin (a)	 	$	1,511.6		 	$	1,199.1		 	$	312.5		 	26.1	%	
Operating and administrative expenses	 	$	945.1		 	$	888.4		 	$	56.7		 	6.4	%	
Partnership EBITDA (b)	 	$	596.5		 	$	322.1		 	$	274.4		 	85.2	%	
Operating income	 	$	394.4		 	$	168.7		 	$	225.7		 	133.8	%	
Retail gallons sold (millions)	 	1,245.2		 	1,017.5		 	227.7		 	22.4	%	
Degree days – % (warmer) than normal (c)	 	(4.9	)%	 	(18.6	)%	 	—		 	—		

(a)	Total margin represents total revenues less total cost of sales.	
		
(b)	Partnership EBITDA (earnings before interest expense, income taxes and depreciation and amortization) should not be considered as an alternative to net income (as an indicator of operating performance) and is not a measure of performance or financial condition under accounting principles generally accepted in the United States of America (“GAAP”). Management uses Partnership EBITDA as the primary measure of segment profitability for the AmeriGas Propane segment (see Note 22 to Consolidated Financial Statements). Partnership EBITDA for Fiscal 2012 includes pre-tax losses of $13.3 million associated with extinguishments of debt. Partnership EBITDA and operating income for Fiscal 2013 and Fiscal 2012 also includes acquisition and transition expenses of $26.5 million and $46.2 million, respectively, associated with Heritage Propane.	
		
(c)	Deviation from average heating degree days for the 30-year period 1971-2000 based upon national weather statistics provided by the National Oceanic and Atmospheric Administration (“NOAA”) for 335 airports in the United States, excluding Alaska.	

Results for Fiscal 2013 reflect the full-year operations of Heritage Propane acquired in January 2012. Based upon heating degree-day data, temperatures in the Partnership's service territories during Fiscal 2013 averaged approximately 4.9% warmer than normal but 16.2% colder than in Fiscal 2012. Retail gallons sold increased 227.7 million gallons (22.4%) principally reflecting the full-year impact of the Heritage Propane operations and the colder Fiscal 2013 weather.

Retail propane revenues increased $241.6 million during Fiscal 2013 reflecting the higher retail volumes sold ($567.6 million) partially offset by a decline in average retail selling prices ($326.0 million) which was the result of lower propane product costs. Wholesale propane revenues declined $33.7 million principally reflecting lower average wholesale propane selling prices ($28.6 million) and lower wholesale volumes sold ($5.1 million). Average daily wholesale propane commodity prices during Fiscal 2013 at Mont Belvieu, Texas, one of the major supply points in the U.S., were approximately 19% lower than such prices during Fiscal 2012. Total revenues from fee income and other ancillary sales and services in Fiscal 2013 were $39.4 million higher than in Fiscal 2012 principally reflecting the full-year effects of Heritage Propane. Total propane cost of sales decreased $76.5 million principally reflecting the effects of the previously mentioned lower propane commodity prices on retail propane cost of sales ($376.3 million) and lower wholesale propane cost of sales ($36.8 million) substantially offset by the effects of the greater retail

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volumes sold ($336.6 million). Cost of sales associated with ancillary sales and services increased $11.3 million principally reflecting the full-year effects of Heritage Propane.
Total margin increased $312.5 million in Fiscal 2013 principally reflecting higher total propane margin ($284.4 million) and greater total margin from fee income and ancillary sales and services ($28.1 million). These increases principally reflect the incremental full-year effects of Heritage Propane, the colder Fiscal 2013 weather and, with respect to total propane margin, slightly higher average unit margins reflecting in large part the lower propane product costs.
Partnership EBITDA in Fiscal 2013 increased $274.4 million principally reflecting the higher total margin ( $312.5 million ) and the absence of the $13.3 million loss on extinguishments of debt recorded in Fiscal 2012 partially offset by higher Partnership operating and administrative expenses ($56.7 million) primarily attributable to the full-year effects of Heritage Propane operations. Operating and administrative expenses in Fiscal 2013 include $26.5 million of transition expenses associated with the integration of Heritage Propane while operating and administrative expenses in Fiscal 2012 include Heritage Propane acquisition and transition-related expenses of $46.2 million. AmeriGas Propane operating income increased $225.7 million in Fiscal 2013 principally reflecting the higher total margin ( $312.5 million ) partially offset by the previously mentioned greater operating and administrative expenses ($56.7 million) and increased depreciation and amortization expense ($37.8 million) reflecting in large part the full-year effects of Heritage Propane.

	
																
UGI International	 	2013	 	2012	 	Increase	
(Dollars in millions)	 	 	 	 	 	 	 	 	
Revenues	 	$	2,179.2		 	$	1,946.1		 	$	233.1		 	12.0	%	
Total margin (a)	 	$	680.8		 	$	620.3		 	$	60.5		 	9.8	%	
Operating and administrative expenses	 	$	454.4		 	$	435.9		 	$	18.5		 	4.2	%	
Operating income	 	$	147.0		 	$	111.9		 	$	35.1		 	31.4	%	
Income before income taxes	 	$	116.2		 	$	80.7		 	$	35.5		 	44.0	%	
 	 	 	 	 	 	 	 	 	
Retail gallons sold (millions) (b)	 	592.4		 	576.5		 	15.9		 	2.8	%	
Antargaz degree days – % colder (warmer) than normal (c)	 	3.7	%	 	(7.1	)%	 	—		 	—		
Flaga degree days – % colder (warmer) than normal (c)	 	0.9	%	 	(6.4	)%	 	—		 	—		

(a)	Total margin represents total revenues less total cost of sales.	
		
(b)	Excludes retail gallons from operations in China.	
		
(c)	Deviation from average heating degree days for the 30-year period 1981-2010 at locations in our Antargaz and Flaga service territories.	

Based upon heating degree day data, temperatures in our European LPG operations in Fiscal 2013 were colder than normal and colder than the prior year. Although Fiscal 2013 wholesale commodity prices for propane and butane based upon index prices in northwest Europe averaged only slightly lower than in Fiscal 2012, such LPG prices generally declined during the Fiscal 2013 peak heating season while LPG prices generally increased during the Fiscal 2012 peak heating season. Retail LPG gallons sold in Fiscal 2013 were higher than Fiscal 2012 principally reflecting the effects of significantly colder weather across all of our European operations partially offset by the effects of a decline in economic activity mainly on commercial and industrial customers in certain of our European markets.
Our UGI International base-currency results are translated into U.S. dollars based upon exchange rates experienced during each of the reporting periods. The functional currency of a significant portion of our UGI International results is the euro. During Fiscal 2013 and Fiscal 2012, the average unweighted translation rate was approximately $1.31 and $1.30 per euro, respectively. The difference in rates did not have a material impact on net income attributable to UGI.
UGI International revenues increased $233.1 million principally reflecting the effects on LPG revenues of greater low-margin wholesale sales, the increase in LPG retail volumes sold and to a lesser extent greater average retail prices. The increase in revenues also reflects higher revenues from natural gas marketing activities in France. Cost of sales increased to $1,498.4 million in Fiscal 2013 from $1,325.8 million in Fiscal 2012 principally reflecting the effects of the greater wholesale and retail LPG volumes sold. The higher UGI International cost of sales also reflects increased cost of sales associated with natural gas marketing activities in France.

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Total UGI International margin increased $60.5 million during Fiscal 2013 principally reflecting higher retail LPG unit margins and volumes at Antargaz and, to a much lesser extent, greater total LPG margin at AvantiGas and Flaga.
UGI International operating income and income before income taxes increased $35.1 million and $35.5 million , respectively, principally reflecting the higher total margin ( $60.5 million ) partially offset by modestly higher operating and administrative expenses. Operating and administrative expenses in Fiscal 2013 principally reflect higher delivery, selling, and incentive compensation and benefits costs principally at Antargaz. Fiscal 2013 UGI International operating and administrative costs include approximately $4.0 million of acquisition and transition costs associated with Flaga’s September 2013 acquisition of BP’s LPG distribution business in Poland, while Fiscal 2012 UGI International operating and administrative expenses include acquisition and transition costs of approximately $7.0 million associated with the LPG businesses acquired from Shell in October 2011. UGI International net income in Fiscal 2013 as a percentage of UGI International earnings before income taxes was lower than the prior year as the Fiscal 2012 UGI International effective income tax rate reflects, in part, the effects of a greater proportion of UGI International tax benefits relative to pre-tax income and the realization of $4.7 million of previously unrecognized foreign tax credits.

																
Gas Utility	 	2013	 	2012	 	Increase	
(Dollars in millions)	 	 	 	 	 	 	 	 	
Revenues	 	$	839.0		 	$	785.4		 	$	53.6		 	6.8	%	
Total margin (a)	 	$	431.8		 	$	382.9		 	$	48.9		 	12.8	%	
Operating and administrative expenses	 	$	176.2		 	$	156.0		 	$	20.2		 	12.9	%	
Operating income	 	$	196.5		 	$	174.1		 	$	22.4		 	12.9	%	
Income before income taxes	 	$	159.1		 	$	134.0		 	$	25.1		 	18.7	%	
System throughput – billions of cubic feet (“bcf”) -	 	 	 	 	 	 	 	 	
     Core market	 	70.6		 	59.2		 	11.4		 	19.3	%	
     Total	 	192.1		 	177.6		 	14.5		 	8.2	%	
Degree days – % (warmer) than normal (b)	 	(0.5	)%	 	(16.3	)%	 	—		 	—		

(a)	Total margin represents total revenues less total cost of sales.	
		
(b)	Deviation from average heating degree days for the 15-year period 1995-2009 based upon weather statistics provided by the National Oceanic and Atmospheric Administration (“NOAA”) for airports located within Gas Utility’s service territory.	

Temperatures in the Gas Utility service territory in Fiscal 2013 based upon heating degree days were 0.5% warmer than normal but 18.2% colder than Fiscal 2012. Total distribution system throughput increased principally reflecting significantly higher throughput to core market customers and, to a lesser extent, greater net volumes associated with lower margin firm and interruptible delivery service customers. Gas Utility system throughput to core-market customers was above last year principally reflecting the effects of the significantly colder weather and, to a much lesser extent, customer growth, principally conversions from oil prompted by sustained lower natural gas prices and high oil prices. Gas Utility’s core market customers comprise firm- residential, commercial and industrial (“retail core-market”) customers who purchase their gas from Gas Utility and, to a much lesser extent, residential and small commercial customers who purchase their gas from alternate suppliers.
Gas Utility revenues increased $53.6 million during Fiscal 2013 principally reflecting higher revenues from core market customers ($52.8 million) and higher large firm delivery service revenues ($9.2 million) partially offset by lower off-system sales revenues ($8.6 million). The increase in core market revenues principally reflects the effects of higher retail core-market volumes on PGC revenues ($60.4 million) and greater core market delivery service revenues partially offset by the effects of lower average PGC rates on retail core-market revenues ($50.6 million). Increases or decreases in retail core-market revenues and cost of sales principally result from changes in retail core-market volumes and the level of gas costs collected through the PGC recovery mechanism. Under the PGC recovery mechanism, Gas Utility records the cost of gas associated with sales to retail core-market customers at amounts included in PGC rates. The difference between actual gas costs and the amounts included in rates is deferred on the balance sheet as a regulatory asset or liability and represents amounts to be collected from or refunded to customers in a future period. As a result of this PGC recovery mechanism, increases or decreases in the cost of gas associated with retail core-market customers have no direct effect on retail core-market margin. Gas Utility's cost of gas was $407.2 million in Fiscal 2013 compared with $402.5 million in Fiscal 2012 principally reflecting the effects on cost of sales of the greater retail core-market volumes ($60.4 million) substantially offset by the effects of lower average PGC rates ($50.6 million) and the lower off-system sales.

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Gas Utility total margin increased $48.9 million in Fiscal 2013 principally reflecting higher core market margin ($38.1 million) and higher large firm delivery service total margin ($9.6 million). The higher core market margin reflects the effects of the greater core market volumes.
The increase in Gas Utility operating income during Fiscal 2013 principally reflects the increase in total margin ($48.9 million) partially offset by higher operating and administrative expenses ($20.2 million) including, among other things, higher pension and benefits expenses ($10.7 million), higher uncollectible accounts expenses ($2.8 million) on higher core market volumes, and greater injuries and damages and distribution system expenses ($4.5 million). The greater income before income taxes in Fiscal 2013 reflects the higher operating income ($22.4 million) and slightly lower interest expense on lower long-term debt outstanding.    

																
Midstream & Marketing	 	2013	 	2012	 	Increase	
(Dollars in millions)	 	 	 	 	 	 	 	 	
Revenues (a)	 	$	1,037.6		 	$	853.9		 	$	183.7		 	21.5	%	
Total margin (b)	 	$	164.0		 	$	130.4		 	$	33.6		 	25.8	%	
Operating and administrative expenses	 	$	57.0		 	$	53.9		 	$	3.1		 	5.8	%	
Operating income	 	$	90.0		 	$	64.3		 	$	25.7		 	40.0	%	
Income before income taxes	 	$	86.8		 	$	59.5		 	$	27.3		 	45.9	%	

(a) Amounts are net of intercompany revenues between Midstream & Marketing’s Energy Services and Electric Generation segments.
(b) Total margin represents total revenues less total cost of sales. Amounts exclude pretax gains (losses) from changes in the fair values of Midstream & Marketing’s unsettled commodity derivative instruments and gains (losses) on settled commodity derivative instruments not associated with current period transactions of $7.4 million and $15.1 million in Fiscal 2013 and Fiscal 2012, respectively.

Midstream & Marketing total revenues increased $183.7 million in Fiscal 2013 principally reflecting, among other things, higher natural gas revenues ($145.1 million) from higher wholesale volumes sold and higher average selling prices for natural gas, and higher Electric Generation total revenues ($30.7 million) principally the result of higher electricity volumes and prices.

Midstream & Marketing Fiscal 2013 total margin was $33.6 million higher than Fiscal 2012 reflecting higher Electric Generation total margin ($15.6 million), higher natural gas marketing total margin ($14.2 million), and greater peaking and capacity management total margin ($13.4 million) due to the colder weather and greater natural gas price volatility. These increases were partially offset by lower retail power total margin principally reflecting lower average unit margins. Total margin from natural gas marketing activities in Fiscal 2013 principally reflects the benefits of higher average unit margins. Natural gas marketing average unit margins in Fiscal 2013 benefited from higher-margin incremental sales resulting from the colder weather while average unit margins in Fiscal 2012 were negatively impacted by significantly warmer than normal weather. The greater total margin from Electric Generation principally reflects the impact of higher electricity production from our Hunlock Creek natural gas-fired electricity generating station and greater volumes sold from the Conemaugh generating station. In Fiscal 2012 the Hunlock Creek generating station was running at less than full capacity due to an accident at one unit and flood damage at another unit sustained late in Fiscal 2011. Unit margins from Electric Generation were higher in Fiscal 2013 reflecting higher electricity spot market prices, the effects of lower per unit fuel costs at the Hunlock Creek generating station, and higher capacity revenues from the Hunlock Creek and Conemaugh generating stations.

Midstream & Marketing operating income in Fiscal 2013 was $25.7 million higher than Fiscal 2012 reflecting the previously mentioned increase in total margin ( $33.6 million ) partially offset by higher operating, administrative and depreciation expenses.

The higher operating and administrative expenses ($3.1 million) include greater Energy Services operating expenses ($2.6 million) due in large part to expenses associated with peaking LNG liquefaction and storage facilities and incremental expenses associated with our non-operating working interest in natural gas acreage in the Marcellus Shale region in northern Pennsylvania acquired in January 2013. The increase in depreciation expenses ($4.9 million) principally reflects greater depreciation associated with the full-year operation of LNG facilities and the Hunlock Creek generating station. The increase in Midstream & Marketing income before income taxes reflects the greater operating income and lower interest expense on Energy Services' Credit Agreement and Receivables Facility borrowings.    

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Interest Expense. Our consolidated interest expense was $19.9 million higher in Fiscal 2013 primarily reflecting higher AmeriGas Propane interest expense ($25.0 million), principally full-year interest on debt issued to fund the cash portion of the January 12, 2012, acquisition of Heritage Propane, partially offset by slightly lower UGI Utilities interest expense ($2.9 million) on slightly lower long-term debt outstanding and lower Midstream & Marketing interest expense.
Income Taxes. Income taxes as a percentage of pretax earnings was lower in Fiscal 2013 reflecting, in part, the effects of a higher percentage of income associated with noncontrolling interests not subject to tax, principally AmeriGas Partners, and the realization of previously unrecognized state deferred tax benefits while income taxes in Fiscal 2012 were reduced by $4.7 million as a result of the realization of previously unrecognized foreign tax credits.
Fiscal 2012 Compared with Fiscal 2011
Consolidated Results
Net Income Attributable to UGI Corporation by Business Unit:

	
																						
 	 	2012	 	2011	 	Variance - Favorable
(Unfavorable)	
(Dollars in millions)	 	Amount	 	% of
Total	 	Amount	 	% of
Total	 	Amount	 	% Change	
AmeriGas Propane	 	$	15.4		 	7.3	%	 	$	39.5		 	16.1	%	 	$	(24.1	)	 	(61.0	)%	
UGI International	 	65.2		 	31.0	%	 	41.0		 	16.7	%	 	24.2		 	59.0	 %	
Gas Utility	 	81.6		 	38.8	%	 	99.3		 	40.5	%	 	(17.7	)	 	(17.8	)%	
Midstream & Marketing	 	37.7		 	17.9	%	 	49.2		 	20.0	%	 	(11.5	)	 	(23.4	)%	
Corporate & Other (a)	 	10.3		 	5.0	%	 	16.4		 	6.7	%	 	(6.1	)	 	N.M.		
Net income attributable to UGI Corporation	 	$	210.2		 	100.0	%	 	$	245.4		 	100.0	%	 	$	(35.2	)	 	(14.3	)%	

(a) Includes changes in the fair values of Midstream & Marketing’s unsettled commodity derivative instruments and gains and losses on settled commodity derivative instruments not associated with current period transactions of $8.9 million and $17.4 million in Fiscal 2012 and Fiscal 2011, respectively.
N.M. — Variance is not meaningful.

Highlights — Fiscal 2012 versus Fiscal 2011
		
•	Our U.S. and European business units were adversely affected by significantly warmer heating-season temperatures during Fiscal 2012. The Fiscal 2012 heating season in the U.S. came to an abrupt end in March 2012.	
		
•	Fiscal 2012 consolidated results were impacted by the January 2012 acquisition of Heritage Propane at AmeriGas Propane and the October 2011 Shell Transaction. Results include combined pre-tax acquisition and transition expenses totaling approximately $53 million (after-tax impact of $(13.3) million equal to $(0.12) per diluted share).	
		
•	AmeriGas Propane Fiscal 2012 results include a $2.2 million after-tax loss ($0.02 per diluted share) on extinguishments of debt while Fiscal 2011 results include a $10.3 million after-tax loss ($0.09 per diluted share) on extinguishments of debt.	
		
•	Midstream & Marketing net income was lower in Fiscal 2012 reflecting the effects of warmer weather on natural gas volumes sold and lower unit margins from our Electric Generation business. Lower and less volatile natural gas prices in Fiscal 2012 reduced capacity management income.	
		
•	Fiscal 2012 UGI International net income benefited from a lower effective income tax rate. Fiscal 2011 Antargaz results include $9.4 million ($0.08 per diluted share) from the reversal of a nontaxable reserve associated with a French competition authority matter.	

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AmeriGas Propane	 	2012	 	2011	 	Increase
(Decrease)	
(Dollars in millions)	 	 	 	 	 	 	 	 	
Revenues	 	$	2,921.5		 	$	2,538.2		 	$	383.3		 	15.1	 %	
Total margin (a)	 	$	1,199.1		 	$	932.8		 	$	266.3		 	28.5	 %	
Operating and administrative expenses	 	$	888.4		 	$	621.4		 	$	267.0		 	43.0	 %	
Partnership EBITDA (b)	 	$	322.1		 	$	295.6		 	$	26.5		 	9.0	 %	
Operating income	 	$	168.7		 	$	241.6		 	$	(72.9	)	 	(30.2	)%	
Retail gallons sold (millions)	 	1,017.5		 	874.2		 	143.3		 	16.4	 %	
Degree days – % (warmer) than normal (c)	 	(18.6	)%	 	(1.0	)%	 	—		 	—		

(a)	Total margin represents total revenues less total cost of sales.	
		
(b)	Partnership EBITDA (earnings before interest expense, income taxes and depreciation and amortization) should not be considered as an alternative to net income (as an indicator of operating performance) and is not a measure of performance or financial condition under GAAP. Management uses Partnership EBITDA as the primary measure of segment profitability for the AmeriGas Propane segment (see Note 22 to Consolidated Financial Statements). Partnership EBITDA for Fiscal 2012 and Fiscal 2011 includes pre-tax losses of $13.3 million and $38.1 million, respectively, associated with extinguishments of debt. Partnership EBITDA and operating income for Fiscal 2012 also include acquisition and transition expenses of $46.2 million associated with Heritage Propane.	
		
(c)	Deviation from average heating degree days for the 30-year period 1971-2000 based upon national weather statistics provided by NOAA for 335 airports in the United States, excluding Alaska.	

Based upon heating degree-day data, temperatures in the Partnership's service territories during Fiscal 2012 averaged 18.6% warmer than normal and 18.3% warmer than Fiscal 2011. The winter heating season also came to an early end with temperatures in the month of March averaging 38% warmer than normal. Notwithstanding the record warm weather's impact on our legacy AmeriGas Propane volumes, retail propane gallons sold were 143.3 million gallons greater than in the prior year reflecting the impact of Heritage Propane.

Retail propane revenues increased $362.6 million during Fiscal 2012 primarily reflecting higher retail volumes sold. The higher retail volumes sold reflects incremental gallons sold associated with Heritage Propane partially offset by the effects of weather-reduced volumes in AmeriGas Propane’s legacy operations. Wholesale propane revenues decreased $45.0 million principally reflecting lower wholesale volumes sold ($28.8 million) and lower average wholesale propane selling prices ($16.2 million). Average daily wholesale propane commodity prices during Fiscal 2012 at Mont Belvieu, Texas, one of the major supply points in the U.S., were approximately 20% lower than such prices during Fiscal 2011. Total revenues from fee income and other ancillary sales and services in Fiscal 2012 were $65.7 million higher than Fiscal 2011 reflecting such revenues from Heritage Propane. Total cost of sales increased $117.0 million principally reflecting incremental cost of sales from Heritage Propane offset in part by both the previously mentioned lower retail and wholesale volumes sold by our legacy AmeriGas Propane operations and the lower average propane commodity prices.
 
Total margin increased $266.3 million in Fiscal 2012 reflecting higher total propane margin ($218.6 million) and higher total margin from ancillary sales and services ($47.7 million). The increases principally reflect incremental margin from Heritage Propane partially offset by lower total propane margin from legacy AmeriGas Propane operations resulting from the significantly warmer weather.

Partnership EBITDA (which includes the losses on extinguishments of debt) in Fiscal 2012 increased $26.5 million principally reflecting the higher total margin ($266.3 million) and a $24.8 million lower loss from extinguishments of debt partially offset by higher operating and administrative expenses ($267.0 million) primarily attributable to Heritage Propane. Fiscal 2012 operating expenses include $46.2 million of acquisition and transition expenses associated with Heritage Propane. Operating income (which excludes the losses on extinguishments of debt) decreased $72.9 million in Fiscal 2012 principally reflecting the higher total margin ($266.3 million) more than offset by the increased operating expenses ($267.0 million) and greater depreciation and amortization expense ($73.6 million) principally associated with Heritage Propane.

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UGI International	 	2012	 	2011	 	Increase
	
(Dollars in millions)	 	 	 	 	 	 	 	 	
Revenues	 	$	1,946.1		 	$	1,488.7		 	$	457.4		 	30.7	%	
Total margin (a)	 	$	620.3		 	$	517.9		 	$	102.4		 	19.8	%	
Operating and administrative expenses	 	$	435.9		 	$	368.7		 	$	67.2		 	18.2	%	
Operating income	 	$	111.9		 	$	86.1		 	$	25.8		 	30.0	%	
Income before income taxes	 	$	80.7		 	$	57.0		 	$	23.7		 	41.6	%	
 	 	 	 	 	 	 	 	 	
Retail gallons sold (millions) (b)	 	576.5		 	429.7		 	146.8		 	34.2	%	
Antargaz degree days – % (warmer) than normal (c)	 	(7.1	)%	 	(4.7	)%	 	—		 	—		
Flaga degree days – % (warmer) than normal (c)	 	(6.4	)%	 	(4.6	)%	 	—		 	—		

(a)	Total margin represents total revenues less total cost of sales.	
		
(b)	Excludes retail gallons from operations in China.	
		
(c)	Deviation from average heating degree days for the 30-year period 1981-2010 at locations in our Antargaz and Flaga service territories.	

UGI International operating results in Fiscal 2012 include the operating results from the Shell Transaction. Based upon heating degree day data, temperatures across Europe were significantly warmer than normal and warmer than the prior year. Weather at Antargaz was approximately 7.1% warmer than normal in Fiscal 2012 compared to weather that was approximately 4.7% warmer than normal in Fiscal 2011. Temperatures in Flaga’s central and eastern European operations were approximately 6.4% warmer than normal in Fiscal 2012 compared to temperatures that were approximately 4.6% warmer than normal in Fiscal 2011. During Fiscal 2012, the average unweighted wholesale commodity price for propane in northwest Europe was approximately 4% higher than such prices in Fiscal 2011, while the average unweighted wholesale commodity price for butane was approximately 5% higher than Fiscal 2011. Retail LPG gallons sold were higher than the prior year reflecting incremental volumes of approximately 175 million gallons associated with the Shell Transaction partially offset by the effects of warmer and erratic weather patterns on volumes sold in our legacy UGI International operations.
 
Our UGI International base-currency results are translated into U.S. dollars based upon exchange rates experienced during each of the reporting periods. The functional currency of a significant portion of our UGI International results is denominated in euros. During Fiscal 2012 and Fiscal 2011, the average unweighted translation rate was approximately $1.30 and $1.40 per euro, respectively. The difference in rates did not have a material impact on net income attributable to UGI.

UGI International revenues increased $457.4 million, notwithstanding the effects of the significantly warmer weather, principally reflecting the effects of the Shell Transaction (approximately $569 million) partially offset by lower revenues from our legacy European LPG distribution businesses due in large part to the effects of the weaker euro. Cost of sales increased to $1,325.8 million in Fiscal 2012 from $970.8 million in Fiscal 2011 principally reflecting incremental cost of sales from the Shell Transaction (approximately $443 million) offset by lower cost of sales from our legacy European LPG distribution businesses due in large part to the effects of the weaker euro.

Total UGI International margin increased $102.4 million principally reflecting incremental margin from the Shell Transaction (approximately $125.8 million) and higher unit margins at our Antargaz legacy operations partially offset by the effects of the lower volumes at our legacy Antargaz and Flaga units resulting from the warmer weather.

UGI International operating income in Fiscal 2012 was $25.8 million higher than Fiscal 2011 principally reflecting the higher total margin ($102.4 million) resulting from the Shell Transaction offset by incremental expenses associated with these acquired businesses, including operating and administrative expenses, depreciation and acquisition integration costs. Fiscal 2012 operating and administrative expenses include approximately $7.0 million of Shell Transaction transition expenses. Fiscal 2011 operating income includes $9.4 million of other income from the reversal at Antargaz of a nontaxable reserve associated with the French competition authority matter at Antargaz. The $23.7 million increase in income before income taxes principally reflects the previously mentioned increase in operating income ($25.8 million) partially offset by a $2.7 million increase in interest expense, principally higher interest expense on Antargaz’ long-term debt and higher Flaga debt outstanding. Net income from UGI International operations in Fiscal 2012 benefited from a lower UGI International effective income tax rate resulting from the impact of the tax efficient structuring of certain of our international operations, the realization of $4.6 million of previously unrecognized foreign tax credits, and a higher proportion of pre-tax income in lower statutory tax-rate countries as a result of the Shell Transaction.

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Gas Utility	 	2012	 	2011	 	Increase
(Decrease)	
(Dollars in millions)	 	 	 	 	 	 	 	 	
Revenues	 	$	785.4		 	$	1,026.4		 	$	(241.0	)	 	(23.5	)%	
Total margin (a)	 	$	382.9		 	$	415.8		 	$	(32.9	)	 	(7.9	)%	
Operating and administrative expenses	 	$	156.0		 	$	169.3		 	$	(13.3	)	 	(7.9	)%	
Operating income	 	$	174.1		 	$	199.6		 	$	(25.5	)	 	(12.8	)%	
Income before income taxes	 	$	134.0		 	$	159.2		 	$	(25.2	)	 	(15.8	)%	
System throughput – bcf –	 	 	 	 	 	 	 	 	
     Core market	 	59.2		 	70.4		 	(11.2	)	 	(15.9	)%	
     Total	 	177.6		 	173.2		 	4.4		 	2.5	 %	
Degree days – % (warmer) colder than normal (b)	 	(16.3	)%	 	3.5	%	 	—		 	—		

(a)	Total margin represents total revenues less total cost of sales.	
		
(b)	Deviation from average heating degree days for the 15-year period 1995-2009 based upon weather statistics provided by NOAA for airports located within Gas Utility’s service territory.	

Temperatures in the Gas Utility service territory in Fiscal 2012 based upon heating degree days were 16.3% warmer than normal and approximately 18.7% warmer than the prior year. Total distribution system throughput was slightly higher than last year, notwithstanding the significantly warmer weather, principally reflecting greater throughput to certain non-weather-sensitive low-margin interruptible delivery service customers. Excluding total volumes to interruptible delivery service customers, Gas Utility system throughput declined 14.3 bcf in Fiscal 2012 principally reflecting the effects of the significantly warmer weather on throughput to core market customers (11.2 bcf) and lower firm delivery service volumes.

Gas Utility revenues decreased $241.0 million during Fiscal 2012 principally reflecting a decline in revenues from retail core-market customers ($169.4 million) and lower revenues from off-system sales ($68.1 million). The decrease in retail core-market revenues principally reflects the effects on gas cost recovery revenues of the lower retail core-market volumes ($91.9 million) and lower average PGC rates resulting from lower natural gas prices ($43.2 million). Gas Utility’s cost of gas was $402.5 million in Fiscal 2012 compared with $610.6 million in Fiscal 2011 reflecting the previously mentioned lower retail core-market sales ($91.9 million), the lower average PGC rates ($43.2 million) and the above-mentioned lower off-system sales.

Gas Utility total margin decreased $32.9 million in Fiscal 2012. The decrease principally reflects lower core market total margin ($27.7 million) and firm delivery service total margin ($4.8 million). Fiscal 2012 Gas Utility total margin includes a full-year of incremental margin from the August 2011 base rate increase at CPG of approximately $9.0 million.

The decreases in Gas Utility operating income and income before income taxes during Fiscal 2012 principally reflects the previously mentioned decrease in total margin ($32.9 million) partially offset by lower operating and administrative expenses.    

	
																
Midstream & Marketing	 	2012	 	2011	 	Increase
(Decrease)	
(Dollars in millions)	 	 	 	 	 	 	 	 	
Revenues (a)	 	$	853.9		 	$	1,059.2		 	$	(205.3	)	 	(19.4	)%	
Total margin (b)	 	$	130.4		 	$	137.5		 	$	(7.1	)	 	(5.2	)%	
Operating and administrative expenses	 	$	53.9		 	$	48.8		 	$	5.1		 	10.5	 %	
Operating income	 	$	64.3		 	$	80.8		 	$	(16.5	)	 	(20.4	)%	
Income before income taxes	 	$	59.5		 	$	78.1		 	$	(18.6	)	 	(23.8	)%	

(a) Amounts are net of intercompany revenues between Midstream & Marketing’s Energy Services and Electric Generation segments.

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(b) Total margin represents total revenues less total cost of sales. Amounts exclude pretax gains (losses) from changes in the fair values of Midstream & Marketing’s unsettled commodity derivative instruments and gains (losses) on settled commodity derivative instruments not associated with current period transactions of $15.1 million and $29.8 million in Fiscal 2012 and Fiscal 2011, respectively.

Midstream & Marketing Fiscal 2012 results were impacted by significantly warmer than normal heating-season temperatures and lower and less volatile natural gas prices. Midstream & Marketing total revenues decreased $205.3 million in Fiscal 2012 principally reflecting lower total revenues from natural gas marketing activities ($211.6 million), the result of lower average natural gas prices and lower volumes sold due to the warmer weather and, to a much lesser extent, lower Electric Generation revenues ($4.7 million) and capacity management revenues ($5.8 million). These decreases were partially offset by greater retail power revenues ($8.9 million), reflecting higher sales, and higher storage services revenues ($7.5 million).
    
The $7.1 million decrease in Midstream & Marketing’s total margin principally reflects lower natural gas marketing total margin ($17.4 million), lower capacity management total margin ($5.8 million), principally the result of the lower and less volatile natural gas prices, and lower Electric Generation total margin ($0.8 million) partially offset by greater retail power natural gas storage and gas gathering total margin. The decrease in Electric Generation total margin principally reflects the effects of lower electricity prices due in large part to the effects on electricity prices of lower natural gas prices.

Midstream & Marketing’s operating income in Fiscal 2012 was $16.5 million lower than Fiscal 2011 reflecting the decrease in total margin ( $7.1 million ) and higher operating, administrative and depreciation expenses associated with Electric Generation assets ($3.2 million), including incremental expenses associated with the repowered Hunlock Creek generation station and higher fuel and maintenance expenses associated with the Conemaugh generation station, and greater energy marketing and storage services’ operating and administrative expenses. The decline in income before income taxes reflects the lower operating income ($20.5 million) and greater interest expense principally on Energy Services’ credit facility borrowings.
Interest Expense. Our consolidated interest expense was $82.4 million higher in Fiscal 2012 reflecting higher AmeriGas Propane interest expense ($78.0 million) on debt issued to fund the acquisition of Heritage Propane; greater UGI International interest expense ($2.7 million); and slightly higher Midstream & Marketing interest expense.
Income Taxes. Our effective income tax rate in Fiscal 2012 was higher than in Fiscal 2011 principally reflecting a much smaller share of pre-tax income from AmeriGas Partners which income is generally not subject to entity-level income taxes. Excluding the impact on the effective income tax rate of AmeriGas Partners’ pre-tax income not subject to tax, the Fiscal 2012 effective tax rate was lower than in Fiscal 2011 reflecting, in large part, the effects of the previously mentioned lower UGI International income tax rate. The Fiscal 2011 effective tax rate was reduced by, among other things, the effect of the reversal of the $9.4 million reserve associated with the French competition authority matter at Antargaz, which was not subject to tax, and the regulatory effects of greater state tax depreciation (as further described below under “UGI Utilities Income Taxes”).

Financial Condition and Liquidity

We depend on both internal and external sources of liquidity to provide funds for working capital and to fund capital requirements. Our short-term cash requirements not met by cash from operations are generally satisfied with borrowings under credit facilities and, in the case of Midstream & Marketing, also from a receivables purchase facility. Long-term cash requirements not met by cash from operations are generally met through 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 purchase facility borrowings; 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.
Our cash and cash equivalents, excluding cash in commodity futures brokerage accounts that is restricted from withdrawal, totaled $389.3 million at September 30, 2013 , compared with $319.9 million at September 30, 2012 . Excluding cash and cash equivalents that reside at UGI’s operating subsidiaries, at September 30, 2013 and 2012 , UGI had $171.6 million and $107.9 million , respectively, of cash and cash equivalents. Such cash is available to pay dividends on UGI Common Stock and for investment purposes.
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.
AmeriGas Propane’s ability to pay dividends to UGI is dependent upon distributions it receives from AmeriGas Partners. At September 30, 2013 , our 27% effective ownership interest in the Partnership consisted of approximately 23.8 million  Common Units and an aggregate 2% general partner interest. Approximately 45 days after the end of each fiscal quarter, the Partnership

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distributes all of its Available Cash (as defined in the Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, as amended (the “Partnership Agreement”)) relating to such fiscal quarter. AmeriGas Propane, as general partner of AmeriGas Partners, is entitled to receive incentive distributions when AmeriGas Partners’ quarterly distribution exceeds $0.605 per limited partner unit (see Note 15 to Consolidated Financial Statements).
During Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , our principal business units paid cash dividends and made other cash payments to UGI and its subsidiaries as follows:

	
													
Year Ended September 30,	 	2013	 	2012	 	2011	
(Millions of dollars)	 	 	 	 	 	 	
AmeriGas Propane	 	$	96.2		 	$	78.6		 	$	56.8		
UGI Utilities	 	59.0		 	70.6		 	99.5		
UGI International	 	22.3		 	14.9		 	32.9		
Midstream & Marketing	 	—		 	55.0		 	30.0		
Total	 	$	177.5		 	$	219.1		 	$	219.2		

In Fiscal 2013 and Fiscal 2011, Midstream & Marketing received capital contributions from UGI totaling $27.5 million and $45.7 million, respectively, to fund major midstream asset and electric generation capital projects including Marcellus Shale infrastructure projects. Dividends in Fiscal 2012 from Midstream & Marketing were used to fund a portion of the October 2011 Shell Transaction.

On April 30, 2013, UGI’s Board of Directors approved an increase in the quarterly dividend rate on UGI Common Stock to $0.2825 per common share or $1.13 per common share on an annual basis. This dividend reflects a 4.6% increase from the previous quarterly dividend rate of $0.27. The new quarterly dividend rate was effective with the dividend payable on July 1, 2013, to shareholders of record on June 14, 2013.
On April 29, 2013, the General Partner’s Board of Directors approved a quarterly distribution of $0.84 per Common Unit equal to an annual rate of $3.36 per Common Unit. This distribution reflects an approximate 5% increase from the previous quarterly rate of $0.80 per Common Unit. The new quarterly rate was effective with the distribution payable on May 17, 2013, to unitholders of record on May 10, 2013.
As a result of the issuance of 29,567,362 AmeriGas Partners Common Units to ETP in conjunction with the acquisition of Heritage Propane and related General Partner Common Unit transactions (see Note 5 to Consolidated Financial Statements), and the issuance of 7,000,000 AmeriGas Partners Common Units pursuant to AmeriGas Partners’ public offering (see Note 15 to Consolidated Financial Statements), during Fiscal 2012, the Company recorded a $196.3 million increase in UGI Corporation stockholders’ equity (which amount is net of deferred income taxes) and an associated $321.4 million pre-tax decrease in noncontrolling interests equity.
Long-term Debt and Credit Facilities
The Company’s debt outstanding at September 30, 2013 , totaled $3,837.3 million (including current maturities of long-term debt of $67.2 million and bank loan borrowings of $227.9 million ) compared to debt outstanding at September 30, 2012 , of $3,679.4 million (including current maturities of long-term debt of $166.7 million and bank loan borrowings of $165.1 million ). Total debt outstanding at September 30, 2013 , consists of (1) $2,417.0 million of Partnership debt; (2) $660.9 million ( €488.6 million ) of UGI International debt; (3) $659.5 million of UGI Utilities’ debt; (4) $88.0 million of Midstream & Marketing debt; and (5) $11.9 million of other debt. For a detailed description of the Company’s debt, see below and Note 6 to Consolidated Financial Statements.
AmeriGas Partners. AmeriGas Partners’ total debt at September 30, 2013 , includes $2,250.8 million of AmeriGas Partners’ Senior Notes, $49.3 million of other long-term debt and $116.9 million of AmeriGas OLP bank loan borrowings.

In order to finance the cash portion of the acquisition of Heritage Propane, on January 12, 2012, AmeriGas Finance Corp. and AmeriGas Finance LLC (the “Issuers”) issued $550 million principal amount of 6.75% Notes due May 2020 (the “6.75% Notes”) and $1,000 million principal amount of 7.00% Notes due May 2022 (the “7.00% Notes”). The 6.75% Notes and the 7.00% Notes are fully and unconditionally guaranteed on a senior secured basis by AmeriGas Partners. The 6.75% and 7.00% Notes and the guarantees rank equal in right of payment with all of AmeriGas Partners’ existing senior notes. In connection with the acquisition of Heritage Propane, AmeriGas Partners, AmeriGas Finance Corp., AmeriGas Finance LLC and UGI entered into a Contingent

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Residual Support Agreement (“CRSA”) with ETP pursuant to which ETP will provide contingent, residual support of $1.5 billion of debt (“Supported Debt” as defined in the CRSA).
UGI International. UGI International’s total debt at September 30, 2013 , includes $ 514.0 million (€380 million) outstanding under Antargaz’ Senior Facilities term loan, $52 million under Flaga’s U.S. dollar-denominated term loan and a combined $81.8 million (€60.5 million) outstanding under Flaga’s euro-denominated term loans. Total UGI International debt outstanding at September 30, 2013 , also includes (1) combined borrowings of $ 6.5 million ( €4.8 million ) outstanding under Flaga’s working capital facilities and (2) $ 6.6 million ( €4.8 million ) of other long-term debt.
Antargaz . Antargaz has a variable-rate term loan agreement with a consortium of banks (“Senior Facilities Agreement”). The Senior Facilities Agreement consists of (1) a €380 million variable-rate term loan and (2) a €40 million credit facility. Scheduled maturities under the term loan are €38 million due May 2014, €34.2 million due May 2015, and €307.8 million due March 2016. Antargaz has entered into pay-fixed, receive-variable interest rate swaps to fix the underlying euribor rate of interest on the term loan at an average rate of approximately 2.45% through September 2015 and, thereafter, at a rate of approximately 3.71% through the date of the term loan’s final maturity in March 2016. At September 30, 2013 , the effective interest rate on Antargaz’ term loan was 4.41% .
Flaga . In order to finance the purchase of BP’s LPG distribution business in Poland in September 2013, Flaga entered into a $52 million U.S. dollar-denominated three-year loan that expires in September 2016. The $52 million loan bears interest at one- to twelve-month euribor rates (as chosen by Flaga from time to time) plus a margin. Flaga has effectively fixed the euribor component of the interest rate, and has effectively fixed the U.S. dollar value of the interest and principal payments payable under the $52 million loan, by entering into a cross-currency swap arrangement with a bank. At September 30, 2013, the effective interest rate on the $52 million loan was 1.82% .
Flaga also has a €40 million ($ 54.1 million ) euro-based term loan of which €26.7 million matures in August 2016 and €13.3 million matures in September 2016, and a €19.1 million ($ 25.8 million ) euro-based variable rate term loan that matures in October 2016. The €40 million term loan bears interest at one- to twelve-month euribor rates (as chosen by Flaga from time to time) plus a margin and the €19.1 million term loan bears interest at three-month euribor rates plus a margin. Flaga has effectively fixed the euribor components of the interest rates on these term loans through the dates of their expiration by entering into interest rate swap agreements. At September 30, 2013 , the effective interest rates on the €40 million and €19.1 million term loans were 4.68% and 3.85% , respectively.
At September 30, 2013, Flaga also had a euro-based variable-rate term loan which had outstanding principal balances of €1.4 ($1.9) with a final maturity in June 2014. This term loan bears interest at three-month euribor rates plus a margin. As of September 30, 2013, the effective interest rate on this term loan was 5.04%.
UGI Utilities. UGI Utilities’ total debt at September 30, 2013 , includes long-term debt comprising $ 275.0 million of Senior Notes, $ 192.0 million of Medium-Term Notes, $175 million outstanding under UGI Utilities Term Loan Credit Agreement and $17.5 million of bank loan borrowings.
In September 2013, UGI Utilities entered into a 364-day term loan credit agreement (“UGI Utilities Term Loan Credit Agreement”) with a bank comprising a $175 million unsecured term loan facility. The UGI Utilities Term Loan Credit Agreement bears interest at the eurodollar rate for the interest period selected, plus a margin of 0.60%. The UGI Utilities Term Loan Credit Agreement terminates on September 22, 2014, but UGI Utilities may prepay the loan in whole or in part, without penalty. UGI Utilities borrowed $175 million on September 30, 2013, under the UGI Utilities Term Loan Credit Agreement which cash proceeds were used to repay UGI Utilities’ $108 million 6.375% Senior Notes due September 30, 2013, and for other general corporate purposes. On October 30, 2013, UGI Utilities entered into a Note Purchase Agreement which provides for the private placement of $175 million aggregate principal amount of 4.98% Senior Notes due March 26, 2044. UGI Utilities expects to use $175 million of borrowings under the Note Purchase Agreement, anticipated to occur in March 2014, to repay amounts outstanding under the UGI Utilities Term Loan Credit Agreement.
Credit Facilities
Due to the seasonal nature of the Company’s businesses, operating cash flows are generally strongest during the second and third fiscal quarters when customers pay for natural gas, LPG, electricity and other energy products consumed during the peak heating season months. Conversely, operating cash flows are generally at their lowest levels during the first and fourth fiscal quarters when the Company’s investment in working capital, principally inventories and accounts receivable, is generally greatest. AmeriGas Propane and UGI Utilities primarily use their credit facilities to satisfy their seasonal operating cash flow needs. Energy Services historically has used its Receivables Facility to satisfy its operating cash flow needs. Energy Services also has a $240 million credit facility which it can use for working capital and general corporate purposes. Flaga principally uses borrowings

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under its credit agreements to satisfy its operating cash flow needs. During Fiscal 2013, Fiscal 2012 and Fiscal 2011, Antargaz generally funded its operating cash flow needs without using its revolving credit facilities and AvantiGas has satisfied its operating cash flow needs from cash on hand. Borrowings under the credit facilities and under the Energy Services Receivables Facility are classified as bank loans on the Consolidated Balance Sheets.
AmeriGas Partners. AmeriGas OLP has a $525 million unsecured credit agreement (“AmeriGas Credit Agreement”) that expires on October 15, 2016. During Fiscal 2012, the AmeriGas Credit Agreement was amended to, among other things, increase the total amount available to $525 million from $325 million previously, extend its expiration date to October 2016, and amend certain financial covenants as a result of the acquisition of Heritage Propane.

UGI International. Under its Senior Facilities Agreement, Antargaz has a €40 million credit facility that expires in March 2016. Flaga has two principal working capital facilities (the “Flaga Credit Agreements”) comprising (1) a €46 million multi-currency working capital facility that includes an uncommitted €6 million overdraft facility (the “Flaga Multi-Currency Working Capital Facility”) and (2) a euro-denominated working capital facility that provides for borrowings and issuances of guarantees totaling €12 million (the “Euro Facility”). Both the Flaga Multi-Currency Working Capital Facility and the Euro Facility expire in September 2014.
UGI Utilities. UGI Utilities has a revolving credit agreement (the “UGI Utilities Credit Agreement”) with a group of banks providing for borrowings up to $300 million (including a $100 million sublimit for letters of credit) which expires in October 2015.
Energy Services. At September 30, 2013, Energy Services had an unsecured credit agreement (“Energy Services Credit Agreement”) with a group of lenders providing for borrowings of up to $240 million (including a $50 million sublimit for letters of credit) which expires in June 2016. The Energy Services Credit Agreement can be used for general corporate purposes of Energy Services and its subsidiaries and to fund dividend payments provided that, after giving effect to such dividend payments, Energy Services maintains a specified ratio of Consolidated Total Indebtedness to EBITDA, each as defined in the Energy Services Credit Agreement.
    
Information about the Company’s principal credit agreements (excluding the Energy Services Receivables Facility discussed below) as of September 30, 2013 and 2012, is presented in the table below. There were no borrowings under Antargaz’ credit facility during Fiscal 2013 and Fiscal 2012.

							
(Millions of dollars or euros)	 	 	 	 	 	
As of September 30, 2013	Total Capacity	Borrowings Outstanding	Letters of Credit and Guarantees Outstanding	Available Capacity	Weighted Average Interest Rate - End of Year	
AmeriGas Credit Agreement	$525.0	$116.9	$53.7	$354.4	2.69	%	
Antargaz Credit Facility	€40.0	€0.0	€0.0	€40.0	N.A.		
Flaga Credit Agreements	€58.0	€0.2	€28.6	€29.2	4.21	%	
UGI Utilities Credit Agreement	$300.0	$17.5	$2.0	$280.5	1.18	%	
Energy Services Credit Agreement	$240.0	$57.0	$0.0	$183.0	2.19	%	

As of September 30, 2012	Total Capacity	Borrowings Outstanding	Letters of Credit and Guarantees Outstanding	Available Capacity	Weighted Average Interest Rate - End of Year	
AmeriGas Credit Agreement	$525.0	$49.9	$47.9	$427.2	2.72	%	
Antargaz Credit Facility	€40.0	€0.0	€0.0	€40.0	N.A.		
Flaga Credit Agreements	€58.0	€11.9	€19.2	€26.9	2.31	%	
UGI Utilities Credit Agreement	$300.0	$9.2	$2.0	$288.8	1.21	%	
Energy Services Credit Agreement	$170.0	$85.0	$0.0	$85.0	3.25	%	

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The average daily and peak bank loan borrowings under the Company’s principal credit agreements during Fiscal 2013 and 2012 are as follows:

						
(Millions of dollars or euros)	2013	 	2012	
 	Average	Peak	 	Average	Peak	
AmeriGas Credit Agreement	$103.8	$200.5	 	$95.3	$239.5	
Flaga Credit Agreements	€4.3	€11.9	 	€13.2	€14.3	
UGI Utilities Credit Agreement	$25.6	$79.0	 	$16.2	$70.6	
Energy Services Credit Agreement	$44.5	$85.0	 	$81.2	$85.0	
At September 30, 2013 , Energy Services had a $100 million receivables purchase facility (“Receivables Facility”) with an issuer of receivables-backed commercial paper. In October 2013, Energy Services extended its Receivables Facility until October 31, 2014 and amended the Receivables Facility to better align its borrowing limits with Energy Services’ seasonal borrowing needs. The Receivables Facility, as amended, provides Energy Services with the ability to borrow up to $150 million of eligible receivables during the period November 1, 2013 to May 31, 2014, and up to $75 million of eligible receivables during the period June 1, 2014 to October 31, 2014. Energy Services uses the Receivables Facility to fund working capital, margin calls under commodity futures contracts, capital expenditures, dividends and for general corporate purposes.
Under the Receivables Facility, Energy Services transfers, on an ongoing basis and without recourse, its trade accounts receivable to its wholly owned, special purpose subsidiary, Energy Services Funding Corporation (“ESFC”), which is consolidated for financial statement purposes. ESFC, in turn, has sold, and subject to certain conditions, may from time to time sell, an undivided interest in some or all of the receivables to a commercial paper conduit of a major bank (through September 30, 2013) and, subsequent to September 30, 2013, to the bank itself. ESFC was created and has been structured to isolate its assets from creditors of Energy Services and its affiliates, including UGI. Trade receivables sold to the commercial paper conduit or the bank remain on the Company’s balance sheet and the Company reflects a liability equal to the amount advanced by the commercial paper conduit or the bank. The Company records interest expense on amounts owed to the commercial paper conduit or the bank.
At September 30, 2013 , the outstanding balance of ESFC trade receivables was $55.0 million and there was $30.0 million  that was sold to the commercial paper conduit and reflected as bank loans on the Consolidated Balance Sheets. At September 30, 2012 , the outstanding balance of ESFC trade receivables was $43.5 million of which no amount was sold to the commercial paper conduit. During Fiscal 2013 and Fiscal 2012 , peak sales of receivables were $46.5 million and $51.5 million , respectively, and average daily amounts sold were $10.4 million and $15.6 million , respectively.
Cash Flows
Operating Activities. Year-to-year variations in cash flow from operations can be significantly affected by changes in operating working capital especially during periods of significant changes in energy commodity prices.
Cash flow provided by operating activities was $801.5 million in Fiscal 2013 , $707.7 million in Fiscal 2012 and $554.7 million in Fiscal 2011 . Cash flow from operating activities before changes in operating working capital was $845.6 million in Fiscal 2013 , $629.0 million in Fiscal 2012 and $697.6 million in Fiscal 2011 . The increase in cash flow from operating activities before changes in operating working capital in Fiscal 2013 compared to Fiscal 2012 largely reflects the effects of the higher operating results. Changes in operating working capital provided (used) operating cash flow of $(44.1) million in Fiscal 2013 , $78.7 million in Fiscal 2012 and $(142.9) million in Fiscal 2011 . The cash required to fund changes in operating working capital in Fiscal 2013 reflects, among other things, g reater cash needed to fund operating working capital associated with the increased Fiscal 2013 sales while cash provided by changes in operating working capital in the prior-year period benefited from the timing of the acquisition of Heritage Propane on cash receipts from Heritage Propane customers. This greater use of cash in the current-year period was partially offset by, among other things, the timing and amount of cash payments associated with accounts payable including the impact of lower LPG product costs.
Investing Activities . Investing activity cash flow is principally affected by expenditures for property, plant and equipment; cash paid for acquisitions of businesses; changes in restricted cash balances and proceeds from sales of assets. Net cash flow used by investing activities was $553.3 million in Fiscal 2013 , $1,904.5 million in Fiscal 2012 and $415.4 million in Fiscal 2011 . Cash paid for acquisitions in Fiscal 2013 largely includes Flaga’s acquisition of BP’s LPG distribution business in Poland; Midstream & Marketing’s acquisition of a non-operating working interest in natural gas acreage in the Marcellus Shale region of Pennsylvania; and several Partnership acquisitions.  Cash paid for acquisitions in Fiscal 2012 principally reflects the January 2012 acquisition of Heritage Propane and the October 2011 acquisition of certain of Shell’s European LPG businesses. Cash expenditures for property, plant and equipment totaled $486.0 million in Fiscal 2013, $339.4 million in Fiscal 2012 and $360.7 million in Fiscal

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2011. Cash from changes in restricted cash in futures brokerage accounts provided (used) cash of $ (5.3) million in Fiscal 2013, $ 14.2 million in Fiscal 2012 and $ 17.6 million in Fiscal 2011. The amount of restricted cash required in such accounts is generally the result of changes in underlying commodity prices.
Financing Activities. Cash flow provided (used) by financing activities was $(186.1) million  in Fiscal 2013 , $1,278.5 million in Fiscal 2012 and $(152.1) million in Fiscal 2011 . Changes in cash flow from financing activities are primarily due to issuances and repayments of long-term debt; net bank loan borrowings; dividends and distributions on UGI Common Stock and AmeriGas Partners Common Units; and issuances of UGI and AmeriGas Partners equity instruments.
Distributions on AmeriGas Partners’ publicly held Common Units in Fiscal 2013 increased over the prior-year period reflecting the full-year impact of a greater number of Common Units outstanding subsequent to the acquisition of Heritage Propane and higher quarterly per-unit distribution rates. In order to finance the cash portion of the acquisition of Heritage Propane, on January 12, 2012, AmeriGas Partners issued $550 million principal amount of 6.75% Notes due 2020 and $1.0 billion principal amount of 7.00% Notes due 2022. During March 2012, AmeriGas Partners sold 7 million Common Units in an underwritten public offering and used a portion of the net proceeds to repay $200 million of outstanding 6.50% Senior Notes due May 2021, to reduce bank loan borrowings and for general corporate purposes.
Capital Expenditures
In the following table, we present capital expenditures (which exclude acquisitions but include capital leases) by our business segments for Fiscal 2013 , Fiscal 2012 and Fiscal 2011 . We also provide amounts we expect to spend in Fiscal 2014 . We expect to finance Fiscal 2014 capital expenditures principally from cash generated by operations, borrowings under credit facilities and cash on hand.

	
																	
Year Ended September 30,	 	2014	 	2013	 	2012	 	2011	
(Millions of dollars)	 	(estimate)	 	 	 	 	 	 	
AmeriGas Propane	 	$	108.4		 	$	111.1		 	$	103.1		 	$	77.2		
UGI International	 	88.9		 	70.8		 	64.2		 	65.4		
Gas Utility	 	136.6		 	144.4		 	109.0		 	91.3		
Midstream & Marketing	 	108.9		 	156.4		 	60.4		 	112.8		
Other	 	8.4		 	7.5		 	6.5		 	8.9		
Total	 	$	451.2		 	$	490.2		 	$	343.2		 	$	355.6		

Midstream & Marketing’s capital expenditures in Fiscal 2013, Fiscal 2012 and Fiscal 2011 principally reflect capital expenditures related to natural gas storage, electric generation and Marcellus Shale projects. These Midstream & Marketing capital expenditures were financed in large part by capital contributions from UGI and cash from operations. AmeriGas Propane Fiscal 2013 and Fiscal 2012 capital expenditures include $20.4 million and $17.6 million, respectively, related to Heritage Propane integration activities. The increase in Gas Utility capital expenditures in Fiscal 2013 includes greater main replacement and system improvement capital expenditures.
Contractual Cash Obligations and Commitments
The Company has contractual cash obligations that extend beyond Fiscal 2013. Such obligations include scheduled repayments of long-term debt, interest on long-term fixed-rate debt, operating lease payments, unconditional purchase obligations for pipeline capacity, pipeline transportation and natural gas storage services and commitments to purchase natural gas, LPG and electricity, capital expenditures and derivative financial instruments. The following table presents contractual cash obligations with non-affiliates under agreements existing as of September 30, 2013:

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 	 	Payments Due by Period	
(Millions of dollars)	 	Total	 	Fiscal
2014	 	Fiscal
2015 -
2016	 	Fiscal
2017 -
2018	 	Thereafter	
Long-term debt (a)	 	$	3,605.7		 	$	68.0		 	$	856.0		 	$	98.0		 	$	2,583.7		
Interest on long-term-fixed rate debt (b)	 	1,796.5		 	216.1		 	432.8		 	345.6		 	802.0		
Operating leases	 	281.1		 	66.7		 	97.3		 	58.9		 	58.2		
AmeriGas Propane supply contracts	 	296.2		 	176.9		 	119.3		 	—		 	—		
UGI International supply contracts	 	489.0		 	198.1		 	290.9		 	—		 	—		
Midstream & Marketing supply contracts	 	367.0		 	244.4		 	121.4		 	1.2		 	—		
UGI Utilities supply, storage and transportation contracts	 	414.1		 	151.6		 	131.2		 	59.2		 	72.1		
Derivative financial instruments (c)	 	24.4		 	17.6		 	6.7		 	0.1		 	—		
Other purchase obligations (d)	 	28.6		 	28.6		 	—		 	—		 	—		
Total	 	$	7,302.6		 	$	1,168.0		 	$	2,055.6		 	$	563.0		 	$	3,516.0		

(a)	Based upon stated maturity dates. UGI Utilities’ $175 million Term Loan Credit Agreement borrowings anticipated to be refinanced on a long-term basis in March 2014 are presented in the table above under “Thereafter.”	
		
(b)	Based upon stated interest rates adjusted for the effects of interest rate swaps.	
		
(c)	Represents the sum of amounts due from us if derivative financial instrument liabilities were settled at the September 30, 2013, amounts reflected in the Consolidated Balance Sheet (but excluding amounts associated with interest rate swaps).	
		
(d)	Includes material capital expenditure obligations.	
Other noncurrent liabilities included in our Consolidated Balance Sheet at September 30, 2013, principally comprise 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 16 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 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. We believe we will be required to make contributions to UGI Utilities’ pension plan (as further described below under “U.S. Pension Plan”) in Fiscal 2014 of approximately $18  million. Contributions to the U.S. Pension Plan in years beyond Fiscal 2014 will depend in large part on the impact of future returns and interest rates on pension plan assets. Certain of our operating lease arrangements, primarily vehicle leases with remaining lease terms of one to ten years, have residual value guarantees. Although such fair values at the end of the leases have historically exceeded the guaranteed amount, at September 30, 2013, the maximum potential amount of future payments under lease guarantees assuming the leased equipment was deemed worthless was approximately $14.0 million.
Significant Acquisitions
In September 2013, Flaga acquired the LPG distribution business of BP in Poland for total cash consideration of approximately $36 million, subject to working capital adjustments. Also during Fiscal 2013, Energy Services acquired a non-operating working interest in natural gas acreage in the Marcellus Shale region of Pennsylvania for approximately $23 million in cash and AmeriGas OLP acquired two domestic retail propane distribution businesses for approximately $20 million in cash.

On January 12, 2012 (the “Acquisition Date”), AmeriGas Partners completed the acquisition of Heritage Propane for total consideration of approximately $2.6 billion comprising $1.5 billion in cash and 29,567,362 AmeriGas Partners Common Units with a fair value of approximately $1.1 billion. The acquisition of Heritage Propane was consummated pursuant to the Contribution Agreement by and among AmeriGas Partners, ETP, Energy Transfer Partners GP, L.P., the general partner of ETP, and Heritage ETC, L.P. (“Contribution Agreement”). The acquired business conducts its propane operations in 41 states. According to LP-Gas Magazine rankings published on February 1, 2012, Heritage Propane was the third largest retail propane distributor in the United States, delivering over 500 million gallons to more than one million retail propane customers in 2011. The acquisition of Heritage Propane is consistent with our growth strategies, one of which is to grow our core business through acquisitions. The results of operations of Heritage Propane are included in the Consolidated Statements of Income since the Acquisition Date.

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In October 2011, we acquired Shell’s LPG distribution businesses in the United Kingdom, Belgium, the Netherlands, Luxembourg, Denmark, Finland, Norway and Sweden for €133.6 million ( $179.0 million) in cash.
For additional information on these acquisitions, see Note 5 to Consolidated Financial Statements.
U.S. Pension Plan
In the U.S., we currently sponsor one defined benefit pension plan for employees hired prior to January 1, 2009, of UGI, UGI Utilities, PNG, CPG and certain of UGI’s other domestic wholly owned subsidiaries (“U.S. Pension Plan”). The fair value of the U.S. Pension Plan’s assets totaled $398.2 million and $351.5 million at September 30, 2013 and 2012, respectively. At September 30, 2013 and 2012, the underfunded positions of the U.S. Pension Plan, defined as the excess of the projected benefit obligation (“PBO”) over the U.S. Pension Plan’s assets, were $88.3 million and $192.1 million, respectively.
We believe we are in compliance with regulations governing defined benefit pension plans, including Employee Retirement Income Security Act of 1974 (“ERISA”) rules and regulations. We anticipate that we will be required to make contributions to the U.S. Pension Plan during Fiscal 2014 of approximately $18  million. Pre-tax pension cost associated with the U.S. Pension Plan in Fiscal 2013 was $19.9 million. Pre-tax pension cost associated with the U.S. Pension Plan in Fiscal 2014 is expected to be approximately $11 million.
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. Through September 30, 2013, we have recorded cumulative after-tax charges to UGI Corporation’s stockholders’ equity of $17.1 million and recorded regulatory assets totaling $94.5 million in order to reflect the funded status of our pension and other postretirement benefit plans. For a more detailed discussion of the U.S. Pension Plan and our other postretirement benefit plans, see Note 8 to Consolidated Financial Statements.

Related Party Transactions
During Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , 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 Matters
On February 19, 2013, the PUC entered a final order (the “Final Order”) settling all regulatory compliance issues pertaining to a natural gas explosion on February 9, 2011, in Allentown, PA. The Final Order requires UGI Utilities to (i) pay a civil penalty in the amount of $0.5 million; (ii) conduct a pilot new technology leak detection program in Allentown; and (iii) accept new reporting requirements governing its agreed upon 14 -year cast iron and 30 -year bare steel pipeline replacement program and distribution integrity management program. The Final Order makes no findings that UGI Utilities has violated any regulation or operating procedure. The Company does not believe that the cost of complying with the requirements of the Final Order will have a material impact on UGI Utilities’ consolidated financial position, results of operations or cash flows.
On August 11, 2011, the PUC approved a settlement agreement with CPG that resulted in an increase in annual base rate revenues of $8.0 million as well as $0.9 million in revenues per year to fund system improvements and operations necessary to maintain safe and reliable natural gas service and fund new programs that would provide rebates and other incentives for customers to install new high-efficiency equipment (collectively, “Energy and Efficiency Conservation Program”). The increase became effective August 30, 2011. During Fiscal 2012, the PUC reversed its earlier decision related to the $0.9 million increase in revenues associated with the Energy and Efficiency Conservation Program and required CPG to refund revenue it had collected for that program.

On February 1, 2012, CPG filed an application with the PUC for review and approval of the transfer of an 11-mile natural gas pipeline, related facilities and right of way located in Delmar Township, Pennsylvania (“TL-96 line”) to Energy Services.  The PUC approved the transfer and, in April 2013, the TL-96 line was dividended to UGI and subsequently contributed to Energy

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Services.  The net book value of the TL-96 line is approximately $2.6 million.
On October 21, 2010, FERC approved and later affirmed CPG’s application to abandon a storage service and approved the transfer of its Tioga, Meeker and Wharton natural gas storage facilities, along with related assets, to UGI Storage Company, a subsidiary of Energy Services. The PUC approved the transfer subject to, among other things, a reduction in base rates and CPG’s agreement to charge PGC customers, for a period of three years, no more for storage services from the transferred assets than they would have paid before the transfer, to the extent used. On April 1, 2011, the storage facilities were dividended to UGI and subsequently contributed to UGI Storage Company. The net book value of the storage facility assets was $10.9 million. Compliance with the provisions of the PUC Order approving the transfer of the storage assets did not have a material impact on the results of operations of Gas Utility. Concurrent with the April 1, 2011 transfer, CPG entered into a one-year firm storage service agreement with UGI Storage Company.
On December 1, 2010, PNG filed an application with the PUC for expedited review and approval of the transfer of a 9 mile natural gas pipeline, related facilities, and right of way located in Mehoopany, Pennsylvania (the “Auburn Line”) to Energy Services. The PUC approved the transfer and in September 2011 the Auburn Line was dividended to UGI and subsequently contributed to Energy Services. The net book value of the Auburn Line was $1.1 million.
UGI Utilities Income Taxes
In 2010, U.S. federal tax legislation was enacted that allowed taxpayers to fully deduct qualifying capital expenditures incurred after September 8, 2010, through the end of calendar 2011, when such property was placed in service before 2012. In accordance with existing Pennsylvania tax statutes, Pennsylvania taxpayers are also permitted to fully deduct such qualifying capital expenditures for Pennsylvania state corporate net income tax purposes. Pennsylvania utility ratemaking practice permits the flow through to ratepayers of state tax benefits from accelerated tax depreciation. UGI Utilities’ Fiscal 2011 and, to a lesser extent, Fiscal 2012 state tax rates reflect the beneficial effects of this greater state tax depreciation.

Manufactured Gas Plants
UGI Utilities
CPG is party to a Consent Order and Agreement (“CPG-COA”) with the Pennsylvania Department of Environmental Protection (“DEP”) requiring CPG to perform a specified level of activities associated with environmental investigation and remediation work at certain properties in Pennsylvania on which manufactured gas plant (“MGP”) related facilities were operated (“CPG MGP Properties”) and to plug a minimum number of non-producing natural gas wells per year. In addition, PNG is a party to a Multi-Site Remediation Consent Order and Agreement (“PNG-COA”) with the DEP. The PNG-COA requires PNG to perform annually a specified level of activities associated with environmental investigation and remediation work at certain properties on which MGP-related facilities were operated (“PNG MGP Properties”). Under these agreements, environmental expenditures relating to the CPG MGP Properties and the PNG MGP Properties are capped at $1.8 and $1.1 , respectively, in any calendar year. The CPG-COA is currently scheduled to terminate at the end of 2013. The PNG-COA terminates in 2019 but may be terminated by either party effective at the end of any two-year period beginning with the original effective date in March 2004. At September 30, 2013 and 2012, our accrued liabilities for environmental investigation and remediation costs related to the CPG-COA and the PNG-COA totaled $14.0 million and $15.0 million , respectively. Because CPG and PNG are currently receiving regulatory recovery of estimated environmental investigation and remediation costs associated with Pennsylvania sites, in accordance with GAAP related to rate-regulated entities we have recorded associated regulatory assets in equal amounts.
From the late 1800s through the mid-1900s, UGI Utilities and its former subsidiaries owned and operated a number of MGPs prior to the general availability of natural gas. Some constituents of coal tars and other residues of the manufactured gas process are today considered hazardous substances under the Superfund Law and may be present on the sites of former MGPs. Between 1882 and 1953, UGI Utilities owned the stock of subsidiary gas companies in Pennsylvania and elsewhere and also operated the businesses of some gas companies under agreement. Pursuant to the requirements of the Public Utility Holding Company Act of 1935, by the early 1950s UGI Utilities divested all of its utility operations other than certain Pennsylvania operations, including those which now constitute UGI Gas and Electric Utility.
UGI Utilities does not expect its costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to its results of operations because (1) UGI Gas is currently permitted to include in rates, through future base rate proceedings, a five-year average of such prudently incurred remediation costs and (2) CPG and PNG are currently receiving regulatory recovery of estimated environmental investigation and remediation costs associated with Pennsylvania sites. At September 30, 2013, neither the undiscounted nor the accrued liability for environmental investigation and cleanup costs for UGI Gas was material.

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From time to time, UGI Utilities is notified of sites outside Pennsylvania on which private parties allege MGPs were formerly owned or operated by it or owned or operated by its former subsidiaries. Such parties generally investigate the extent of environmental contamination or perform environmental remediation. Management believes that under applicable law UGI Utilities should not be liable in those instances in which a former subsidiary owned or operated an MGP. There could be, however, significant future costs of an uncertain amount associated with environmental damage caused by MGPs outside Pennsylvania that UGI Utilities directly operated, or that were owned or operated by former subsidiaries of UGI Utilities if a court were to conclude that (1) the subsidiary’s separate corporate form should be disregarded or (2) UGI Utilities should be considered to have been an operator because of its conduct with respect to its subsidiary’s MGP.
For additional information on an MGP site outside of Pennsylvania currently subject to a third-party claim, see Note 16 to Consolidated Financial Statements.
AmeriGas Propane
By letter dated March 6, 2008, the New York State Department of Environmental Conservation (“DEC”) notified AmeriGas OLP that DEC had placed property owned by the Partnership in Saranac Lake, New York, on its Registry of Inactive Hazardous Waste Disposal Sites. A site characterization study performed by DEC disclosed contamination related to former MGP operations on the site. DEC has classified the site as a significant threat to public health or environment with further action required. The Partnership has researched the history of the site and its ownership interest in the site and reviewed the preliminary site characterization study prepared by the DEC, the extent of contamination and the possible existence of other potentially responsible parties. The Partnership communicated the results of its research to DEC in January 2009. There have been no recent developments in this matter. Because of the preliminary nature of available environmental information, the ultimate amount of expected clean up costs cannot be reasonably estimated. 
In connection with the acquisition of Heritage Propane on January 12, 2012, a predecessor of Titan Propane LLC (“Titan LLC”), a former subsidiary acquired in the acquisition of Heritage Propane, is purportedly the beneficial holder of title with respect to two former MGPs discussed below. The Contribution Agreement provides for indemnification from ETP for certain expenses associated with remediation of these sites. By letter dated September 30, 2010, the EPA notified Titan LLC that it may be a potentially responsible party (“PRP”) for cleanup costs associated with contamination at a former MGP in Claremont, New Hampshire. In June 2010, the Maryland Attorney General (“MAG”) identified Titan LLC as a PRP in connection with contamination at a former MGP in Chestertown, Maryland and requested that Titan LLC participate in characterization and remediation activities. Titan LLC has supplied the EPA and MAG with corporate and bankruptcy information for its predecessors to support its claim that it is not liable for any remediation costs at the sites. Because of the preliminary nature of available environmental information, the ultimate amount of expected clean up costs cannot be reasonably estimated.
We cannot predict with certainty the final results of any of the MGP matters referenced above. However, it is reasonably possible that some of them could be resolved unfavorably to us and result in losses in excess of recorded amounts. We are unable to estimate any possible losses in excess of recorded amounts. Although we currently believe, after consultation with counsel, that damages or settlements, if any, recovered by the plaintiffs in such claims or actions will not have a material adverse effect on our financial position, damages or settlements could be material to our operating results or cash flows in future periods depending on the nature and timing of future developments with respect to these matters and the amounts of future operating results and cash flows.

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.

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Commodity Price Risk

The risk associated with fluctuations in the prices the Partnership and our International Propane operations pay for LPG is principally a result of market forces reflecting changes in supply and demand for propane 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 International Propane 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 and option contracts. Our UGI International LPG operations also use over-the-counter price swap and option contracts to reduce commodity price volatility associated with a portion of their forecasted LPG purchases. Over-the-counter derivative commodity instruments used to hedge forecasted purchases of propane are generally settled at expiration of the contract. In addition, Antargaz hedges a portion of its future U.S. dollar denominated LPG product purchases through the use of forward foreign exchange contracts as further described below.

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

Electric Utility’s DS tariffs contain clauses which permit recovery of all prudently incurred power costs, including the cost of financial instruments used to hedge electricity costs, through the application of DS rates. Because of this ratemaking mechanism, there is limited power cost risk, including the cost of financial transmission rights (“FTRs”) and forward electricity purchase contracts, associated with our Electric Utility operations.
In addition, Gas Utility and Electric Utility from time to time enter into exchange-traded gasoline futures and swap contracts for a portion of gasoline volumes expected to be used in their operations. These gasoline futures and swap contracts are recorded at fair value with changes in fair value reflected in other income.
In order to manage market price risk relating to substantially all of Midstream & Marketing’s fixed-price sales contracts for natural gas and electricity, Midstream & Marketing enters into NYMEX, IntercontinentalExchange and over-the-counter natural gas and electricity futures 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. Midstream & Marketing has entered into and may continue to enter into fixed-price propane sales agreements. In order to manage the market price risk relating to substantially all of its fixed-price propane sales agreements, Midstream & Marketing enters into price swap and option contracts.

Midstream & Marketing purchases FTRs to economically hedge certain transmission costs that may be associated with its fixed-price electricity sales contracts. Midstream & Marketing from time to time also enters into New York Independent System Operator (“NYISO”) capacity swap contracts to economically hedge the locational basis differences for customers it serves on the NYISO electricity grid. Midstream & Marketing also uses NYMEX futures contracts to economically hedge the gross margin associated with the purchase and anticipated later sale of natural gas or propane. Although Midstream & Marketing’s FTRs and NYISO capacity swap contracts, and NYMEX futures contracts associated with the purchase and later anticipated sale of natural gas and propane, are generally effective as economic hedges, they do not currently qualify for hedge accounting treatment.    
UGID 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, UGID 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 UGID’s results.

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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 includes bank loan borrowings and Antargaz’ and Flaga’s variable-rate term loans. These debt agreements have interest rates that are generally indexed to short-term market interest rates. Antargaz and Flaga have effectively fixed the underlying euribor interest rates on their euro-denominated term loans through their scheduled maturity dates through the use of interest rate swaps. In addition, Flaga’s $52 million U.S. dollar-denominated loan has been swapped from fixed-rate U.S. dollars to fixed-rate euro currency at issuance through cross currency swaps, removing interest rate risk and foreign currency exchange risk associated with the underlying interest and principal payments. At September 30, 2013, combined borrowings outstanding under variable-rate debt agreements, excluding Antargaz’ and Flaga’s effectively fixed-rate term loans and Flaga’s U.S. dollar-denominated loan, totaled $227.9 million. Based upon average borrowings outstanding under variable-rate borrowings (excluding Antargaz’ and Flaga’s effectively fixed-rate term loan debt and Flaga’s U.S. dollar denominated loan), an increase in short-term interest rates of 100 basis points (1%) would have increased our Fiscal 2013 and Fiscal 2012 interest expense by approximately $1.8 million and $2.8 million, respectively. 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 $170.3 million and $160.1 million at September 30, 2013 and 2012, respectively. A 100 basis point decrease in market interest rates would result in increases in the fair value of this fixed-rate debt of $102.2 million and $137.0 million at September 30, 2013 and 2012, respectively.
Long-term debt associated with our domestic businesses is typically issued at fixed rates of interest based upon market rates for debt having 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 interest rate protection agreements (“IRPAs”). There were no unsettled IRPAs at September 30, 2013.
Foreign Currency Exchange Rate Risk
Our primary currency exchange rate risk is associated with the U.S. dollar versus the euro. 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 (“net investment hedges”). Gains or losses on net investment hedges remain in accumulated other comprehensive income until such foreign operations are liquidated. At September 30, 2013, there were no unsettled net investment hedges outstanding. With respect to our net investments in our International Propane operations, a 10% decline in the value of the associated foreign currencies versus the U.S. dollar, excluding the effects of any net investment hedges, would reduce their aggregate net book value at September 30, 2013, by approximately $94 million, which amount would be reflected in other comprehensive income.
In addition, in order to reduce volatility, Antargaz hedges a portion of its anticipated U.S. dollar-denominated LPG product purchases during the months of October through March through the use of forward foreign exchange contracts. The amount of dollar-denominated purchases of LPG associated with such contracts generally represents approximately 15% - 30% of estimated dollar-denominated purchases to occur during the heating-season months of October to March.
Derivative Financial Instrument Credit Risk

We are exposed to risk of loss in the event of nonperformance by our derivative financial instrument counterparties. Our derivative financial 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.
Certain of our derivative instrument agreements call for the posting of collateral by the counterparty or by the Company in the forms of letters of credit, parental guarantees or cash. Additionally, our natural gas and electricity exchange-traded futures and option contracts generally require cash deposits in margin accounts. Declines in natural gas, LPG and electricity product costs can require our business units to post collateral with counterparties or make margin deposits to brokerage accounts. At September 30, 2013 and 2012, restricted cash in brokerage accounts totaled $7.0 million  and $ 3.0 million , respectively.
The following table summarizes the fair values of unsettled market risk sensitive derivative instruments assets (liabilities) held at September 30, 2013 and 2012. The table also includes the changes in fair values of derivative instruments that

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would result if there were a 10% adverse change in (1) the market prices of LPG, gasoline, natural gas, electricity and electricity transmission congestion charges; (2) the three-month and one-month Euribor rates; and (3) the value of the euro versus the U.S. dollar. Gas Utility’s and Electric Utility’s derivative instruments other than gasoline futures and swap contracts are excluded from the table below because any associated net gains or losses are refundable to or recoverable from customers in accordance with Gas Utility and Electric Utility ratemaking.

									
 	 	Asset (Liability)	
(Millions of dollars)	 	Fair Value	 	Change in
Fair Value	
September 30, 2013:	 	 	 	 	
Commodity price risk	 	$	14.0		 	$	(48.3	)	
Interest rate risk	 	(31.0	)	 	(0.8	)	
Foreign currency exchange rate risk	 	(7.5	)	 	(26.2	)	
 	 	 	 	 	
September 30, 2012:	 	 	 	 	
Commodity price risk	 	(43.7	)	 	(35.9	)	
Interest rate risk	 	(71.9	)	 	(2.9	)	
Foreign currency exchange rate risk	 	1.8		 	(15.4	)	

Because a significant portion of our derivative instruments qualify as hedges under GAAP, we expect that changes in the fair value of derivative instruments used to manage commodity, currency or interest rate market risk would be substantially offset by gains or losses on the associated anticipated transactions.

Critical Accounting Policies and Estimates
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. Changes in these policies and estimates could have a material effect on the financial statements. 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 which could have a material impact on the financial statements. Management has reviewed these critical accounting policies, and the estimates and assumptions associated with them, with the Company’s Audit Committee. In addition, management has reviewed the following disclosures regarding the application of these critical accounting policies and estimates with the Audit Committee. Also, see Note 2 to Consolidated Financial Statements which discusses the significant accounting policies that we have selected from acceptable alternatives.
Litigation Accruals and Environmental Remediation Liabilities. We are involved in litigation regarding pending claims and legal actions that arise in the normal course of business. In addition, UGI Utilities and its former subsidiaries owned and operated a number of MGPs in Pennsylvania and elsewhere, and PNG and CPG owned and operated a number of MGP sites located in Pennsylvania, at which hazardous substances may be present. In accordance with GAAP, when a loss is considered probable and reasonably estimable, we record a liability in the amount of our best estimate for the ultimate loss. When there is a range of possible loss with equal likelihood, liabilities recorded are based upon the low end of such range. The likelihood of a loss with respect to a particular contingency is often difficult to predict and determining 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 contingency. Reasonable estimates involve management judgments based on a broad range of information and prior experience. These judgments are reviewed quarterly as more information is received and the amounts reserved are updated as necessary. Such estimated reserves may differ materially from the actual liability and such reserves may change materially as more information becomes available and estimated reserves are adjusted.

Accounting For Derivative Instruments At Fair Value. The Company enters into derivative instruments to hedge the risks associated with changes in commodity prices, interest rates and foreign currency rates. Accounting requirements for derivatives and related hedging activities are complex and may be subject to further clarification by standard-setting bodies. These derivatives are recognized as assets and liabilities at fair value on the Consolidated Balance Sheets. Changes in the fair values of derivative instruments that qualify and are designated as cash flow hedges are recorded in AOCI or noncontrolling interests, both of which are components of equity, to the extent effective at offsetting changes in the hedged item, until earnings are affected by the hedged item. Changes in the fair values of derivative instruments that we do not designate as, or that do not qualify for, hedges under GAAP, which currently comprise substantially all of Midstream & Marketing’s commodity derivative instruments, are recognized in earnings on the Consolidated Statements of Income. The fair values of our derivative instruments are determined based upon actively-quoted market prices for identical assets and liabilities, indicative price quotations available through brokers, industry

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price publications or recent market transactions and related market indicators. We maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. Gains and losses associated with derivatives utilized by UGI Utilities to manage the price risk inherent in its natural gas purchasing and electricity activities are recoverable through PGC or Electric Utility default service mechanisms, subject to PUC approval. Accordingly, the offset to the change in fair value of these derivatives is recorded as either a regulatory asset or liability on the Consolidated Balance Sheets. At September 30, 2013, our total net derivative liabilities totaled $31.2 million .
Regulatory Assets and Liabilities. Gas Utility and Electric Utility are subject to regulation by the PUC. In accordance with accounting guidance associated with rate-regulated entities, we record the effects of rate regulation in our financial statements as regulatory assets or regulatory liabilities. 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 PUC, and the status of any pending deregulation legislation. 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, 2013 , our regulatory assets totaled $244.9 million . See Notes 2 and 9 to Consolidated Financial Statements.
Depreciation and Amortization of Long-Lived Assets. We compute depreciation on utility property, plant and equipment on a straight-line basis over the average remaining lives of its various classes of depreciable property and on our non-utility property, plant and equipment on a straight-line basis over estimated useful lives generally ranging from 2 to 40 years. We also use amortization methods and determine asset values of intangible assets subject to amortization using reasonable assumptions and projections. Changes in the estimated useful lives of property, plant and equipment and changes in intangible asset amortization methods or values could have a material effect on our results of operations. As of September 30, 2013 , our net property, plant and equipment totaled $4,480.2 million and we recorded depreciation expense of $301.4 million during Fiscal 2013 . As of September 30, 2013 , our net intangible assets subject to amortization totaled $ 477.7 million and we recorded amortization expense on intangible assets subject to amortization of $52.8 million during Fiscal 2013 .
Purchase Price Allocations. From time to time, the Company enters into material business combinations. In accordance with accounting guidance associated with business combinations, the purchase price is allocated to the various assets acquired and liabilities assumed at their estimated fair value. Fair values of assets acquired and liabilities assumed are based upon available information and we may involve an independent third party to perform appraisals. Estimating fair values can be complex and subject to significant business judgment and most commonly impacts property, plant and equipment and intangible assets, including those with indefinite lives. Generally, we have, if necessary, up to one year from the acquisition date to finalize the purchase price allocation.
Impairment of Goodwill. We do not amortize goodwill, but test it at least annually for impairment at the reporting unit level. A reporting unit is the operating segment, or a business one level below the operating segment (a component), if discrete financial information is prepared and regularly reviewed by segment management. Components are aggregated if they have similar economic characteristics. Certain of the Company’s operating segments have goodwill resulting from purchase business combinations. In accordance with GAAP, each of our reporting units with goodwill is required to perform impairment tests annually or whenever events or circumstances indicate that the value of goodwill may be impaired. For certain of our reporting units, 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, and for those reporting units for which we are not able, based upon the assessment of qualitative factors, to determine that it is more likely than not that the fair value of such reporting unit is not less than its carrying amount, we determine fair values generally using an income approach unless market values are available. For purposes of the income approach, fair values are determined based upon the present value of estimated future cash flows discounted at an appropriate risk-adjusted rate. Cash flow estimates used to establish fair values involve management judgments based on a broad range of information and historical results. We use our internal forecasts to estimate future cash flows and include an estimate of long-term future growth rates based upon our most recent reviews of the long-term outlook for each reporting unit. We are required to recognize an impairment charge under GAAP if the carrying amount of a reporting unit exceeds its fair value and the carrying amount of the reporting unit’s goodwill exceeds the implied fair value of that goodwill. To the extent estimated cash flows are revised downward, the reporting unit may be required to write down all or a portion of its goodwill which would adversely impact our results of operations. As of September 30, 2013 , our goodwill totaled $2,873.7 million . We did not record any impairments of goodwill in Fiscal 2013 , Fiscal 2012 or Fiscal 2011 .
Pension Plan Assumptions. Pension plan assumptions are significant inputs to the actuarial models that measure pension benefit obligations and pension expense. The cost of providing benefits under the U.S. Pension Plan is dependent on historical information such as employee age, length of service, level of compensation and the actual rate of return on plan assets. In addition, certain assumptions relating to the future are used to determine pension expense including the discount rate applied to benefit obligations, the expected rate of return on plan assets and the rate of compensation increase, among others. Assets of the U.S. Pension Plan are held in trust and consist principally of equity and fixed income mutual funds. Changes in plan assumptions as well as fluctuations

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in actual equity or fixed income market returns could have a material impact on future pension costs. We believe the two most critical assumptions are (1) the expected rate of return on plan assets and (2) the discount rate. A decrease in the expected rate of return on U.S. Pension Plan assets of 50 basis points to a rate of 7.25% would result in an increase in pre-tax pension cost of approximately $1.9 million in Fiscal 2014. A decrease in the discount rate of 50 basis points to a rate of 4.70% would result in an increase in pre-tax pension cost of approximately $3.1 million in Fiscal 2014.
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. 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, 2013 , our net deferred tax liabilities totaled $967.4 million .

Recently Issued Accounting Pronouncements
See Note 4 to Consolidated Financial Statements for a discussion of the effects of recently issued accounting guidance.

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	
Management’s Annual Report on Internal Control Over Financial Reporting and the financial statements and financial statement schedules referred to in the Index contained on page F-2 of this Report are incorporated herein by reference.

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

ITEM 9A.	CONTROLS AND PROCEDURES	
		
(a)	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 defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended), 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, because of the material weakness in internal control over financial reporting identified in “Management’s Annual Report on Internal Control over Financial Reporting” (see Item 8 of this Report), the Company’s disclosure controls and procedures were not effective as of September 30, 2013.	

Remediation Plans

Management and the Board of Directors are committed to the remediation of the material weakness related to the accounting for commodity derivative instruments described in Item 8 of this Report. Subsequent to the end of the Company’s fiscal year ended September 30, 2013 the Company has taken or will take the following actions designed to remediate the material weakness: 1) supplement the Company’s existing technical expertise necessary to evaluate the accounting for commodity derivatives, 2) enhance controls over the assessment of new commodity derivative agreements to ensure the appropriate accounting is identified at the inception of the agreement, and 3) enhance controls over commodity derivative agreements to ensure that any ongoing compliance requirements are appropriately monitored. Management expects to remediate the material weakness during fiscal 2014. In addition, management has discontinued the use of hedge accounting for commodity derivative instruments at Midstream and Marketing and will report mark-to-market adjustments on unsettled derivatives.

(b)	For “Management’s Annual Report on Internal Control over Financial Reporting” see Item 8 of this Report (which information is incorporated herein by reference).	

(c)	During the most recent fiscal quarter, 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.	

ITEM 9B.	OTHER INFORMATION	
None.

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PART III:

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, 2013.

	
				
 	Information	 	Captions of Proxy Statement
Incorporated by Reference	
Item 10.	Directors, Executive Officers and Corporate Governance	 	Election of Directors - Nominees; Corporate Governance; Board Independence; Board Committees; Communications with the Board; Securities Ownership of Management - Section 16(a) - Beneficial Ownership Reporting Compliance; Report of the Audit Committee of the Board of Directors	
 	 	 	 	
 	The Code of Ethics for the Chief Executive Officer and Senior Financial Officers of UGI Corporation is available without charge on the Company’s website, www.ugicorp.com, or by writing to Treasurer, UGI Corporation, P. O. Box 858, Valley Forge, PA 19482.	 	 	
 	 	 	 	
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	
 	 	 	 	
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	 	Securities Ownership of Certain Beneficial Owners; Securities Ownership of Management	
 	 	 	 	
Item 13.	Certain Relationships and Related Transactions, and Director Independence	 	Election of Directors — Board Independence and Board Committees; Policy for Approval of Related Person Transactions	
 	 	 	 	
Item 14.	Principal Accounting Fees and Services	 	Our Independent Registered Public Accounting Firm	

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Equity Compensation Table

The following table sets forth information as of the end of Fiscal 2013 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	 	6,795,968		(1)	$	28.92		 	13,637,192		(2)	
 	 	920,601		(3)	$	0		 	 	 	
Equity compensation plans not approved by security holders	 	0		 	 	 	 	 	
Total	 	7,716,569		 	$	28.92		(4)	 	 	

(1)	Represents 6,795,968 stock options under the UGI Corporation 2004 Omnibus Equity Compensation Plan Amended and Restated as of December 5, 2006 and the UGI Corporation 2013 Omnibus Incentive Compensation Plan.	
		
(2)	Represents 187,543 securities remaining for future issuance of stock options from the 2004 Omnibus Equity Compensation Plan Amended and Restated as of December 5, 2006 and 13,449,649 of securities for issuance from the UGI Corporation 2013 Omnibus Incentive Compensation Plan. The UGI Corporation 2013 Omnibus Incentive Compensation Plan was approved by shareholders on January 24, 2013.	
		
(3)	Represents 920,601 phantom share units under the UGI Corporation 2004 Omnibus Equity Compensation Plan Amended and Restated as of December 5, 2006 and the UGI Corporation 2013 Omnibus Incentive Compensation Plan.	
		
(4)	Weighted-average exercise price of outstanding options; excludes phantom share units.	
The information concerning the Company’s executive officers required by Item 10 is set forth below.
EXECUTIVE OFFICERS

	
					
Name	 	Age	 	Position	
John L. Walsh	 	58	 	President and Chief Executive Officer	
Kirk R. Oliver	 	55	 	Chief Financial Officer	
Davinder S. Athwal	 	46	 	Vice President - Accounting and Financial Control and Chief Risk Officer	
Jerry E. Sheridan	 	48	 	President and Chief Executive Officer, AmeriGas Propane, Inc.	
Robert F. Beard	 	48	 	President and Chief Executive Officer, UGI Utilities, Inc.	
Monica M. Gaudiosi	 	51	 	Vice President, General Counsel and Secretary	
Bradley C. Hall	 	60	 	Vice President - New Business Development	

All officers are elected for a one-year term at the organizational meetings of the respective Boards 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.

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John L. Walsh

Mr. Walsh is a Director and President (since 2005) and Chief Executive Officer (since 2013) of UGI Corporation. In addition, Mr. Walsh serves as Vice Chairman of AmeriGas Propane, Inc. (since 2005) and UGI Utilities, Inc. (since 2005). Previously, he also served as Chief Operating Officer of UGI Corporation (2005 to 2013) and as President and Chief Executive Officer of UGI Utilities, Inc. (2009 to 2011). Mr. Walsh was the Chief Executive of the Industrial and Special Products Division of the BOC Group plc, an industrial gases company, a position he assumed in 2001. He was also an Executive Director of BOC (2001 to 2005). He joined BOC in 1986 as Vice President-Special Gases and held various senior management positions in BOC, including President of Process Gas Solutions, North America (2000 to 2001) and President of BOC Process Plants (1996 to 2000). Mr. Walsh also serves as a Director of UGI Utilities, Inc. and AmeriGas Propane, Inc.

Kirk R. Oliver

Mr. Oliver is Chief Financial Officer of UGI (since October 2012). From December 2011 until September 2012, Mr. Oliver served as Senior Managing Director & Chief Operating Officer of InfraREIT Capital Partners, LLC, a partnership that invests in infrastructure assets, primarily electric transmission and gas pipeline assets. Prior to joining InfraREIT Capital, Mr. Oliver served as Senior Vice President and Chief Financial Officer of Allegheny Energy, Inc., an electric utility company, from 2008 to 2011, and as a Senior Executive at Hunt Power, LLC, a company that develops and invests in electric and gas utility projects, from 2007 to 2008. Mr. Oliver served in various positions at TXU Corp. (now Energy Future Holdings Corp.), an electricity distribution, generation and transmission company in Texas, from 1998 to 2006, including as Executive Vice President and Chief Financial Officer from 2004 to 2006, Senior Vice President, Finance from 2000 to 2003 and Vice President, Treasurer and Assistant Secretary from 1998 to 1999. Prior to joining TXU Corp., Mr. Oliver spent eleven years as an investment banker in the Global Power and Energy Group at Lehman Brothers and six years at Motorola Inc.

Davinder S. Athwal

Mr. Athwal is Vice President - Accounting and Financial Control and Chief Risk Officer (since January 2009). He previously served as the Global Mergers & Acquisitions Controller of Nortel Networks, Inc., a global supplier of telecommunications equipment and solutions from 2007 through 2008. Mr. Athwal served as Director, Global Revenue Governance for Nortel Networks, Inc. from 2006 through 2007. Mr. Athwal previously served in both accounting and risk management roles for IBM Corporation, a globally integrated innovation and technology company (2003 to 2006).

Jerry E. Sheridan

Mr. Sheridan is President, Chief Executive Officer and a Director of AmeriGas Propane, Inc. (since March 2012). Previously, he served as Vice President - Operations and Chief Operating Officer (2011 to 2012) and as Vice President - Finance and Chief Financial Officer (2005 to 2011) of AmeriGas Propane, Inc. Mr. Sheridan served as President and Chief Executive Officer (2003 to 2005) of Potters Industries, Inc., a global manufacturer of engineered glass materials and a wholly-owned subsidiary of PQ Corporation, a global producer of inorganic specialty chemicals. In addition, Mr. Sheridan served as Executive Vice President (2003 to 2005) and as Vice President and Chief Financial Officer (1999 to 2003) of PQ Corporation. Mr. Sheridan also serves on the Management Board of CP Kelco, a privately held company that provides innovative products and solutions through the use of nature-based chemistry.

Robert F. Beard

Mr. Beard is President and Chief Executive Officer of UGI Utilities, Inc. (since September 2011). He previously served as 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 Vice President, General Counsel and Secretary (since April 2012). She also serves as Vice President and Secretary of AmeriGas Propane, Inc. and UGI Utilities, Inc. (since April 2012). Prior to joining UGI, 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).

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Bradley C. Hall

Mr. Hall is Vice President - New Business Development (since October 1994). He also serves as President of UGI Enterprises, Inc. (since 1994) and UGI Energy Services, LLC (formerly known as UGI Energy Services, Inc.) (since 1995). He joined the Company in 1982 and held various positions in UGI Utilities, Inc., including Vice President - Marketing and Rates.

PART IV:

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 Internal Control over Financial Reporting
Report of Independent Registered Public Accounting Firm
Consolidated Balance Sheets as of September 30, 2013 and 2012
Consolidated Statements of Income for the years ended September 30, 2013 , 2012 and 2011
Consolidated Statements of Comprehensive Income for the years ended September 30, 2013 , 2012 and 2011
Consolidated Statements of Cash Flows for the years ended September 30, 2013 , 2012 and 2011
Consolidated Statements of Changes in Equity for the years ended September 30, 2013 , 2012 and 2011
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, 2013 , 2012 and 2011 
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	
2.1	Contribution and Redemption Agreement, dated October 15, 2011, by and among AmeriGas Partners, L.P., Energy Transfer Partners, L.P., Energy Transfer Partners GP, L.P. and Heritage ETC, L.P.	AmeriGas
Partners, L.P.	Form 8-K (10/15/11)	2.1	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
2.2	Amendment No. 1, dated as of December 1, 2011, to the Contribution and Redemption Agreement, dated as of October 15, 2011, by and among Energy Transfer Partners, L.P., Energy Transfer Partners GP, L.P., Heritage ETC, L.P. and AmeriGas Partners, L.P.	AmeriGas
Partners, L.P.	Form 8-K
(12/1/11)	2.1	
2.3	Amendment No. 2, dated as of January 11, 2012, to the Contribution and Redemption Agreement, dated as of October 15, 2012, by and among Energy Transfer Partners, L.P., Energy Transfer Partners GP, L.P., Heritage ETC, L.P. and AmeriGas Partners, L.P.	AmeriGas
Partners, L.P.	Form 8-K
(1/11/12)	2.1	
2.4	Letter Agreement, dated as of January 11, 2012, by and among Energy Transfer Partners, L.P., Energy Transfer Partners GP, L.P., Heritage ETC, L.P. and AmeriGas Partners, L.P.	AmeriGas
Partners, L.P.	Form 8-K
(1/11/12)	2.1	
2.5	Amendment to Contribution and Redemption Agreement, dated as of October 15, 2011, by an among Energy Transfer Partners, L.P., Energy Transfer Partners GP, L.P., Heritage ETC, L.P. and AmeriGas Partners, L.P., dated as of March 20, 2013.	AmeriGas
Partners, L.P.	Form 10-Q (3/31/13)	2.1	
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	Amended and Restated Bylaws of UGI Corporation.	UGI	Form 8-K (7/30/13)	3.1	
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)	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
4.3	UGI’s (Second) Amended and Restated Articles of Incorporation and Bylaws referred to in 3.1 and 3.2 above.	 	 	 	
4.4	Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, L.P. dated as of July 27, 2009.	AmeriGas
Partners, L.P.	Form 10-Q (6/30/09)	3.1	
4.5	Amendment No. 1 to Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, L.P. dated as of March 13, 2012.	AmeriGas
Partners, L.P.	Form 8-K
(3/14/12)	3.1	
4.6	Indenture, dated as of January 20, 2011, by and among AmeriGas Partners, L.P., AmeriGas Finance Corp. and U.S. Bank National Association, as trustee.	AmeriGas
Partners, L.P.	Form 10-Q (12/31/10)	4.1	
4.7	First Supplemental Indenture, dated as of January 20, 2011, to Indenture dated as of January 20, 2011, by and among AmeriGas Partners, L.P., AmeriGas Finance Corp. and U.S. Bank National Association, as trustee.	AmeriGas
Partners, L.P.	Form 8-K (1/19/11)	4.1	
4.8	Second Supplemental Indenture, dated as of August 10, 2011, to Indenture dated as of January 20, 2011, by and among AmeriGas Partners, L.P., AmeriGas Finance Corp. and U.S. Bank National Association, as trustee.	AmeriGas
Partners, L.P.	Form 8-K (8/10/11)	4.1	
4.9	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)	
4.10	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	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
4.11	Indenture, dated as of January 12, 2012, among AmeriGas Finance Corp., AmeriGas Finance LLC, AmeriGas Partners, L.P., as guarantor, and U.S. Bank National Association, as trustee.	AmeriGas
Partners, L.P.	Form 8-K
(1/12/12)	4.1	
4.12	First Supplemental Indenture, dated as of January 12, 2012, among AmeriGas Finance Corp., AmeriGas Finance LLC, AmeriGas Partners, L.P., as guarantor, and U.S. Bank National Association, as trustee.	AmeriGas
Partners, L.P.	Form 8-K
(1/12/12)	4.2	
4.13	Form of Fixed Rate Medium-Term Note.	Utilities	Form 8-K (8/26/94)	4(i)	
4.14	Form of Fixed Rate Series B Medium-Term Note.	Utilities	Form 8-K (8/1/96)	4(i)	
4.15	Form of Floating Rate Series B Medium-Term Note.	Utilities	Form 8-K (8/1/96)	4(ii)	
4.16	Officer’s Certificate establishing Medium-Term Notes Series.	Utilities	Form 8-K (8/26/94)	4(iv)	
4.17	Form of Officer’s Certificate establishing Series B Medium-Term Notes under the Indenture.	Utilities	Form 8-K (8/1/96)	4(iv)	
4.18	Form of Officers’ Certificate establishing Series C Medium-Term Notes under the Indenture.	Utilities	Form 8-K (5/21/02)	4.2	
4.19	Forms of Floating Rate and Fixed Rate Series C Medium-Term Notes.	Utilities	Form 8-K (5/21/02)	4.1	
4.20	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	
10.1**	UGI Corporation 2004 Omnibus Equity Compensation Plan Amended and Restated as of December 5, 2006.	UGI	Form 8-K (2/27/07)	10.1	
*10.2**	UGI Corporation 2004 Omnibus Equity Compensation Plan Amended and Restated as of December 5, 2006 - Terms and Conditions as amended and restated effective November, 2012.	 	 	 	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
10.3**	UGI Corporation 2013 Omnibus Incentive Compensation Plan.	UGI	Registration Statement No. 333-186178 (1/24/13)	99.1	
10.4**	UGI Corporation Senior Executive Employee Severance Plan, as amended and restated as of November 16, 2012.	UGI	Form 10-Q (6/30/13)	10.1	
10.5**	UGI Corporation Executive Employee Severance Plan, as amended and restated as of November 16, 2012.	UGI	Form 10-Q (6/30/13)	10.2	
10.6**	UGI Corporation Supplemental Executive Retirement Plan and Supplemental Savings Plan, as Amended and Restated effective January 1, 2009.	UGI	Form 10-K (9/30/09)	10.11	
10.7**	Amendment 2009-1 to the UGI Corporation Supplemental Executive Retirement Plan and Supplemental Savings Plan as Amended and Restated effective January 1, 2009.	UGI	Form 10-Q (12/31/09)	10.1	
10.8**	UGI Corporation 2009 Supplemental Executive Retirement Plan For New Employees.	UGI	Form 10-Q (12/31/09)	10.2	
10.9**	UGI Corporation Executive Annual Bonus Plan effective as of October 1, 2006, as amended November 16, 2012.	UGI	Form 10-Q (3/31/13)	10.14	
10.10**	AmeriGas Propane, Inc. 2010 Long-Term Incentive Plan on Behalf of AmeriGas Partners, L.P. effective July 30, 2010.	AmeriGas
Partners, L.P.	Form 8-K (7/30/10)	10.2	
10.11**	AmeriGas Propane, Inc. 2010 Long-Term Incentive Plan on Behalf of AmeriGas Partners, L.P. effective July 30, 2010 - Terms and Conditions.	AmeriGas
Partners, L.P.	Form 10-K (9/30/10)	10.10	
10.12**	AmeriGas Propane, Inc. 2010 Long-Term Incentive Plan on Behalf of AmeriGas Partners, L.P., Performance Unit Grant Letter for Employees dated January 1, 2013.	AmeriGas
Partners, L.P.	Form 10-Q
(3/31/13)	10.8	
10.13**	AmeriGas Propane, Inc. 2010 Long-Term Incentive Plan on Behalf of AmeriGas Partners, L.P., Phantom Unit Grant Letter for Directors, dated January 8, 2013.	AmeriGas
Partners, L.P.	Form 10-Q
(3/31/13)	10.7	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
10.14**	AmeriGas Propane, Inc. 2010 Long-Term Incentive Plan on Behalf of AmeriGas Partners, L.P., Phantom Unit Grant Letter for Employees, dated December 3, 2012.	AmeriGas
Partners, L.P.	Form 10-Q
(12/31/12)	10.1	
10.15**	UGI Corporation 2004 Omnibus Equity Compensation Plan Nonqualified Stock Option Grant Letter for Mr. R. Paul Grady dated January 17, 2012.	AmeriGas
Partners, L.P.	Form 10-Q
(3/31/12)	10.9	
*10.16**	UGI Corporation 2004 Omnibus Equity Compensation Plan Nonqualified Stock Option Grant Letter for Mr. Kirk R. Oliver dated October 1, 2012.	 	 	 	
*10.17**	UGI Corporation 2004 Omnibus Equity Compensation Plan Performance Unit Grant Letter for Mr. Kirk R. Oliver dated October 1, 2012.	 	 	 	
10.18**	Form of UGI Corporation 2004 Omnibus Equity Compensation Plan Performance Unit Grant Letter for Ms. Monica M. Gaudiosi for the 2010-12 Performance Period, dated as of April 23, 2012.	UGI	Form 10-K
(9/30/12)	10.20	
10.19**	Form of UGI Corporation 2004 Omnibus Equity Compensation Plan Performance Unit Grant Letter for Ms. Monica M. Gaudiosi for the 2011-13 Performance Period, dated as of April 23, 2012.	UGI	Form 10-K
(9/30/12)	10.21	
10.20**	AmeriGas Propane, Inc. Non-Qualified Deferred Compensation Plan, as Amended and Restated effective January 1, 2012.	AmeriGas
Partners, L.P.	Form 10-Q (3/31/12)	10.5	
10.21**	AmeriGas Propane, Inc. Senior Executive Employee Severance Plan, as amended and restated as of November 15, 2012.	AmeriGas
Partners, L.P.	Form 10-Q
(6/30/13)	10.1	
10.22**	AmeriGas Propane, Inc. Executive Employee Severance Plan, as amended and restated as of November 15, 2012.	AmeriGas
Partners, L.P.	Form 10-Q
(6/30/13)	10.2	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
10.23**	AmeriGas Propane, Inc. Supplemental Executive Retirement Plan, as Amended and Restated effective January 1, 2009.	AmeriGas
Partners, L.P.	Form 10-Q (12/31/09)	10.1	
10.24**	AmeriGas Propane, Inc. Executive Annual Bonus Plan, effective as of October 1, 2006, as amended November 15, 2012.	AmeriGas
Partners, L.P.	Form 10-Q (3/31/13)	10.9	
10.25**	UGI Utilities, Inc. Senior Executive Employee Severance Plan, as amended and restated as of November 16, 2012.	Utilities	Form 10-Q (6/30/13)	10.1	
10.26**	UGI Utilities, Inc. Executive Annual Bonus Plan, effective as of October 1, 2006, as amended as of November 16, 2012.	Utilities	Form 10-Q (3/31/13)	10.2	
10.27**	UGI Corporation 2013 Omnibus Incentive Compensation Plan, Performance Unit Grant Letter for Employees, dated January 24, 2013.	UGI	Form 10-Q (3/31/13)	10.4	
10.28**	UGI Corporation 2013 Omnibus Incentive Compensation Plan, Performance Unit Grant Letter for UGI Utilities Employees, dated January 24, 2013.	Utilities	Form 10-Q (3/31/13)	10.3	
10.29**	UGI Corporation 2004 Omnibus Equity Compensation Plan Stock Unit Grant Letter for Non Employee Directors, dated January 8, 2013.	UGI	Form 10-Q
(3/31/13)	10.6	
10.30**	UGI Corporation 2004 Omnibus Equity Compensation Plan Nonqualified Stock Option Grant Letter for Non Employee Directors, dated January 8, 2013.	UGI	Form 10-Q (3/31/13)	10.7	
10.31**	UGI Corporation 2004 Omnibus Equity Compensation Plan Nonqualified Stock Option Grant Letter for UGI Employees, dated January 1, 2013.	UGI	Form 10-Q
(3/31/13)	10.8	
10.32**	UGI Corporation 2004 Omnibus Equity Compensation Plan Nonqualified Stock Option Grant Letter for AmeriGas Employees, dated January 1, 2013.	UGI	Form 10-Q
(3/31/13)	10.9	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
10.33**	UGI Corporation 2004 Omnibus Equity Compensation Plan Nonqualified Stock Option Grant Letter for UGI Utilities Employees, dated January 1, 2013.	Utilities	Form 10-Q
(3/31/13)	10.1	
*10.34**	UGI Corporation 2013 Omnibus Incentive Compensation Plan Nonqualified Stock Option Grant Letter for Mr. John L. Walsh dated April 1, 2013.	 	 	 	
*10.35**	UGI Corporation 2013 Omnibus Incentive Compensation Plan Performance Unit Grant Letter for Mr. John L. Walsh dated April 1, 2013.	 	 	 	
10.36**	UGI Corporation 2009 Deferral Plan As Amended and Restated Effective June 1, 2010.	UGI	Form 10-Q (6/30/10)	10.1	
*10.37**	Description of oral compensation arrangements for Messrs. Walsh, Hall, and Oliver and Ms. Gaudiosi.	 	 	 	
10.38**	Description of oral compensation arrangement for Mr. Sheridan.	AmeriGas
Partners, L.P.	Form 10-K
(9/30/13)	10.34	
*10.39**	Summary of Director Compensation as of October 1, 2013.	 	 	 	
10.40**	Form of Change in Control Agreement Amended and Restated as of May 12, 2008 for Mr. Walsh.	UGI	Form 10-Q (6/30/08)	10.3	
10.41**	Change in Control Agreement for Monica M. Gaudiosi dated as of April 23, 2012.	UGI	Form 10-Q (6/30/12)	10.1	
10.42**	Change in Control Agreement for Kirk R. Oliver dated as of October 1, 2012.	UGI	Form 10-Q (12/31/12)	10.1	
10.43	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	
10.44	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	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
10.45	Credit Agreement dated as of June 21, 2011, as amended through and including Amendment No. 4 thereto dated April 18, 2012, 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 (“Agent”), Wells Fargo Securities, LLC, as Sole Lead Arranger and Sole Book Manager and the financial institutions from time to time party thereto.	AmeriGas Partners, L.P.	Form 10-K (9/30/12)	10.39	
10.46	Release of Liens and Termination of Security Documents dated as of November 6, 2006 by and among AmeriGas Propane, Inc., Petrolane Incorporated, AmeriGas Propane, L.P., AmeriGas Propane Parts & Service, Inc. and Wachovia Bank, National Association, as Collateral Agent for the Secured Creditors, pursuant to the Intercreditor and Agency Agreement dated as of April 19, 1995.	AmeriGas
Partners, L.P.	Form 10-K (9/30/06)	10.3	
10.47	Receivables Purchase Agreement, dated as of November 30, 2001, as amended through and including Amendment No. 8 thereto dated April 22, 2010 and Amendment No. 9 thereto dated August 26, 2010, by and among UGI Energy Services, Inc., as servicer, Energy Services Funding Corporation, as seller, Market Street Funding, LLC, as issuer, and PNC Bank, National Association, as administrator.	UGI	Form 10-K
(9/30/11)	10.47	
10.48	Amendment No. 10, dated as of April 21, 2011 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, Inc. as servicer, Energy Services Funding Corporation, as seller, Market Street Funding LLC, as issuer, and PNC Bank, National Association, as administrator.	UGI	Form 8-K (4/21/11)	 	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
10.49	Amendment No. 11, dated as of April 19, 2012, 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, Inc., as servicer, Energy Services Funding Corporation, as seller, Market Street Funding LLC, as issuer, and PNC Bank, National Association, as administrator.	UGI	Form 8-K
(4/19/12)	10.1	
10.50	Amendment No. 12, dated as of April 18, 2013, 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, Inc., as servicer, Energy Services Funding Corporation, as seller, Market Street Funding LLC, as issuer, and PNC Bank, National Association, as administrator.	 UGI	Form 8-K (4/18/13)	10.1	
10.51	Credit Agreement, dated as of May 25, 2011 among UGI Utilities, Inc., as borrower, and PNC Bank, National Association, as administrative agent, Citizens Bank of Pennsylvania, as syndication agent, PNC Capital Markets LLC and RBS Citizens, N.A., as joint lead arrangers and joint bookrunners, and PNC Bank, National Association, Citizens Bank of Pennsylvania, Citibank, N.A., Credit Suisse AG, Cayman Islands Branch, JPMorgan Chase Bank, N.A., Wells Fargo Bank, National Association, The Bank of New York Mellon, and the other financial institutions from time to time parties thereto.	Utilities	Form 8-K (5/25/11)	10.1	
10.52	Purchase and Sale Agreement, dated as of November 30, 2001, as amended through and including Amendment No. 3 thereto dated August 26, 2010, by and between UGI Energy Services, Inc. and Energy Services Funding Corporation.	UGI	Form 10-K (9/30/10)	10.47	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
10.53	Amended and Restated Credit Agreement, dated as of December 18, 2012, among UGI Energy Services, Inc., as borrower, and 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 (12/18/12)	10.1	
10.54	Amendment No. 1, dated as of March 15, 2013, to Amended and Restated Credit Agreement, dated as of December 18, 2012, among UGI Energy Services, Inc., as borrower, and 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 10-Q (3/31/13)	10.1	
10.55	Senior Facilities Agreement dated March 16, 2011 by and among AGZ Holding, as Parent and Borrower, Antargaz, as Borrower, BNP Paribas, Caisse Régionale de Crédit Agricole Mutuel de Paris et d’Ile de France, Credit Lyonnais and Natixis, as Mandated Lead Arrangers and Bookrunners, Barclays Bank PLC, Banque Commerciale pour le Marché de l’Entreprise and ING Belgium SA, Succursale en France, as Mandated Lead Arrangers, Natixis, as Facility Agent and Security Agent, Banco Bilbao Vizcaya Argentaria, Crédit du Nord, HSBC France, Crédit Suisse International, Bred Banque Populaire and Banque Palatine, as Arrangers and the Financial Institutions named therein.	UGI	Form 10-Q (3/31/11)	10.1	
10.56	Pledge of Financial Instruments Account relating to Financial Instruments held by AGZ Holding in Antargaz, dated March 16, 2011, by and among AGZ Holding, as Pledgor, Natixis, as Security Agent and Bank Account Holder, and the Lenders, as Beneficiaries.	UGI	Form 10-Q (3/31/11)	10.2	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
10.57	Pledge of Financial Instruments Account relating to Financial Instruments held by Antargaz in certain subsidiary companies, dated March 16, 2011, by and among Antargaz, as Pledgor, Natixis, as Security Agent and Bank Account Holder, and the Lenders, as Beneficiaries.	UGI	Form 10-Q (3/31/11)	10.3	
10.58	Master Agreement for Assignment of Receivables dated March 16, 2011 between AGZ Holding, as Assignor, Natixis, as Security Agent, and the Beneficiaries.	UGI	Form 10-Q (3/31/11)	10.4	
10.59	Master Agreement for Assignment of Receivables dated March 16, 2011 between Antargaz, as Assignor, Natixis, as Security Agent, and the Beneficiaries.	UGI	Form 10-Q (3/31/11)	10.5	
10.60	First Demand Guarantee dated March 16, 2011 by UGI Corporation in favor of Natixis and the Lenders set forth in the Senior Facilities Agreement dated March 16, 2011.	UGI	Form 10-Q (3/31/11)	10.6	
10.61	FSS Service Agreement No. 79028 dated March 29, 2012 between Columbia Gas Transmission, LLC and UGI Utilities, Inc.	Utilities	Form 10-Q
(3/31/12)	10.2	
10.62	Firm Storage and Delivery Service Agreement (Rate GSS) dated July 1, 1996 between Transcontinental Gas Pipe Line Corporation and PG Energy.	Utilities	Form 8-K
(8/24/06)	10.8	
10.63	Service Agreement For Use Under Seller’s GSS Rate Schedule dated July 9, 2012 between Transcontinental Gas Pipe Line Company, LLC and UGI Penn Natural Gas, Inc.	Utilities	Form 10-Q (6/30/12)	10.1	
10.64	SST Service Agreement No. 79133 dated March 29, 2012 between Columbia Gas Transmission, LLC and UGI Utilities, Inc.	Utilities	Form 10-Q
(3/31/12)	10.1	
10.65	Letter Agreement, dated as of June 10, 2013, amending SST Service Agreement No. 79133, dated March 29, 2012, between Columbia Gas Transmission, LLC and UGI Utilities, Inc.	Utilities	Form 10-Q (6/30/13)	10.3	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
10.66	FTS Service Agreement No. 46284 dated November 1, 1993, as amended by that certain letter agreement dated May 5, 2004, between Columbia Transmission Corporation and UGI Utilities, Inc.	Utilities	Form 10-Q
(3/31/11)	10.2	
10.67	FTS Service Agreement No. 46284, dated July 23, 2013, between Columbia Gas Transmission, LLC and UGI Utilities, Inc.	Utilities	Form 8-K (7/23/13)	10.1	
10.68	Contingent Residential Support Agreement dated as of January 12, 2012, among Energy Transfer Partners, L.P., AmeriGas Finance LLC, AmeriGas Finance Corp., AmeriGas Partners, L.P., and for certain limited purposes only, UGI Corporation.	AmeriGas
Partners, L.P.	Form 8-K
(1/11/12)	10.1	
10.69	Amendment to Contingent Residual Support Agreement dated as of January 12, 2012, among Energy Transfer Partners, L.P., AmeriGas Finance LLC, AmeriGas Finance Corp., AmeriGas Partners, L.P., and for certain limited purposes only, UGI Corporation, dated as of March 20, 2013.	AmeriGas
Partners, L.P.	Form 10-Q (3/31/13)	10.1	
10.70	Unitholder Agreement, dated as of January 12, 2012, by and among Heritage ETC, L.P., AmeriGas Partners, L.P., and, for limited purposes, Energy Transfer Partners, L.P., Energy Transfer Partners GP, L.P., and Energy Transfer Equity, L.P.	AmeriGas
Partners, L.P.	Form 8-K
(1/11/12)	10.2	
10.71	Term Loan Credit Agreement dated September 23, 2013 by and between UGI Utilities, Inc. and JPMorgan Chase Bank, N.A., as administrative agent.	Utilities	Form 8-K (9/23/13)	10.1	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
*10.72	Amendment No. 13, dated as of October 1, 2013, 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, Market Street Funding LLC, as issuer, and PNC Bank, National Association, as administrator.	 	 	 	
*10.73	Amendment No. 4 dated as of October 1, 2013 to Purchase and Sale Agreement dated as of November 30, 2001 by and between UGI Energy Services, LLC and Energy Services Funding Corporation.	 	 	 	
*10.74	Amendment No. 14, dated as of October 1, 2013, 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, Market Street Funding LLC, as issuer, and PNC Bank, National Association, as administrator.	 	 	 	
14	Code of Ethics for principal executive, financial and accounting officers.	UGI	Form 10-K (9/30/03)	14	
*21	Subsidiaries of the Registrant.	 	 	 	
*23	Consent of PricewaterhouseCoopers 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, 2013 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, 2013 pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.	 	 	 	

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Incorporation by Reference	
Exhibit No.	Exhibit	Registrant	Filing	Exhibit	
*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, 2013, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.	 	 	 	
*101.INS	XBRL.Instance	 	 	 	
*101.SCH	XBRL Taxonomy Extension Schema	 	 	 	
*101.CAL	XBRL Taxonomy Extension Calculation Linkbase	 	 	 	
*101.DEF	XBRL Taxonomy Extension Definition Linkbase	 	 	 	
*101.LAB	XBRL Taxonomy Extension Labels Linkbase	 	 	 	
*101.PRE	XBRL Taxonomy Extension Presentation Linkbase	 	 	 	

*	Filed herewith.	
		
**	As required by Item 15(a)(3), this exhibit is identified as a compensatory plan or arrangement.	

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SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized.

	

 	 	UGI CORPORATION
	
Date:	December 16, 2013	By:  	/s/ Kirk R. Oliver	
 	 	 	Kirk R. Oliver
Chief Financial Officer 	

Pursuant to the requirements of the Securities Exchange Act of 1934, this Report has been signed below on December 16, 2013 , by the following persons on behalf of the Registrant in the capacities indicated.

	
			
Signature	 	Title	
 	 	 	
/s/ John L. Walsh	 	Chief Executive Officer
(Principal Executive Officer) and Director	
John L. Walsh	 		
 	 	 	
/s/ Kirk R. Oliver	 	Chief Financial Officer (Principal Financial Officer)	
Kirk R. Oliver	 		
 	 	 	
/s/ Davinder S. Athwal	 	Vice President — Accounting and Financial Control,
Chief Risk Officer (Principal Accounting Officer)	
Davinder S. Athwal	 		
 	 	 	
/s/ Lon R. Greenberg	 	Chairman and Director	
Lon R. Greenberg	 		
 	 	 	
/s/ Richard W. Gochnauer	 	Director	
Richard W. Gochnauer	 		
 	 	 	
/s/ Frank S. Hermance	 	Director	
Frank S. Hermance	 		
 	 	 	
/s/ Ernest E. Jones	 	Director	
Ernest E. Jones	 		
 	 	 	
/s/ Anne Pol	 	Director	
Anne Pol	 		
 	 	 	
/s/ M. Shawn Puccio	 	Director	
M. Shawn Puccio	 	 	
 	 	 	
/s/ Marvin O. Schlanger	 	Director	
Marvin O. Schlanger	 		
 	 	 	
/s/ Roger B. Vincent	 	Director	
Roger B. Vincent	 		

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UGI CORPORATION AND SUBSIDIARIES
FINANCIAL INFORMATION
FOR INCLUSION IN ANNUAL REPORT ON FORM 10-K
YEAR ENDED SEPTEMBER 30, 2013

F-1

Table of Contents

UGI CORPORATION
INDEX TO FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES

	
		
 	Pages	
 	 	
Management’s Annual Report on Internal Control over Financial Reporting	F-3	
 	 	
Financial Statements:	 	
 	 	
Report of Independent Registered Public Accounting Firm	F-5	
 	 	
Consolidated Balance Sheets as of September 30, 2013 and 2012	F-6	
 	 	
Consolidated Statements of Income for the years ended September 30, 2013, 2012 and 2011	F-7	
 	 	
Consolidated Statements of Comprehensive Income for the years ended September 30, 2013, 2012 and 2011	F-8	
 	 	
Consolidated Statements of Cash Flows for the years ended September 30, 2013, 2012 and 2011	F-9	
 	 	
Consolidated Statements of Changes in Equity for the years ended September 30, 2013, 2012 and 2011	F-10	
 	 	
Notes to Consolidated Financial Statements	F-11	
 	 	
Financial Statement Schedules:	 	
 	 	
For the years ended September 30, 2013, 2012 and 2011:	 	
 	 	
I — Condensed Financial Information of Registrant (Parent Company)	S-1	
 	 	
II — Valuation and Qualifying Accounts	S-4	

We have omitted all other financial statement schedules because the required information is either (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.

F-2

Table of Contents

Report of Management
Financial Statements
The Company’s consolidated financial statements and other financial information contained in this Annual Report are prepared by management, which is responsible for their fairness, integrity and objectivity. The consolidated financial statements and related information were prepared in accordance with accounting principles generally accepted in the United States of America and include amounts that are based on management’s best judgments and estimates.
The Audit Committee of the Board of Directors is composed of three members, none of whom is an employee of the Company. This Committee is responsible for (i) overseeing the financial reporting process and the adequacy of internal control and (ii) monitoring the independence and performance of the Company’s independent registered public accounting firm and internal auditors. The Committee is also responsible for maintaining direct channels of communication among the Board of Directors, management, and both the independent registered public accounting firm and the internal auditors.
PricewaterhouseCoopers LLP, our independent registered public accounting firm, is engaged to perform audits of our consolidated financial statements. These audits are performed in accordance with the standards of the Public Company Accounting Oversight Board (United States). Our independent registered public accounting firm was given unrestricted access to all financial records and related data, including minutes of all meetings of the Board of Directors and committees of the Board. The Company believes that all representations made to the independent registered public accounting firm during their audits were valid and appropriate.
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, using the criteria in Internal Control - Integrated Framework (1992), issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO Framework”).

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 accounting principles generally accepted in the United States of America (“GAAP”) and includes policies and procedures that, among other things, provide reasonable assurance that assets are safeguarded and that transactions are executed in accordance with management’s authorization and are properly recorded to permit the preparation of reliable financial information.

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.

A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of the Company’s annual or interim financial statements will not be prevented or detected on a timely basis.

We did not maintain effective controls over our accounting for commodity derivative instruments. Specifically, controls were not designed effectively to provide reasonable assurance that commodity derivative instruments were accounted for in accordance with GAAP. The material weakness resulted in errors in the recording of certain commodity derivative transactions as cash flow hedges. As a result of the error, the Company misstated other comprehensive income, non-utility revenues and non-utility cost of sales, requiring the Company to restate its financial statements for the fiscal quarters ended March 31, 2013, June 30, 2012 and December 31, 2011 and revise its financial statements for the fiscal years ended September 30, 2012 and 2011 and the quarters ended June 30, 2013, December 31, 2012, and March 31, 2012.  Additionally, this material weakness could result in misstatements of the aforementioned accounts and disclosures that would result in a material misstatement of the consolidated financial statements that would not be prevented or detected.

Because of this material weakness, management concluded that the Company did not maintain effective internal control over financial reporting as of September 30, 2013 based on criteria in the COSO Framework.

F-3

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The Company’s independent registered public accounting firm, PricewaterhouseCoopers LLP, has issued its report on the effectiveness of the Company’s internal control over financial reporting as of September 30, 2013 , which appears herein.

/s/ John L. Walsh
Chief Executive Officer

/s/ Kirk R. Oliver
Chief Financial Officer

/s/ Davinder S. Athwal
Chief Accounting Officer

F-4

Table of Contents

Report of Independent Registered Public Accounting Firm
To the Board of Directors and Stockholders of UGI Corporation:
In our opinion, the accompanying consolidated balance sheets and the related consolidated statements of income, of comprehensive income, of changes in equity and of cash flows present fairly, in all material respects, the financial position of UGI Corporation and its subsidiaries at September 30, 2013 and 2012 , and the results of their operations and their cash flows for each of the three years in the period ended September 30, 2013 in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedules listed in the index appearing under Item 15 (a)(2) present fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements. Also in our opinion, the Company did not maintain, in all material respects, effective internal control over financial reporting as of September 30, 2013 , based on criteria established in Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO 1992) because a material weakness in internal control over financial reporting related to commodity derivative accounting existed as of that date. A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of the annual or interim financial statements will not be prevented or detected on a timely basis. The material weakness referred to above is described in the accompanying Management’s Annual Report on Internal Control over Financial Reporting. We considered this material weakness in determining the nature, timing, and extent of audit tests applied in our audit of the September 30, 2013 consolidated financial statements, and our opinion regarding the effectiveness of the Company’s internal control over financial reporting does not affect our opinion on those consolidated financial statements. The Company’s management is responsible for these financial statements and financial statement schedules, for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in management’s report referred to above. Our responsibility is to express opinions on these financial statements, on the financial statement schedules, and on the Company’s internal control over financial reporting based on our integrated audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.
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 (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) 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 (iii) 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/ PricewaterhouseCoopers LLP
Philadelphia, Pennsylvania
December 16, 2013

F-5

Table of Contents

UGI CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Millions of dollars)

								
 	September 30,	
 	2013	 	2012	
 	 	 	Revised (See Note 3)	
ASSETS	 	 	 	
Current assets	 	 	 	
Cash and cash equivalents	$	389.3		 	$	319.9		
Restricted cash	8.3		 	3.0		
Accounts receivable (less allowances for doubtful accounts of $39.5 and $36.1, respectively)	745.6		 	627.5		
Accrued utility revenues	18.9		 	16.9		
Inventories	365.5		 	354.1		
Deferred income taxes	10.6		 	29.8		
Utility regulatory assets	8.2		 	6.5		
Derivative financial instruments	23.8		 	13.2		
Prepaid expenses and other current assets	57.1		 	99.5		
Total current assets	1,627.3		 	1,470.4		
Property, plant and equipment	 	 	 	
Utilities	2,427.8		 	2,295.7		
Non-utility	4,612.7		 	4,223.9		
 	7,040.5		 	6,519.6		
Accumulated depreciation and amortization	(2,560.3	)	 	(2,285.2	)	
Net property, plant, and equipment	4,480.2		 	4,234.4		
Goodwill	2,873.7		 	2,818.3		
Intangible assets, net	607.9		 	658.2		
Other assets	419.7		 	495.6		
Total assets	$	10,008.8		 	$	9,676.9		
LIABILITIES AND EQUITY	 	 	 	
Current liabilities	 	 	 	
Current maturities of long-term debt	$	67.2		 	$	166.7		
Bank loans	227.9		 	165.1		
Accounts payable	472.3		 	409.9		
Employee compensation and benefits accrued	97.0		 	89.7		
Deposits and advances	205.2		 	252.8		
Derivative financial instruments	30.0		 	100.9		
Accrued interest	60.6		 	71.6		
Other current liabilities	264.7		 	225.6		
Total current liabilities	1,424.9		 	1,482.3		
Debt and other liabilities	 	 	 	
Long-term debt	3,542.2		 	3,347.6		
Deferred income taxes	962.3		 	905.7		
Deferred investment tax credits	4.3		 	4.6		
Other noncurrent liabilities	527.2		 	621.3		
Total liabilities	6,460.9		 	6,361.5		
Commitments and contingencies (Note 16)		 		
Equity:	 	 	 	
UGI Corporation stockholders’ equity:	 	 	 	
UGI Common Stock, without par value (authorized - 300,000,000 shares; issued - 115,783,794 and 115,624,594 shares, respectively)	1,208.1		 	1,157.7		
Retained earnings	1,308.3		 	1,156.0		
Accumulated other comprehensive income (loss)	8.4		 	(55.2	)	
Treasury stock, at cost	(32.3	)	 	(28.7	)	
Total UGI Corporation stockholders’ equity	2,492.5		 	2,229.8		
Noncontrolling interests, principally in AmeriGas Partners	1,055.4		 	1,085.6		
Total equity	3,547.9		 	3,315.4		
Total liabilities and equity	$	10,008.8		 	$	9,676.9		

See accompanying notes to consolidated financial statements.

F-6

Table of Contents

UGI CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(Millions of dollars, except per share amounts)

	
												
 	Year Ended September 30,	
 	2013	 	2012	 	2011	
 	 	 	 Revised (See Note 3)	 	Revised (See Note 3)	
Revenues	 	 	 	 	 	
Utilities	$	939.0		 	$	882.5		 	$	1,135.5		
Non-utility	6,255.7		 	5,638.8		 	4,955.4		
 	7,194.7		 	6,521.3		 	6,090.9		
Costs and Expenses	 	 	 	 	 	
Cost of sales (excluding depreciation shown below):	 	 	 	 	 	
Utilities	466.0		 	459.1		 	678.5		
Non-utility	3,858.4		 	3,640.0		 	3,304.2		
Operating and administrative expenses	1,692.0		 	1,591.1		 	1,267.0		
Utility taxes other than income taxes	16.9		 	17.3		 	16.6		
Depreciation	301.4		 	263.2		 	201.0		
Amortization	61.7		 	51.8		 	26.7		
Other income, net	(32.8	)	 	(39.8	)	 	(45.5	)	
 	6,363.6		 	5,982.7		 	5,448.5		
Operating income	831.1		 	538.6		 	642.4		
Loss from equity investees	(0.4	)	 	(0.3	)	 	(0.9	)	
Loss on extinguishments of debt	—		 	(13.3	)	 	(38.1	)	
Interest expense	(240.3	)	 	(220.4	)	 	(138.0	)	
Income before income taxes	590.4		 	304.6		 	465.4		
Income taxes	(162.8	)	 	(106.9	)	 	(145.4	)	
Net income	427.6		 	197.7		 	320.0		
(Deduct net income) add net loss attributable to noncontrolling interests, principally in AmeriGas Partners	(149.5	)	 	12.5		 	(74.6	)	
Net income attributable to UGI Corporation	$	278.1		 	$	210.2		 	$	245.4		
Earnings per common share attributable to UGI Corporation stockholders:	 	 	 	 	 	
Basic	$	2.44		 	$	1.87		 	$	2.20		
Diluted	$	2.41		 	$	1.85		 	$	2.17		
Average common shares outstanding (thousands):	 	 	 	 	 	
Basic	113,923		 	112,581		 	111,674		
Diluted	115,521		 	113,432		 	112,944		

See accompanying notes to consolidated financial statements.

F-7

Table of Contents

UGI CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Millions of dollars)

	
												
 	Year Ended September 30,	
 	2013	 	2012	 	2011	
 	 	 	Revised (See Note 3)	 	Revised (See Note 3)	
Net income	$	427.6		 	$	197.7		 	$	320.0		
Net gains (losses) on derivative instruments (net of tax of $(7.2), $29.3 and $5.0, respectively)	14.4		 	(105.4	)	 	3.9		
Reclassifications of net losses (gains) on derivative instruments (net of tax of $(10.3), $(14.6) and $1.5, respectively)	53.5		 	56.3		 	(19.0	)	
Foreign currency translation adjustments (net of tax of $(6.6), $2.8 and $4.5, respectively)	28.8		 	(20.6	)	 	(14.0	)	
Foreign currency gains and (losses) on long-term intra-company transactions (net of tax of $(0.8), $0.7 and $0.4, respectively)	3.2		 	(1.7	)	 	(0.8	)	
Benefit plans (net of tax of $(3.8), $6.0 and $(0.1), respectively)	5.3		 	(11.5	)	 	0.1		
Reclassifications of benefit plans actuarial losses and prior service costs to net income (net of tax of $(0.8), $(0.5) and $(0.4), respectively)	1.2		 	0.7		 	0.6		
Other comprehensive income (loss)	106.4		 	(82.2	)	 	(29.2	)	
Comprehensive income	534.0		 	115.5		 	290.8		
(Deduct comprehensive income) add comprehensive loss attributable to noncontrolling interests, principally in AmeriGas Partners	(192.3	)	 	38.6		 	(69.1	)	
Comprehensive income attributable to UGI Corporation	$	341.7		 	$	154.1		 	$	221.7		

See accompanying notes to consolidated financial statements.

F-8

Table of Contents

UGI CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Millions of dollars)

	
												
 	Year Ended September 30,	
 	2013	 	2012	 	2011	
 	 	 	Revised (See Note 3)	 	Revised (See Note 3)	
CASH FLOWS FROM OPERATING ACTIVITIES	 	 	 	 	 	
Net income	$	427.6		 	$	197.7		 	$	320.0		
Adjustments to reconcile net income to net cash provided by operating activities:	 	 	 	 	 	
Depreciation and amortization	363.1		 	315.0		 	227.7		
Deferred income taxes, net	48.7		 	90.2		 	91.5		
Provision for uncollectible accounts	30.2		 	26.5		 	20.0		
Stock-based compensation expense	17.6		 	14.5		 	15.6		
Unrealized gains on derivative instruments	(0.2	)	 	(17.2	)	 	(19.6	)	
Loss on extinguishments of debt	—		 	13.3		 	38.1		
Other, net	(41.4	)	 	(11.0	)	 	4.3		
Net change in:	 	 	 	 	 	
Accounts receivable and accrued utility revenues	(110.8	)	 	65.5		 	(66.0	)	
Inventories	4.6		 	89.2		 	(40.7	)	
Utility deferred fuel costs, net of changes in unsettled derivatives	9.3		 	(8.2	)	 	12.8		
Accounts payable	38.7		 	(78.7	)	 	19.2		
Other current assets	36.3		 	(12.5	)	 	(1.9	)	
Other current liabilities	(22.2	)	 	23.4		 	(66.3	)	
Net cash provided by operating activities	801.5		 	707.7		 	554.7		
CASH FLOWS FROM INVESTING ACTIVITIES	 	 	 	 	 	
Expenditures for property, plant and equipment	(486.0	)	 	(339.4	)	 	(360.7	)	
Acquisitions of businesses, net of cash acquired	(78.9	)	 	(1,580.5	)	 	(52.5	)	
(Increase) decrease in restricted cash	(5.3	)	 	14.2		 	17.6		
Other, net	16.9		 	1.2		 	(19.8	)	
Net cash used by investing activities	(553.3	)	 	(1,904.5	)	 	(415.4	)	
CASH FLOWS FROM FINANCING ACTIVITIES	 	 	 	 	 	
Dividends on UGI Common Stock	(125.8	)	 	(119.1	)	 	(113.8	)	
Distributions on AmeriGas Partners publicly held Common Units	(226.5	)	 	(181.7	)	 	(93.7	)	
Issuances of debt	227.1		 	1,550.2		 	1,480.6		
Repayments of debt	(168.7	)	 	(299.9	)	 	(1,383.6	)	
Receivables Facility net borrowings (repayments)	30.0		 	(14.3	)	 	2.2		
Increase (decrease) in bank loans	32.3		 	41.7		 	(74.6	)	
Issuances of UGI Common Stock	36.4		 	23.2		 	27.3		
Issuances of AmeriGas Partners Common Units	—		 	276.6		 	—		
Other	9.1		 	1.8		 	3.5		
Net cash (used) provided by financing activities	(186.1	)	 	1,278.5		 	(152.1	)	
EFFECT OF EXCHANGE RATE CHANGES ON CASH	7.3		 	(0.3	)	 	(9.4	)	
Cash and cash equivalents increase (decrease) 	$	69.4		 	$	81.4		 	$	(22.2	)	
Cash and cash equivalents:	 	 	 	 	 	
End of year	$	389.3		 	$	319.9		 	$	238.5		
Beginning of year	319.9		 	238.5		 	260.7		
Increase (decrease)	$	69.4		 	$	81.4		 	$	(22.2	)	
SUPPLEMENTAL CASH FLOW INFORMATION:	 	 	 	 	 	
Cash paid for:	 	 	 	 	 	
Interest	$	243.6		 	$	168.8		 	$	135.0		
Income taxes	$	60.0		 	$	33.3		 	$	48.6		

See accompanying notes to consolidated financial statements.

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Table of Contents

UGI CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(Millions of dollars, except per share amounts)

												
 	Year Ended September 30,	
 	2013	 	2012	 	2011	
 	 	 	Revised (See Note 3)	 	Revised (See Note 3)	
Common stock, without par value	 	 	 	 	 	
Balance, beginning of year	$	1,157.7		 	$	937.4		 	$	906.1		
Common Stock issued:	 	 	 	 	 	
Employee and director plans	29.7		 	13.6		 	14.7		
Dividend reinvestment plan	1.4		 	2.2		 	2.2		
Excess tax benefits realized on equity-based compensation	9.4		 	1.8		 	3.8		
Stock-based compensation expense	9.9		 	8.3		 	10.6		
Adjustments to reflect change in ownership of AmeriGas Partners, net of tax	—		 	194.4		 	—		
Balance, end of year	$	1,208.1		 	$	1,157.7		 	$	937.4		
Retained earnings	 	 	 	 	 	
Balance, beginning of year	$	1,156.0		 	$	1,064.9		 	$	933.3		
Net income attributable to UGI Corporation	278.1		 	210.2		 	245.4		
Cash dividends on Common Stock ($1.105, $1.06 and $1.02 per share, respectively)	(125.8	)	 	(119.1	)	 	(113.8	)	
Balance, end of year	$	1,308.3		 	$	1,156.0		 	$	1,064.9		
Accumulated other comprehensive income (loss)	 	 	 	 	 	
Balance, beginning of year	$	(55.2	)	 	$	(1.0	)	 	$	22.8		
Net gains (losses) on derivative instruments, net of tax	9.8		 	(45.6	)	 	(8.7	)	
Reclassification of net losses (gains) on derivative instruments, net of tax	15.3		 	22.6		 	(1.0	)	
Benefit plans, principally actuarial gains (losses), net of tax	5.3		 	(11.5	)	 	0.1		
Reclassification of benefit plans actuarial losses and prior service costs, net of tax, to net income	1.2		 	0.7		 	0.6		
Adjustments to reflect change in ownership of AmeriGas Partners, net of tax	—		 	1.9		 	—		
Foreign currency gains (losses) on long-term intra-company transactions, net of tax	3.2		 	(1.7	)	 	(0.8	)	
Foreign currency translation adjustments, net of tax	28.8		 	(20.6	)	 	(14.0	)	
Balance, end of year	$	8.4		 	$	(55.2	)	 	$	(1.0	)	
Treasury stock	 	 	 	 	 	
Balance, beginning of year	$	(28.7	)	 	$	(27.8	)	 	$	(38.2	)	
Common Stock issued:	 	 	 	 	 	
Employee and director plans	35.2		 	6.4		 	9.7		
Dividend reinvestment plan	0.8		 	0.9		 	0.7		
Reacquired common stock - employee and director plans	(39.6	)	 	(8.2	)	 	—		
Balance, end of year	$	(32.3	)	 	$	(28.7	)	 	$	(27.8	)	
Total UGI Corporation stockholders’ equity	$	2,492.5		 	$	2,229.8		 	$	1,973.5		
Noncontrolling interests	 	 	 	 	 	
Balance, beginning of year	$	1,085.6		 	$	213.0		 	$	237.4		
Net income (loss) attributable to noncontrolling interests, principally in AmeriGas Partners	149.5		 	(12.5	)	 	74.6		
Net gains (losses) on derivative instruments	4.6		 	(59.8	)	 	12.6		
Reclassification of net losses (gains) on derivative instruments	38.2		 	33.7		 	(18.1	)	
Dividends and distributions	(226.7	)	 	(182.1	)	 	(94.0	)	
AmeriGas Partners Common Unit public offering	—		 	276.6		 	—		
AmeriGas Partners Common Units issued for Heritage Acquisition	—		 	1,132.6		 	—		
Adjustments to reflect change in ownership of AmeriGas Partners	—		 	(321.4	)	 	—		
Other	4.2		 	5.5		 	0.5		
Balance, end of year	$	1,055.4		 	$	1,085.6		 	$	213.0		
Total equity	$	3,547.9		 	$	3,315.4		 	$	2,186.5		
See accompanying notes to consolidated financial statements.

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Table of Contents

UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Index to Notes
Note 1 — Nature of Operations
Note 2 — Significant Accounting Policies
Note 3 — Revisions and Restatements of Consolidated Financial Statements
Note 4 — Accounting Changes
Note 5 — Acquisitions
Note 6 — Debt
Note 7 — Income Taxes
Note 8 — Employee Retirement Plans
Note 9 — Utility Regulatory Assets and Liabilities and Regulatory Matters
Note 10 — Inventories
Note 11 — Property, Plant and Equipment
Note 12 — Goodwill and Intangible Assets
Note 13 — Series Preferred Stock
Note 14 — Common Stock and Equity-Based Compensation
Note 15 — Partnership Distributions and Common Unit Offerings
Note 16 — Commitments and Contingencies
Note 17 — Fair Value Measurements
Note 18 — Disclosures About Derivative Instruments and Hedging Activities
Note 19 — Energy Services Accounts Receivable Securitization Facility
Note 20 — Other Income, Net
Note 21 — Quarterly Data (unaudited)
Note 22 — Segment Information

Note 1 — Nature of Operations
UGI Corporation (“UGI”) is a holding company that, through subsidiaries and affiliates, distributes, stores, transports and markets energy products and related services. In the United States, we (1) are the general partner and own limited partner interests in a retail propane marketing and distribution business; (2) own and operate natural gas and electric distribution utilities; (3) own all or a portion of electricity generation facilities; (4) own and operate an energy marketing, midstream infrastructure, storage and energy services business; and (5) own and operate heating, ventilation, air conditioning and electrical contracting businesses. Internationally, we market and distribute propane and other liquefied petroleum gases (“LPG”) in Europe and China. We refer to UGI and its consolidated subsidiaries collectively as “the Company” or “we.”
We conduct a domestic propane marketing and distribution business through AmeriGas Partners, L.P. (“AmeriGas Partners”), a publicly traded limited partnership, its principal operating subsidiary AmeriGas Propane, L.P. (“AmeriGas OLP”) and, prior to its merger with AmeriGas OLP on July 1, 2013, AmeriGas OLP’s principal operating subsidiary Heritage Operating, L.P. (“HOLP”). In addition, from January 12, 2012, through the date of its merger with and into AmeriGas OLP in August 2012, we also conducted business through AmeriGas OLP’s operating subsidiary, Titan Propane LLC (“Titan LLC”). HOLP and Titan LLC (collectively, “Heritage Propane”) were acquired on January 12, 2012, from Energy Transfer Partners, L.P. (“ETP”) (see Note 5 for additional information about the acquisition of Heritage Propane). AmeriGas OLP along with HOLP and Titan LLC (prior to their mergers with and into AmeriGas OLP) are referred to herein as the “Operating Partnership.” AmeriGas Partners and AmeriGas OLP are Delaware limited partnerships. UGI’s wholly owned second-tier subsidiary AmeriGas Propane, Inc. (the “General Partner”) serves as the general partner of AmeriGas Partners and AmeriGas OLP. We refer to AmeriGas Partners and its subsidiaries together as “the Partnership” and the General Partner and its subsidiaries, including the Partnership, as “AmeriGas Propane.” At September 30, 2013 , the General Partner held a 1% general partner interest and 25.3% limited partner interest in AmeriGas Partners, and held an effective 27.1% ownership interest in AmeriGas OLP. Our limited partnership interest in AmeriGas Partners comprises 23,756,882 AmeriGas Partners Common Units (“Common Units”). The remaining 73.7% interest in AmeriGas Partners comprises 47,000,295  Common Units held by the public and 22,067,362 Common Units held by a subsidiary of ETP as a result of the acquisition of Heritage Propane.
Our wholly owned subsidiary, UGI Enterprises, Inc. (“Enterprises”), through subsidiaries, conducts (1) an LPG distribution business in France, Belgium, the Netherlands and Luxembourg (“Antargaz”); (2)  an LPG distribution business in central, northern

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

and eastern Europe (“Flaga”); (3) an LPG distribution business in the United Kingdom (“AvantiGas”); and (4) an LPG distribution business in the Nantong region of China. We refer to our foreign LPG operations collectively as “UGI International.”
Enterprises, through UGI Energy Services, LLC (which was formerly known as UGI Energy Services, Inc. prior to its merger with and into UGI Energy Services, LLC effective October 1, 2013) and its subsidiaries conduct an energy marketing, midstream infrastructure, storage, natural gas gathering, natural gas production and energy services business primarily in the Mid-Atlantic region of the United States. In addition, UGI Energy Services, LLC’s wholly owned subsidiary, UGI Development Company (“UGID”), owns all or a portion of electricity generation facilities principally located in Pennsylvania. These businesses are referred to herein collectively as “Midstream & Marketing.” UGI Energy Services, LLC subsequent to the merger and UGI Energy Services, Inc. prior to the merger are referred to herein as “Energy Services.” Enterprises also conducts heating, ventilation, air-conditioning, refrigeration and electrical contracting businesses in the Mid-Atlantic region through first-tier subsidiaries.
Our natural gas and electric distribution utility businesses are conducted through our wholly owned subsidiary, UGI Utilities, Inc. (“UGI Utilities”), and its subsidiaries UGI Penn Natural Gas, Inc. (“PNG”) and UGI Central Penn Gas, Inc. (“CPG”). UGI Utilities, PNG and CPG own and operate natural gas distribution utilities in eastern, northeastern and central Pennsylvania and in a portion of one Maryland county. UGI Utilities also owns and operates an electric distribution utility in northeastern Pennsylvania (“Electric Utility”). UGI Utilities’ natural gas distribution utility is referred to as “UGI Gas.” UGI Gas, PNG and CPG are collectively referred to as “Gas Utility.” Gas Utility is subject to regulation by the Pennsylvania Public Utility Commission (“PUC”) and, with respect to a small service territory in one Maryland county, the Maryland Public Service Commission, and Electric Utility is subject to regulation by the PUC. Gas Utility and Electric Utility are collectively referred to as “Utilities.”

Note 2 — Significant Accounting Policies
Basis of Presentation
Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”).
The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based on management’s knowledge of current events, historical experience and various other assumptions that are believed to be reasonable under the circumstances. Accordingly, actual results may be different from these estimates and assumptions.
Certain prior-year amounts have been reclassified to conform to the current-year presentation. In addition, see Note 3 regarding the effects of revisions on previously issued financial statements.
Principles of Consolidation
The consolidated financial statements include the accounts of UGI and its controlled subsidiary companies which, except for the Partnership, are majority owned. We report the general public’s and ETP’s interests in the Partnership, and outside ownership interests in other consolidated but less than 100% -owned subsidiaries, as noncontrolling interests. We eliminate all significant intercompany accounts and transactions when we consolidate. Entities in which we do not have control but have significant influence over operating and financial policies are accounted for by the equity method. Undistributed net earnings of our equity investees included in consolidated retained earnings were not material at September 30, 2013 . Investments in business entities that are not publicly traded and in which we hold less than 20% of voting rights are accounted for using the cost method. Such investments are recorded in other assets and totaled $82.0 and $80.0 at September 30, 2013 and 2012 , respectively (including $16.4 and $20.0 , respectively, associated with our approximate 3.5% interest in a private equity partnership that invests in renewable energy companies). Undivided interests in natural gas production assets and an electricity generation facility are consolidated on a proportionate basis.
Effects of Regulation
UGI Utilities accounts for the financial effects of regulation in accordance with the Financial Accounting Standards Board’s (“FASB’s”) guidance in Accounting Standards Codification (“ASC”) 980 related to regulated entities whose rates are designed to recover the costs of providing service. In accordance with this guidance, incurred costs and estimated future expenditures that would otherwise be charged to expense are capitalized and recorded as regulatory assets when it is probable that the incurred costs or estimated future expenditures will be recovered in rates in the future. Similarly, we recognize regulatory liabilities when it is probable that regulators will require customer refunds through future rates or when revenue is collected from customers for

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

expenditures that have not yet been incurred. Generally, regulatory assets are amortized into expense and regulatory liabilities are amortized into income over the period authorized by the regulator.
For additional information regarding the effects of rate regulation on our utility operations, see Note 9 .
Fair Value Measurements
We apply fair value measurements on a recurring basis to certain assets and liabilities, principally our commodity, foreign currency and interest rate derivative instruments. Assets that are not measured at fair value on a recurring basis but are subject to fair value measurements under certain circumstances principally comprise our cost and equity method investments and long-lived assets that are written down to fair value when they are impaired. Fair value in GAAP is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Fair value is based upon assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. Fair value measurements require that we assume that the transaction occurs in the principal market for the asset or liability or, in the absence of a principal market, the most advantageous market for the asset or liability (the market for which the reporting entity would be able to maximize the amount received or minimize the amount paid). We evaluate the need for credit adjustments to our derivative instrument fair values in accordance with the requirements noted above. Such adjustments were not material to the fair values of our derivative instruments.
We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:
		
•	Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date. Instruments categorized in Level 1 consist of our exchange-traded commodity futures and option contracts and non exchange-traded commodity futures and non exchange-traded electricity forward contracts whose underlying is identical to an exchange-traded contract.	
		
•	Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over the counter commodity price swap and option contracts, interest rate swaps and interest rate protection agreements, foreign currency forward contracts, financial transmission rights (“FTRs”) and non exchange-traded electricity forward and capacity swap contracts that do not qualify for Level 1.	
		
•	Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. We did not have any derivative financial instruments categorized as Level 3 at September 30, 2013 or 2012 .	
The fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs to measure fair value might fall into different levels of the fair value hierarchy. The lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability. See Note 17 for additional information on fair value measurements.
Derivative Instruments
We account for derivative instruments and hedging activities in accordance with guidance provided by the FASB which requires that all derivative instruments, whether designated in hedging relationships or not, be recognized as either assets or liabilities and measured at fair value unless the derivative instruments qualify for the normal purchase and sale exemption under GAAP. The accounting for changes in fair value depends upon the purpose of the derivative instrument and whether it is designated and qualifies for hedge accounting.
A substantial portion of our derivative financial instruments other than commodity derivative instruments at Midstream & Marketing are designated and qualify as cash flow hedges or net investment hedges. Substantially all of Midstream & Marketing’s commodity derivative instruments are not designated as cash flow hedges. These derivative instruments are recorded at fair value

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

with changes in fair value reflected in income. In addition, unrealized gains and losses on certain derivative financial instruments used by Gas Utility and Electric Utility are included in regulatory assets or liabilities in accordance with FASB guidance regarding accounting for rate-regulated entities.
For cash flow hedges, changes in the fair value of the derivative financial instruments are recorded in accumulated other comprehensive income (“AOCI”) or noncontrolling interests, to the extent effective at offsetting changes in the hedged item, until earnings are affected by the hedged item. We discontinue cash flow hedge accounting if the occurrence of the forecasted transaction is determined to be no longer probable. Gains and losses on net investment hedges which relate to our foreign operations are included in AOCI until such foreign net investment is sold or liquidated. Changes in the fair values of Midstream & Marketing’s commodity derivative instruments, along with those of certain of our other businesses’ derivative financial instruments, do not qualify for, or are not designated as, cash flow hedges. Changes in the fair values of these derivative instruments are generally reflected in cost of sales or revenues, as appropriate, on the Consolidated Statements of Income. Cash flows from derivative financial instruments, other than net investment hedges, are included in cash flows from operating activities. Cash flows from net investment hedges are included in cash flows from investing activities.
For a more detailed description of the derivative instruments we use, our accounting for derivatives, our objectives for using them and other information, see Note 18 .
Foreign Currency Translation
Balance sheets of international subsidiaries are translated into U.S. dollars using the exchange rate at the balance sheet date. Income statements and equity investee results are translated into U.S. dollars using an average exchange rate for each reporting period. Where the local currency is the functional currency, translation adjustments are recorded in other comprehensive income.
Revenue Recognition
Revenues from the sale of LPG are recognized principally upon delivery. Midstream & Marketing records revenues when energy products are delivered or services are provided to customers. Revenues from the sale of appliances and equipment are recognized at the later of sale or installation. Revenues from repair or maintenance services are recognized upon completion of services.
UGI Utilities’ regulated revenues are recognized as natural gas and electricity are delivered and include estimated amounts for distribution service and commodities rendered but not billed at the end of each month. We reflect the impact of Gas Utility and Electric Utility rate increases or decreases at the time they become effective.
We present revenue-related taxes collected from customers and remitted to taxing authorities, principally sales and use taxes, on a net basis. Electric Utility gross receipts taxes are included in total revenues in accordance with regulatory practice.
LPG Delivery Expenses
Expenses associated with the delivery of LPG to customers of the Partnership and our UGI International operations (including vehicle expenses, expenses of delivery personnel, vehicle repair and maintenance and general liability expenses) are classified as operating and administrative expenses on the Consolidated Statements of Income. Depreciation expense associated with the Partnership and UGI International delivery vehicles is classified in depreciation on the Consolidated Statements of Income.
Income Taxes
AmeriGas Partners and the Operating Partnerships are not directly subject to federal income taxes. Instead, their taxable income or loss is allocated to the individual partners. We record income taxes on (1) our share of the Partnership’s current taxable income or loss and (2) the differences between the book and tax basis of our investment in the Partnership. The Operating Partnership has subsidiaries which operate in corporate form and are directly subject to federal and state income taxes. Legislation in certain states allows for taxation of partnership income and the accompanying financial statements reflect state income taxes resulting from such legislation.
Gas Utility and Electric Utility record deferred income taxes in the Consolidated Statements of Income resulting from the use of accelerated tax depreciation methods based upon amounts recognized for ratemaking purposes. They also record a deferred income tax liability for tax benefits, principally the result of accelerated tax depreciation for state income tax purposes, that are

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

flowed through to ratepayers when temporary differences originate and record a regulatory income tax asset for the probable increase in future revenues that will result when the temporary differences reverse.
We are amortizing deferred investment tax credits related to UGI Utilities’ plant additions over the service lives of the related property. UGI Utilities reduces its deferred income tax liability for the future tax benefits that will occur when investment tax credits, which are not taxable, are amortized. We also reduce the regulatory income tax asset for the probable reduction in future revenues that will result when such deferred investment tax credits amortize. Investment tax credits associated with Midstream & Marketing’s qualifying solar energy property under the Emergency Economic Stabilization Act of 2008 are reflected in income taxes for assets placed in service after Fiscal 2011 and are amortized over the estimated useful life of the property for assets placed in service prior to Fiscal 2012.
We record interest on tax deficiencies and income tax penalties in income taxes on the Consolidated Statements of Income. No amounts were recorded for interest in Fiscal 2013. For Fiscal 2012 and Fiscal 2011 , interest (income) expense of $(0.1) and $0.2 , respectively, was recognized in income taxes on the Consolidated Statements of Income.
Earnings Per Common Share
Basic earnings per share attributable to UGI Corporation stockholders reflect the weighted-average number of common shares outstanding. Diluted earnings per share include the effects of dilutive stock options and common stock awards. In the following table, we present shares used in computing basic and diluted earnings per share for Fiscal 2013 , Fiscal 2012 and Fiscal 2011 :

										
(Thousands of shares)	 	2013	 	2012	 	2011	
Average common shares outstanding for basic computation	 	113,923		 	112,581		 	111,674		
Incremental shares issuable for stock options and common stock awards (a)	 	1,598		 	851		 	1,270		
Average common shares outstanding for diluted computation	 	115,521		 	113,432		 	112,944		

(a)	For Fiscal 2013, Fiscal 2012 and Fiscal 2011, there were approximately 88 shares, 81 shares and 3,700 shares, respectively, associated with outstanding stock option awards that were not included in the computation of diluted earnings per share above because their effect was antidilutive.	
Comprehensive Income
Comprehensive income comprises net income and other comprehensive income (loss). Other comprehensive income (loss) principally results from gains and losses on derivative instruments qualifying as cash flow hedges, actuarial gains and losses on postretirement benefit plans and foreign currency translation adjustments and foreign currency long-term intra-company transactions.
The components of AOCI at September 30, 2013 and 2012 follow:

																
 	Postretirement
Benefit Plans	 	Derivative
Instruments Net
Losses	 	Foreign
Currency
Translation
Adjustments	 	Total	
Balance, September 30, 2013	$	(16.4	)	 	$	(26.9	)	 	$	51.7		 	$	8.4		
Balance, September 30, 2012	$	(22.9	)	 	$	(52.0	)	 	$	19.7		 	$	(55.2	)	

Cash and Cash Equivalents
All highly liquid investments with maturities of three months or less when purchased are classified as cash equivalents.
Restricted Cash
Restricted cash principally represents those cash balances in our commodity futures and option brokerage accounts which are restricted from withdrawal.

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Inventories
Our inventories are stated at the lower of cost or market. We determine cost using an average cost method for natural gas, propane and other LPG; specific identification for appliances; and the first-in, first-out (“FIFO”) method for all other inventories.
Property, Plant and Equipment and Related Depreciation
We record property, plant and equipment at original cost. The amounts assigned to property, plant and equipment of acquired businesses are based upon estimated fair value at date of acquisition.
We record depreciation expense on non-utility plant and equipment on a straight-line basis over estimated economic useful lives ranging from 15 to 40  years for buildings and improvements; 7 to 40  years for storage and customer tanks and cylinders; 25 to 35  years for electricity generation facilities; and 2 to 12  years for vehicles, equipment and office furniture and fixtures. Costs to install Partnership and Antargaz-owned tanks, net of amounts billed to customers, are capitalized and amortized over the estimated period of benefit not exceeding ten years.
We record depreciation expense for Utilities’ plant and equipment on a straight-line basis over the estimated average remaining lives of the various classes of its depreciable property. Depreciation expense as a percentage of the related average depreciable base for Gas Utility was 2.3% in Fiscal 2013 , 2.2% in Fiscal 2012 and 2.3% in Fiscal 2011 . Depreciation expense as a percentage of the related average depreciable base for Electric Utility was 2.4% in Fiscal 2013 , 2.4% in Fiscal 2012 and 2.6% in Fiscal 2011 . When Utilities retires depreciable utility plant and equipment, we charge the original cost to accumulated depreciation for financial accounting purposes.
We include in property, plant and equipment costs associated with computer software we develop or obtain for use in our businesses. We amortize computer software costs on a straight-line basis over expected periods of benefit not exceeding fifteen years once the installed software is ready for its intended use.
No depreciation expense is included in cost of sales in the Consolidated Statements of Income.
Goodwill and Intangible Assets
In accordance with GAAP relating to intangible assets, we amortize intangible assets over their estimated useful lives unless we determine their lives to be indefinite. We review identifiable intangible assets subject to amortization for impairment whenever events or changes in circumstances indicate that the associated carrying amounts may not be recoverable. Determining whether an impairment loss occurred requires comparing the carrying amount to the sum of undiscounted cash flows expected to be generated by the asset. Intangible assets with indefinite lives are not amortized but are tested annually for impairment and written down to fair value as required.
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 discrete financial information is prepared and regularly reviewed by segment management. Components are aggregated as a single reporting unit if they have similar economic characteristics. We are required to recognize an impairment charge under GAAP if the carrying amount of a reporting unit exceeds its fair value and the carrying amount of the reporting unit’s goodwill exceeds the implied fair value of that goodwill. 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, and for those reporting units for which we are not able, based upon the assessment of qualitative factors, to determine that it is not more likely than not that the fair value of such reporting unit is less than its carrying amount, we determine fair values generally using an income approach unless market values are available. For purposes of the income approach, fair values are determined based upon the present value of estimated future cash flows discounted at an appropriate risk-adjusted rate.
No provisions for goodwill or other intangible asset impairments were recorded during Fiscal 2013 , Fiscal 2012 or Fiscal 2011 . No amortization expense is included in cost of sales in the Consolidated Statements of Income (see Note 12 ).
Impairment of Long-Lived Assets and Cost Basis Investments
We evaluate the impairment of long-lived assets whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. We evaluate recoverability based upon undiscounted future cash flows expected

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

to be generated by such assets. No material provisions for impairments were recorded during Fiscal 2013 , Fiscal 2012 or Fiscal 2011 .
We reduce the carrying values of our cost basis investments when we determine that a decline in fair value is other than temporary. During Fiscal 2013, we recorded a pre-tax loss of $6.3 associated with an other-than-temporary impairment of an investment in a private equity partnership.

Deferred Debt Issuance Costs
Included in other assets on our Consolidated Balance Sheets are net deferred debt issuance costs of $39.4 and $46.6 at September 30, 2013 and 2012 , respectively. We are amortizing these costs over the terms of the related debt.
Refundable Tank and Cylinder Deposits
Included in other noncurrent liabilities on our Consolidated Balance Sheets are customer paid deposits on Antargaz owned tanks and cylinders of $214.6 and $205.1 at September 30, 2013 and 2012 , respectively. Deposits are refundable to customers when the tanks or cylinders are returned in accordance with contract terms.
Environmental Matters
We are subject to environmental laws and regulations intended to mitigate or remove the effect 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.
Environmental reserves are accrued when assessments indicate that it is probable that a liability has been incurred and an amount can reasonably be estimated. Amounts recorded as environmental liabilities on the 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. Our estimated liability for environmental contamination is reduced to reflect anticipated participation of other responsible parties but is not reduced for possible recovery from insurance carriers. In those instances for which the amount and timing of cash payments associated with environmental investigation and cleanup are reliably determinable, we discount such liabilities to reflect the time value of money. We intend to pursue recovery of incurred costs through all appropriate means, including regulatory relief. UGI Gas is permitted to amortize as removal costs site-specific environmental investigation and remediation costs, net of related third-party payments, associated with Pennsylvania sites. UGI Gas is currently permitted to include in rates, through future base rate proceedings, a five -year average of such prudently incurred remediation costs, and CPG and PNG are currently receiving regulatory recovery of estimated environmental investigation and remediation costs associated with Pennsylvania sites. For further information, see Note 16 .
Employee Retirement Plans
We use a market-related value of plan assets and an expected long-term rate of return to determine the expected return on assets of our pension and other postretirement plans. The market-related value of plan assets, other than equity investments, is based upon fair values. The market-related value of equity investments is calculated by rolling forward the prior-year’s market-related value with contributions, disbursements and the expected return on plan assets. One third of the difference between the expected and the actual value is then added to or subtracted from the expected value to determine the new market-related value (see Note 8 ).
Equity-Based Compensation
All of our equity-based compensation, principally comprising UGI stock options, grants of UGI stock-based equity instruments and grants of AmeriGas Partners equity instruments (together with UGI stock-based equity instruments, “Units”), are measured at fair value on the grant date, date of modification or end of the period, as applicable. Compensation expense is recognized on a straight-line basis over the requisite service period. Depending upon the settlement terms of the awards, all or a portion of the fair value of equity-based awards may be presented as a liability or as equity in our Consolidated Balance Sheets. Equity-based compensation costs associated with the portion of Unit awards classified as equity are measured based upon their estimated fair value on the date of grant or modification. Equity-based compensation costs associated with the portion of Unit awards classified as liabilities are measured based upon their estimated fair value at the grant date and remeasured as of the end of each period.

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

We have calculated a tax windfall pool using the shortcut method. We record deferred tax assets for awards that we expect will result in deductions on our income tax returns based on the amount of compensation cost recognized and the statutory tax rate in the jurisdiction in which we will receive a deduction. Differences between the deferred tax assets recognized for financial reporting purposes and the actual tax benefit received on the income tax return are recorded in Common Stock (if the tax benefit exceeds the deferred tax asset) or in the Consolidated Statements of Income (if the deferred tax asset exceeds the tax benefit and no tax windfall pool exists from previous awards).
For additional information on our equity-based compensation plans and related disclosures, see Note 14 .

Note 3 — Revisions and Restatements of Consolidated Financial Statements 

During the preparation of the Fiscal 2013 consolidated financial statements, management concluded that it had incorrectly accounted for certain commodity derivative instruments as cash flow hedges. Management had incorrectly applied the hedge accounting criteria when designating certain commodity derivative instruments at its Midstream & Marketing businesses as cash flow hedges. As a result, the accompanying financial statements as of and for the two years in the period ended September 30, 2012, have been revised to report changes in the fair values of unsettled commodity derivative instruments and gains and losses on settled commodity derivative instruments for which the associated forecasted transactions have not yet occurred in cost of sales or revenues in the Consolidated Statements of Income rather than in other comprehensive income. Management has discontinued the use of hedge accounting for substantially all of Midstream & Marketing’s commodity derivative instruments and has reported changes in the fair values of unsettled commodity derivative instruments, and gains and losses on settled commodity derivatives for which the associated forecasted transaction has not yet occurred, in net income.

Although the impact of the error was not material to the Company’s historical annual consolidated financial statements, management decided to revise its consolidated financial statements and disclosures to correct this error in accounting for the years ended September 30, 2012 and 2011. Management did conclude that the error in accounting was material to its consolidated financial statements for the fiscal quarters ended March 31, 2013, June 30, 2012, and December 31, 2011, and that it is necessary to restate the Company’s financial statements for those periods while the Company’s consolidated financial statements for other quarterly periods have been revised (see Note 21).

The following table sets forth the effects of the revision on affected line items within the Company’s previously reported consolidated financial statements for fiscal years ended September 30, 2012 and 2011. Also included in the adjustment columns in the tables below are certain other immaterial corrections that the Company made, including, but not limited to, adjustments to correct the Partnership’s accounting for certain customer credits and to correct the classification of deferred income tax assets, as further described below, as well as certain other minor adjustments related principally to the timing of certain expense and income accruals.

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Consolidated Balance Sheet

										
 	September 30, 2012	
 	As Previously Reported	Adjustment	As Revised	
Assets:	 	 	 	
Accounts receivable	$	632.6		$	(5.1	)	$	627.5		
Inventories	$	356.9		$	(2.8	)	$	354.1		
Deferred income taxes	$	56.8		$	(27.0	)	$	29.8		
Prepaid expenses and other current assets	$	98.7		$	0.8		$	99.5		
Non-utility property, plant and equipment	$	4,223.4		$	0.5		$	4,223.9		
Accumulated depreciation and amortization	$	(2,286.0	)	$	0.8		$	(2,285.2	)	
Liabilities and equity:	 	 	 	
Accounts payable	$	411.3		$	(1.4	)	$	409.9		
Employee compensation and benefits accrued	$	91.1		$	(1.4	)	$	89.7		
Accrued interest	$	72.7		$	(1.1	)	$	71.6		
Other current liabilities	$	226.4		$	(0.8	)	$	225.6		
Deferred income taxes	$	935.0		$	(29.3	)	$	905.7		
Other noncurrent liabilities	$	616.7		$	4.6		$	621.3		
Retained earnings	$	1,166.1		$	(10.1	)	$	1,156.0		
Accumulated other comprehensive (loss) income	$	(62.0	)	$	6.8		$	(55.2	)	
Noncontrolling interests, principally in AmeriGas Partners	$	1,085.7		$	(0.1	)	$	1,085.6		

During the three months ended September 30, 2013, we identified an error in the classification of deferred income tax assets on the September 30, 2012, Consolidated Balance Sheet in the amount of $27.0 . The adjustment to correct this error is included in the table above in deferred income taxes (assets) and deferred income taxes (liabilities).

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Consolidated Statements of Income

																				
 	Fiscal years ended September 30,	
 	 	2012	 	 	 	2011	 	
 	As Previously Reported	Adjustment	As Revised	 	As Previously Reported	Adjustment	As Revised	
Non-utility revenues	$	5,636.7		$	2.1		$	5,638.8		 	$	4,955.8		$	(0.4	)	$	4,955.4		
Non-utility cost of sales	$	3,652.1		$	(12.1	)	$	3,640.0		 	$	3,332.4		$	(28.2	)	$	3,304.2		
Operating and administrative expenses	$	1,591.7		$	(0.6	)	$	1,591.1		 	$	1,266.4		$	0.6		$	1,267.0		
Depreciation	$	264.2		$	(1.0	)	$	263.2		 	$	201.2		$	(0.2	)	$	201.0		
Other income, net	$	(38.3	)	$	(1.5	)	$	(39.8	)	 	$	(46.5	)	$	1.0		$	(45.5	)	
Operating income	$	521.3		$	17.3		$	538.6		 	$	616.0		$	26.4		$	642.4		
Interest expense	$	(221.5	)	$	1.1		$	(220.4	)	 	$	(138.0	)	N/A		N/A		
Income before income taxes	$	286.2		$	18.4		$	304.6		 	$	439.0		$	26.4		$	465.4		
Income taxes	$	(99.6	)	$	(7.3	)	$	(106.9	)	 	$	(130.8	)	$	(14.6	)	$	(145.4	)	
Net income	$	186.6		$	11.1		$	197.7		 	$	308.2		$	11.8		$	320.0		
(Deduct net income) add net loss attributable to noncontrolling interests, principally in AmeriGas Partners	$	12.8		$	(0.3	)	$	12.5		 	$	(75.3	)	$	0.7		$	(74.6	)	
Net income attributable to UGI Corporation	$	199.4		$	10.8		$	210.2		 	$	232.9		$	12.5		$	245.4		
Basic earnings per common share	$	1.77		 	$	1.87		 	$	2.09		 	$	2.20		
Diluted earnings per common share	$	1.76		 	$	1.85		 	$	2.06		 	$	2.17		

Consolidated Statements of Comprehensive Income

																				
 	Fiscal years ended September 30,	
 	 	2012	 	 	 	2011	 	
 	As Previously Reported	Adjustment	As Revised	 	As Previously Reported	Adjustment	As Revised	
Net income	$	186.6		$	11.1		$	197.7		 	$	308.2		$	11.8		$	320.0		
Net (losses) gains on derivative instruments	$	(127.1	)	$	21.7		$	(105.4	)	 	$	(10.8	)	$	14.7		$	3.9		
Reclassifications of net losses (gains) on derivative instruments	$	87.9		$	(31.6	)	$	56.3		 	$	11.8		$	(30.8	)	$	(19.0	)	
Comprehensive income	$	114.3		$	1.2		$	115.5		 	$	295.1		$	(4.3	)	$	290.8		
Comprehensive income attributable to UGI Corporation	$	153.2		$	0.9		$	154.1		 	$	225.3		$	(3.6	)	$	221.7		

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Consolidated Statements of Cash Flows

																				
 	Fiscal years ended September 30,	
 	 	2012	 	 	 	2011	 	
CASH FLOWS FROM OPERATING ACTIVITIES:	As Previously Reported	Adjustment	As Revised	 	As Previously Reported	Adjustment	As Revised	
Net income	$	186.6		$	11.1		$	197.7		 	$	308.2		$	11.8		$	320.0		
Depreciation and amortization	$	316.0		$	(1.0	)	$	315.0		 	$	227.9		$	(0.2	)	$	227.7		
Deferred income taxes, net	$	82.9		$	7.3		$	90.2		 	$	82.7		$	8.8		$	91.5		
Net change in realized gains and losses deferred as cash flow hedges	$	(6.6	)	$	6.6		$	—		 	$	12.2		$	(12.2	)	$	—		
Unrealized gains on derivative instruments	$	—		$	(17.2	)	$	(17.2	)	 	$	—		$	(19.6	)	$	(19.6	)	
Other, net	$	(10.7	)	$	(6.8	)	$	(17.5	)	 	$	(7.1	)	$	11.4		$	4.3		

Consolidated Statements of Changes in Equity

																				
 	Fiscal years ended September 30,	
 	 	2012	 	 	 	2011	 	
 	As Previously Reported	Adjustment	As Revised	 	As Previously Reported	Adjustment	As Revised	
Retained earnings	$	1,166.1		$	(10.1	)	$	1,156.0		 	$	1,085.8		$	(20.9	)	$	1,064.9		
Accumulated other comprehensive (loss) income	$	(62.0	)	$	6.8		$	(55.2	)	 	$	(17.7	)	$	16.7		$	(1.0	)	
Noncontrolling interests	$	1,085.7		$	(0.1	)	$	1,085.6		 	$	213.4		$	(0.4	)	$	213.0		

During the three months ended March 31, 2013, the Partnership determined that the recording of propane revenues did not appropriately consider the effects of certain customer credits which were recorded in a subsequent period. Although the Company evaluated the impact of the error on prior periods and determined the effect was not material to any prior period financial statement and corrected the error during the three months ended March 31, 2013, the tables above include correction of the error in accounting for customer credits in the appropriate historical period.

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

The impacts of the corrections on the key financial metrics operating income, net income attributable to UGI Corporation and diluted earnings per share for the years ended September 30, 2013 and 2012 are as follows:

								
 	Fiscal 2012	 	Fiscal 2011	
Operating income :	 	 	 	
Midstream & Marketing hedge accounting	$	17.0		 	$	27.6		
Partnership customer credits	(1.8	)	 	0.1		
Other	2.1		 	(1.3	)	
Total	$	17.3		 	$	26.4		
 	 	 	 	
Net income attributable to UGI Corporation:	 	 	 	
Midstream & Marketing hedge accounting	$	10.0		 	$	16.2		
Partnership customer credits	(0.6	)	 	—		
Other	1.4		 	(3.7	)	
Total	$	10.8		 	$	12.5		
 	 	 	 	
Diluted earnings per common share attributable to UGI Corporation stockholders:	 	 	 	
Midstream & Marketing hedge accounting	$	0.09		 	$	0.14		
Partnership customer credits	—		 	—		
Other	—		 	(0.03	)	
Total	$	0.09		 	$	0.11		

Note 4 — Accounting Changes
New Accounting Standards Not Yet Adopted
Disclosures about Reclassifications Out of Accumulated Other Comprehensive Income . In February 2013, the FASB issued new accounting guidance regarding disclosures for items reclassified out of AOCI. The new disclosure guidance is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2012. The new disclosures are to be applied prospectively, and early adoption is permitted. We will adopt the new guidance in Fiscal 2014. As this guidance provides only disclosure requirements, the adoption of this standard will not impact our results of operations, cash flows or financial position.
Disclosures about Offsetting Assets and Liabilities. In December 2011 (and amended in January 2013), the FASB issued new accounting guidance requiring entities to disclose both gross and net information about recognized derivative instruments that are offset on the balance sheet or subject to an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset on the balance sheet. The new guidance is effective for annual reporting periods beginning on or after January 1, 2013 (Fiscal 2014) and interim periods within those annual periods, and is required to be applied retrospectively. As this guidance provides only disclosure requirements, the adoption of this standard will not impact our results of operations, cash flows or financial position.

Note 5 — Acquisitions
On January 12, 2012 (the “Acquisition Date”), AmeriGas Partners completed the acquisition of Heritage Propane from ETP for total consideration of $2,598.2 , comprising $1,465.6 in cash and 29,567,362 AmeriGas Partners Common Units with a fair value of $1,132.6 (the “Heritage Acquisition”). The Acquisition Date cash consideration for the Heritage Acquisition was subject to purchase price adjustments based on working capital, cash and the amount of indebtedness of Heritage Propane (“Working Capital Adjustment”) and certain excess cash proceeds resulting from ETP’s sale of HOLP’s former cylinder exchange business (“HPX”). In April 2012, AmeriGas Partners paid $25.5 of additional cash consideration as a result of the Working Capital Adjustment and in June 2012, AmeriGas Partners received $18.9 in cash representing the excess cash proceeds from the sale of HPX. The Heritage Acquisition was consummated pursuant to a Contribution and Redemption Agreement dated October 15, 2011, as amended (the “Contribution Agreement”), by and among AmeriGas Partners, ETP, Energy Transfer Partners GP, L.P., the general partner of ETP (“ETP GP”), and Heritage ETC, L.P. (the “Contributor”). The acquired business conducted its propane

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

operations in 41 states through HOLP and Titan LLC. According to LP-Gas Magazine rankings published on February 1, 2012, Heritage Propane was the third largest retail propane distributor in the United States, delivering over 500 million gallons to more than one million retail propane customers in 2011. The Heritage Acquisition is consistent with our growth strategies, one of which is to grow the Partnership’s core business through acquisitions.
Pursuant to the Contribution Agreement, the Contributor contributed to AmeriGas Partners a 99.999% limited partner interest in HOLP; a 100% membership interest in Heritage Operating GP, LLC, a Delaware limited liability company and a holder of a 0.001% general partner interest in HOLP; a 99.99% limited partner interest in Titan Energy Partners, L.P., a Delaware limited partnership and the sole member of Titan LLC; and a 100% membership interest in Titan Energy GP, L.L.C., a Delaware limited liability company and holder of a 0.01% general partner interest in Titan Energy Partners, L.P. As a result of the Heritage Acquisition, the General Partner, in order to maintain its general partner interests in AmeriGas Partners and AmeriGas OLP, contributed 934,327 Common Units to the Partnership having a fair value of $41.7 . These Common Units were subsequently cancelled.
The cash portion of the Heritage Acquisition was financed by the issuance by AmeriGas Finance Corp. and AmeriGas Finance LLC, wholly owned finance subsidiaries of AmeriGas Partners (the “Issuers”), of $550 principal amount of 6.75% Senior Notes due May 2020 (the “ 6.75% Notes”) and $1,000 principal amount of 7.00% Senior Notes due May 2022 (the “ 7.00% Notes”). For further information on the 6.75% Notes and the 7.00% Notes, see Note 6 .

The Consolidated Balance Sheet at September 30, 2012, reflects the final allocation of the purchase price to the assets acquired and liabilities assumed for the Heritage Propane business combination. The purchase price paid comprises AmeriGas Partners Common Units issued having a fair value of $1,132.6 , and total cash consideration of $1,472.2 including cash acquired of $60.7 . The fair value of the AmeriGas Partners Common Units issued to ETP was based on the closing price on the Acquisition Date subject to a discount to reflect certain contractual transfer restrictions for a period of approximately twelve months. The purchase price allocation was as follows:

				
Assets acquired:	 	
Current assets	$	301.4		
Property, plant & equipment	890.2		
Customer relationships (estimated useful life of 15 years)	418.9		
Trademarks and tradenames (a)	91.1		
Goodwill (a)	1,217.7		
Other assets	9.9		
Total assets acquired	$	2,929.2		
 	 	
Liabilities assumed:	 	
Current liabilities	$	(238.1	)	
Long-term debt	(62.9	)	
Other noncurrent liabilities	(23.4	)	
Total liabilities assumed	$	(324.4	)	
Total	$	2,604.8		
(a) During Fiscal 2013, the Partnership made a correcting adjustment to trademarks and tradenames and goodwill which is not reflected in the table above. See Note 12 .
Goodwill associated with the Heritage Acquisition principally results from synergies expected from combining the operations and from assembled workforce. The tax effects of such goodwill will be realized over a fifteen -year period. We allocated the purchase price of the acquisition to identifiable intangible assets based on estimated fair values.  Tradenames and trademarks were valued using the relief from royalty method and customer relationships were valued using a discounted cash flow method. The relief from royalty method estimates our theoretical royalty savings from ownership of the tradenames and trademarks. Key assumptions used in this method include discount rates, royalty rates, growth rates and sales projections and are the assumptions most sensitive and susceptible to change as they require significant management judgment. The key assumptions used in the customer relationship discounted cash flow method include discount rates, growth rates and cash flow projections and are the assumptions most sensitive and susceptible to change as they require significant management judgment. We allocated the purchase price of the acquisition to property, plant and equipment based on estimated fair values primarily using replacement cost and market value methods.

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Transaction expenses associated with the Heritage Acquisition, which are included in operating and administrative expenses in the Consolidated Statement of Income, totaled $5.3 for Fiscal 2012. The results of operations of Heritage Propane are included in the Consolidated Statements of Income since the Acquisition Date. As a result of combining the Heritage Propane operations with the Partnership’s legacy operations, it is impracticable to determine the impact of the Heritage Propane operations on the revenues and earnings of the Company.
The following presents unaudited pro forma income statement and earnings per share data for Fiscal 2012 and 2011 as if the Heritage Acquisition had occurred on October 1, 2010:

	
									
 	 	Fiscal 2012	 	Fiscal 2011	
Revenues	 	$	7,013.0		 	$	7,522.1		
Net income attributable to UGI Corporation	 	$	208.4		 	$	236.0		
Earnings per common share attributable to UGI Corporation stockholders:	 	 	 	 	
Basic	 	$	1.85		 	$	2.11		
Diluted	 	$	1.84		 	$	2.09		
The unaudited pro forma results of operations reflect Heritage Propane’s historical operating results after giving effect to adjustments directly attributable to the transaction that are expected to have a continuing effect. The unaudited pro forma consolidated results of operations are not necessarily indicative of the results that would have occurred had the Heritage Acquisition occurred on the date indicated nor are they necessarily indicative of future operating results.
During Fiscal 2013, Flaga acquired BP’s LPG distribution business in Poland for total cash consideration of approximately $36 which Flaga financed with cash proceeds from the issuance of long-term debt (see Note 6 ) and its purchase price has been preliminarily allocated to the assets acquired and liabilities assumed; AmeriGas OLP acquired two domestic retail propane distribution businesses for approximately $20 in cash; and Energy Services acquired a non-operating working interest in natural gas acreage in the Marcellus Shale region of Pennsylvania for approximately $23 in cash. In October 2011, we acquired Shell’s LPG distribution businesses in (1) Belgium, the Netherlands and Luxembourg through Antargaz; (2) Denmark, Finland, Norway and Sweden through Flaga; and (3) the United Kingdom through UGI Midlands Limited (a second-tier subsidiary of Enterprises), for a total of €133.6 ( $179.0 ) in cash (the “Shell Transaction”). Also during Fiscal 2012, AmeriGas OLP acquired a number of smaller domestic retail propane distribution businesses for $13.5 in cash. During Fiscal 2011, AmeriGas OLP acquired a number of domestic retail propane distribution businesses for $34.0 in cash, and Flaga acquired a propane distribution business in Poland for total cash consideration of approximately $19.0 .

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Note 6 — Debt
Long-term debt comprises the following at September 30:

								
 	2013	 	2012	
AmeriGas Propane:	 	 	 	
AmeriGas Partners Senior Notes:	 	 	 	
   7.00%, due May 2022	$	980.8		 	$	980.8		
   6.75%, due May 2020	550.0		 	550.0		
   6.50%, due May 2021	270.0		 	270.0		
   6.25%, due August 2019	450.0		 	450.0		
HOLP Senior Secured Notes	32.0		 	55.6		
Other	17.3		 	21.6		
Total AmeriGas Propane	2,300.1		 	2,328.0		
UGI International:	 	 	 	
Antargaz Senior Facilities term loan, due through March 2016	514.0		 	488.7		
Flaga term loan, due September 2016	52.0		 	—		
Flaga term loan, due through September 2016	54.1		 	51.4		
Flaga term loan, due October 2016	25.8		 	24.6		
Flaga term loan, due through June 2014	1.9		 	3.6		
Other	6.6		 	5.6		
Total UGI International	654.4		 	573.9		
UGI Utilities:	 	 	 	
Term Loan Credit Agreement	175.0		 	—		
Senior Notes:	 	 	 	
6.375%, due September 2013	—		 	108.0		
5.75%, due September 2016	175.0		 	175.0		
6.21%, due September 2036	100.0		 	100.0		
Medium-Term Notes:	 	 	 	
5.37%, due August 2013	—		 	25.0		
5.16%, due May 2015	20.0		 	20.0		
7.37%, due October 2015	22.0		 	22.0		
5.64%, due December 2015	50.0		 	50.0		
6.17%, due June 2017	20.0		 	20.0		
7.25%, due November 2017	20.0		 	20.0		
5.67%, due January 2018	20.0		 	20.0		
6.50%, due August 2033	20.0		 	20.0		
6.13%, due October 2034	20.0		 	20.0		
Total UGI Utilities	642.0		 	600.0		
Other	12.9		 	12.4		
Total long-term debt	3,609.4		 	3,514.3		
Less: current maturities	(67.2	)	 	(166.7	)	
Total long-term debt due after one year	$	3,542.2		 	$	3,347.6		

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Scheduled principal repayments of long-term debt due in fiscal years 2014 to 2018 follow:

	
																				
 	2014	 	2015	 	2016	 	2017	 	2018	
AmeriGas Propane	$	12.0		 	$	9.3		 	$	7.0		 	$	5.0		 	$	4.3		
UGI Utilities (a)	—		 	20.0		 	247.0		 	20.0		 	40.0		
UGI International	55.4		 	47.9		 	523.4		 	26.7		 	0.5		
Other	0.6		 	0.7		 	0.7		 	0.7		 	0.8		
Total	$	68.0		 	$	77.9		 	$	778.1		 	$	52.4		 	$	45.6		
(a) UGI Utilities $175 Term Loan Credit Agreement borrowings anticipated to be refinanced on a long-term basis in March 2014 pursuant to a Note Purchase Agreement as further described below are excluded from the table above.

AmeriGas Propane
In order to finance the cash portion of the Heritage Acquisition, on January 12, 2012, the Issuers issued $550 principal amount of 6.75% Notes due May 2020 and $1,000 principal amount of 7.00% Notes due May 2022. The 6.75% Notes and the 7.00% Notes are fully and unconditionally guaranteed on a senior unsecured basis by AmeriGas Partners. The Issuers have the right to redeem the 6.75% Notes, in whole or in part, at any time on or after May 20, 2016, and to redeem the 7.00% Notes, in whole or in part, at any time on or after May 20, 2017, subject to certain restrictions. A premium applies to redemptions of the 6.75% Notes and 7.00% Notes through May 2018 and May 2020, respectively. On or prior to May 20, 2015, the Issuers may also redeem, at a premium and subject to certain restrictions, up to 35% of each of the 6.75% Notes and the 7.00% Notes with the proceeds of an AmeriGas Partners registered public equity offering. The 6.75% Notes and the 7.00% Notes and the guarantees rank equal in right of payment with all of AmeriGas Partners’ existing Senior Notes. In connection with the Heritage Acquisition, AmeriGas Partners, AmeriGas Finance Corp., AmeriGas Finance LLC and UGI entered into a Contingent Residual Support Agreement (“CRSA”) with ETP pursuant to which ETP will provide contingent, residual support of $1,500 of debt (“Supported Debt” as defined in the CRSA).
On March 28, 2012, AmeriGas Partners announced that holders of approximately $383.5 in aggregate principal amount of outstanding 6.50% Senior Notes due May 2021 (the “ 6.50% Notes”), representing approximately 82% of the total $470 principal amount outstanding, had validly tendered their notes in connection with the Partnership’s March 14, 2012, offer to purchase for cash up to $200 of the 6.50% Notes. Tendered 6.50% Notes in the amount of $200 were redeemed on March 28, 2012, at an effective price of 105% using an approximate proration factor of 52.3% of total notes tendered. During June 2012, AmeriGas Partners repurchased approximately $19.2 aggregate principal amount of outstanding 7.00% Notes. The Partnership recorded a net loss of $13.3 on these extinguishments of debt which amount is reflected on the Fiscal 2012 Consolidated Statement of Income under the caption loss on extinguishments of debt. The net loss reduced net income attributable to UGI Corporation by $2.2 during Fiscal 2012.
In January 2011, AmeriGas Partners issued $470 principal amount of 6.50% Notes due May 2021. The proceeds from the issuance of the 6.50% Notes were used in February 2011 to repay AmeriGas Partners’ $415 principal amount of its 7.25% Senior Notes due May 2015 pursuant to a tender offer and subsequent redemption. In addition, in February 2011, AmeriGas Partners redeemed the outstanding $14.6 principal amount of its 8.875% Senior Notes due May 2011. The Partnership incurred a loss of $18.8 on these extinguishments of debt which amount is reflected on the Fiscal 2011 Consolidated Statement of Income under the caption loss on extinguishments of debt. This loss reduced net income attributable to UGI Corporation by $5.2 during Fiscal 2011.
In August 2011, AmeriGas Partners issued $450 principal amount of 6.25% Senior Notes due August 2019 (the “ 6.25% Senior Notes”). The proceeds from the issuance of the 6.25% Senior Notes were used to repay $350 principal amount of AmeriGas Partners 7.125% Senior Notes due May 2016 pursuant to a tender offer and subsequent redemption. The Partnership incurred a loss of $19.3 on this extinguishment of debt which amount is reflected on the Fiscal 2011 Consolidated Statement of Income under the caption loss on extinguishments of debt. This loss reduced net income attributable to UGI Corporation by $5.2 during Fiscal 2011.
The 6.50% and 6.25% Senior Notes generally may be redeemed at our option (pursuant to a tender offer). A redemption premium applies through May 2019 (with respect to the 6.50% Notes) and through August 2017 (with respect to the 6.25% Notes). In addition, in the event that AmeriGas Partners completes a registered public offering of Common Units, the Partnership may, at its option, redeem up to 35% of the outstanding 6.50% Notes (through May 20, 2014) or 35% of the outstanding 6.25% Notes (through August 20, 2014), each at a premium. AmeriGas Partners may, under certain circumstances involving excess sales proceeds

F-26

Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

from the disposition of assets not reinvested in the business or a change of control, be required to offer to prepay its 6.50% and 6.25% Senior Notes.
The Partnership’s total long-term debt at September 30, 2013, includes $ 32.0 of HOLP Senior Secured Notes (including unamortized premium of $3.7 ). At September 30, 2013, the face interest rates on the HOLP Notes range from 7.89% to 8.87% with an effective interest rate of 6.75% . The HOLP Senior Secured Notes are collateralized by AmeriGas OLP’s receivables, contracts, equipment, inventory, general intangibles and cash.
AmeriGas OLP has an unsecured credit agreement (the “AmeriGas Credit Agreement”) with a group of banks providing for borrowings up to $525 (including a $125 sublimit for letters of credit) which expires in October 2016. The AmeriGas Credit Agreement permits AmeriGas OLP to borrow at prevailing interest rates, including the base rate, defined as the higher of the Federal Funds rate plus 0.50% or the agent bank’s prime rate, or at a one-week, one-, two-, three-, or six-month Eurodollar Rate, as defined in the AmeriGas Credit Agreement, plus a margin. The margin on base rate borrowings (which ranges from 0.75% to 1.75% ), Eurodollar Rate borrowings (which ranges from 1.75% to 2.75% ), and the AmeriGas Credit Agreement facility fee rate (which ranges from 0.30% to 0.50% ) are dependent upon AmeriGas Partners’ ratio of debt to earnings before interest expense, income taxes, depreciation and amortization (“EBITDA”), each as defined in the AmeriGas Credit Agreement.
At September 30, 2013 and 2012 , there were $116.9 and $49.9 , respectively, of borrowings outstanding under the AmeriGas Credit Agreement, which amounts are reflected as bank loans on the Consolidated Balance Sheets. The weighted-average interest rates on AmeriGas Credit Agreement borrowings at September 30, 2013 and 2012 , were 2.69% and 2.72% , respectively. At September 30, 2013 and 2012 , issued and outstanding letters of credit, which reduce available borrowings under the AmeriGas Credit Agreement, totaled $53.7 and $47.9 , respectively.
Restrictive Covenants.  The AmeriGas Partners Senior Notes restrict the ability of the Partnership and AmeriGas OLP to, among other things, incur additional indebtedness, make investments, incur liens, issue preferred interests, prepay subordinated indebtedness, and effect mergers, consolidations and sales of assets. Under the AmeriGas Partners Senior Notes Indentures, AmeriGas Partners is generally permitted to make cash distributions equal to Available Cash, as defined, as of the end of the immediately preceding quarter, if certain conditions are met. At September 30, 2013 , these restrictions did not limit the amount of Available Cash. See Note 15 for definition of Available Cash included in the Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, L.P. (“Partnership Agreement”).
The HOLP Senior Secured Notes contain restrictive covenants including the maintenance of financial covenants and limitations on the disposition of assets, changes in ownership, additional indebtedness, restrictive payments and the creation of liens. The financial covenants require AmeriGas OLP to maintain a ratio of Consolidated Funded Indebtedness to Consolidated EBITDA (as defined) below certain thresholds and to maintain a minimum ratio of Consolidated EBITDA to Consolidated Interest Expense (as defined).
The AmeriGas Credit Agreement restricts the incurrence of additional indebtedness and also restrict certain liens, guarantees, investments, loans and advances, payments, mergers, consolidations, asset transfers, transactions with affiliates, sales of assets, acquisitions and other transactions. The AmeriGas Credit Agreement requires that the Partnership and AmeriGas OLP maintain ratios of total indebtedness to EBITDA, as defined, below certain thresholds. In addition, the Partnership must maintain a minimum ratio of EBITDA to interest expense, as defined, as calculated on a rolling four-quarter basis. Generally, as long as no default exists or would result, the Partnership and AmeriGas OLP are permitted to make cash distributions not more frequently than quarterly in an amount not to exceed available cash, as defined, for the immediately preceding calendar quarter.
UGI International
In March 2011, Antargaz entered into a five -year Senior Facilities Agreement with a consortium of banks (“Senior Facilities Agreement”) consisting of a €380 ( $514.0 ) variable-rate term loan and a €40 credit facility. The proceeds from the Senior Facilities Agreement term loan were used to repay Antargaz’ then-existing Senior Facilities Agreement term loan due March 2011.
Scheduled maturities under the term loan are €38 ( $51.4 ) due May 2014, €34.2 ( $46.3 ) due May 2015, and €307.8 ( $416.3 ) due March 2016. Borrowings under the Senior Facilities Agreement bear interest at one-, two-, three- or six-month euribor, plus a margin, as defined by the Senior Facilities Agreement. There were no amounts outstanding under the Senior Facilities Agreement at September 30, 2013 or 2012 . The margin on the term loan and credit facility borrowings (which ranges from 1.75% to 2.50% ) is dependent upon the ratio of Antargaz’ total net debt to EBITDA, each as defined in the Senior Facilities Agreement. Antargaz has entered into pay-fixed, receive-variable interest rate swaps to fix the underlying euribor rate of interest on the term loan at an average rate of approximately 2.45% through September 2015 and, thereafter, at a rate of 3.71% through the date of the term loan’s

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

final maturity in March 2016. At September 30, 2013 and 2012 , the effective interest rates on Antargaz’ term loan were 4.41% and 4.66% , respectively. The Senior Facilities Agreement is collateralized by substantially all of Antargaz’ shares in its subsidiaries and by substantially all of its accounts receivables.
In order to finance the purchase of BP’s LPG distribution business in Poland in September 2013, Flaga entered into a $52 U.S. dollar-denominated three-year term loan which matures in September 2016. The $52 loan bears interest at one- to twelve-month euribor rates (as chosen by Flaga from time to time) plus a margin of 1.25% . Flaga has effectively fixed the euribor component of the interest rate, and has effectively fixed the U.S. dollar value of the interest and principal payments payable under the $52 loan, by entering into a cross-currency swap arrangement with a bank. At September 30, 2013, the effective interest rate on the $52 loan was 1.82% .
In December 2011, Flaga entered into a €19.1 ( $25.8 ) euro-based variable-rate term loan agreement. Proceeds from the term loan were used, in large part, to fund Flaga’s October 2011 acquisition of Shell’s LPG propane businesses in Finland, Norway, Sweden and Denmark. The term loan matures in October 2016 and bears interest at three-month euribor rates plus a margin. The margin on such borrowings ranges from 1.175 % to 2.525 % and is based upon certain consolidated equity, return on assets and debt to EBITDA ratios. Flaga has effectively fixed the euribor component of the interest rate on this term loan at 1.79 % by entering into an interest rate swap agreement. The effective interest rates on this term loan at September 30, 2013 and 2012, was 3.85% and 4.35% , respectively.
In September 2011, Flaga entered into a €40 euro-based variable-rate term loan of which €26.7 ( $36.1 ) matures in August 2016 and €13.3 ( $18.0 ) matures in September 2016. A portion of the proceeds from the loan were used to repay its €24.0 euro-based variable-rate term loan which matured during Fiscal 2011. The €40 euro-based term loan bears interest at one- to twelve-month euribor rates (as chosen by Flaga from time to time) plus a margin. The margin on such borrowings ranges from 0.23% to 2.55% and is based upon certain consolidated equity, return on assets and debt to EBITDA ratios. Flaga has effectively fixed the euribor component of its interest rate on this term loan through September 2016 at 2.68% by entering into interest rate swap agreements. The effective interest rates on Flaga’s term loans at September 30, 2013 and 2012 , were 4.68% and 5.18% , respectively.
As of September 30, 2013 and 2012 , Flaga also has a euro-based variable-rate term loan which had outstanding principal balances of €1.4 ( $1.9 ) and €2.8 ( $3.6 ), respectively. This term loan matures in June 2014 and bears interest at three-month euribor rates plus a margin. The margin on such borrowings ranges from 2.625% to 3.50% and is based upon certain consolidated equity, return on assets and debt to EBITDA ratios. Semi-annual principal payments of €0.7 are due on December 31 and June 30 each year through June 2014. Flaga has effectively fixed the euribor component of the interest rate on this term loan at 2.16% by entering into an interest rate swap agreement. As of September 30, 2013 and 2012 , the effective interest rate on this term loan was 5.04% .
At September 30, 2013 , Flaga has two principal working capital facilities (the “Flaga Credit Agreements”) comprising (1) a €46 multi-currency working capital facility which includes an uncommitted €6 overdraft facility (the “Multi-Currency Working Capital Facility”) and (2) a euro-denominated working capital facility that provides for borrowings and issuances of guarantees totaling €12 (the “Euro Working Capital Facility”). Both the Multi-Currency Working Capital Facility and the Euro Working Capital Facility expire in September 2014. At September 30, 2013 and 2012 , there were €0.2 ( $0.3 ) and €11.9 ( $15.3 ) of borrowings outstanding under the Flaga Credit Agreements. These amounts are reflected as bank loans on the Consolidated Balance Sheets.
Borrowings under the Flaga Credit Agreements generally bear interest at market rates (a daily euro-based rate or three-month euribor rates) plus a margin. The weighted-average interest rates on Flaga Credit Agreements borrowings at September 30, 2013 and 2012 , were 4.21% and 2.31% , respectively. Issued and outstanding letters of credit, which reduce available borrowings under the Flaga Credit Agreements, totaled €28.6 ( $38.7 ) and €19.2 ( $24.7 ) at September 30, 2013 and 2012 , respectively.
Restrictive Covenants and Guarantees. The Senior Facilities Agreement restricts the ability of Antargaz to, among other things, incur additional indebtedness, make investments, incur liens, and effect mergers, consolidations and sales of assets, and requires Antargaz to maintain a ratio of net debt to EBITDA on a French generally accepted accounting basis, as defined in the agreement, that shall not exceed 3.50 to 1.00. Under this agreement, Antargaz is generally permitted to make restricted payments, such as dividends if no event of default exists or would exist upon payment of such restricted payment. UGI has guaranteed up to €100 of payments under the Senior Facilities Agreement.
The Flaga term loans, working capital facilities and interest rate and cross currency agreements are guaranteed by UGI. In addition, under certain conditions regarding changes in certain financial ratios of UGI, the lending banks may accelerate repayment of the debt.

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

UGI Utilities
In September 2013, UGI Utilities entered into a 364 -day term loan credit agreement (“UGI Utilities Term Loan Credit Agreement”) with a bank comprising a $175 unsecured term loan facility. The UGI Utilities Term Loan Credit Agreement bears interest at the eurodollar rate for the interest period selected, plus a margin of 0.60% . The UGI Utilities Term Loan Credit Agreement terminates on September 22, 2014, but UGI Utilities may prepay the loan in whole or in part, without penalty. UGI Utilities borrowed $175 on September 30, 2013, under the UGI Utilities Term Loan Credit Agreement which cash proceeds were used to repay UGI Utilities’ $108 million 6.375% Senior Notes due September 30, 2013, and for other general corporate purposes. On October 30, 2013, UGI Utilities entered into a Note Purchase Agreement which provides for the private placement of $175 aggregate principal amount of 4.98% Senior Notes due March 26, 2044. UGI Utilities expects to use net proceeds from the issuance of $175 face amount of 4.98% Senior Notes in March 2014 to repay then-outstanding borrowings under the UGI Utilities Term Loan Credit Agreement. Because the Company has the intent and ability to refinance the UGI Utilities Term Loan Credit Agreement on a long-term basis, amounts outstanding under the UGI Utilities Term Loan Agreement are classified as long-term on the September 30, 2013 Consolidated Balance Sheet.
UGI Utilities has an unsecured credit agreement (“UGI Utilities Credit Agreement”) with a group of banks providing for borrowings up to $300 (including a $100 sublimit for letters of credit) which expires in October 2015. Under the UGI Utilities 2011 Credit Agreement, UGI Utilities may borrow at various prevailing market interest rates, including LIBOR and the banks’ prime rate, plus a margin. The margin on such borrowings ranges from 0.0% to 2.0% and is based upon the credit ratings of certain indebtedness of UGI Utilities. UGI Utilities had $17.5 and $9.2 of borrowings outstanding under the UGI Utilities Credit Agreement at September 30, 2013 and 2012 , respectively, which amounts are reflected in bank loans on the Consolidated Balance Sheets. The weighted-average interest rates on UGI Utilities Credit Agreement borrowings at September 30, 2013 and 2012 were 1.18% and 1.21% , respectively. Issued and outstanding letters of credit, which reduce available borrowings under the UGI Utilities Credit Agreement, totaled $2.0 at September 30, 2013 and 2012 .
Restrictive Covenants. UGI Utilities Credit Agreement requires UGI Utilities not to exceed a ratio of Consolidated Debt to Consolidated Total Capital, as defined, of 0.65 to 1.00 .
Energy Services
Energy Services has an unsecured credit agreement (“Energy Services Credit Agreement”) with a group of lenders providing for borrowings of up to $240 (including a $50 sublimit for letters of credit) which expires in June 2016. The Energy Services Credit Agreement can be used for general corporate purposes of Energy Services and its subsidiaries. In addition, Energy Services may not pay a dividend unless, after giving effect to such dividend payment, the ratio of Consolidated Total Indebtedness to EBITDA, each as defined in the Energy Services Credit Agreement, does not exceed 2.25 to 1.00 . There were $57 and $85 of borrowings outstanding under the Energy Services Credit Agreement at September 30, 2013 and 2012 , respectively. These amounts are reflected as bank loans on the Consolidated Balance Sheets.
Borrowings under the Energy Services Credit Agreement bear interest at either (i) a rate derived from LIBOR (the “LIBO Rate”) plus 2.5% for each Eurodollar Revolving Loan (as defined in the Energy Services Credit Agreement) or (ii) the Alternate Base Rate plus 1.5% . The Alternate Base Rate (as defined in the Energy Services Credit Agreement) is generally the greater of (a) the Agent Bank’s prime rate, (b) the federal funds rate plus 0.50% and (c) the one-month LIBO Rate plus 1.0% . The weighted-average interest rates on the Energy Services Credit Agreement borrowings at September 30, 2013 and 2012 , were 2.91% and 3.25% , respectively. The Energy Services Credit Agreement is guaranteed by certain subsidiaries of Energy Services.
Restrictive Covenants. The Energy Services Credit Agreement restricts the ability of Energy Services to dispose of assets, effect certain consolidations or mergers, incur indebtedness and guaranty obligations, create liens, make acquisitions or investments, make certain dividend or other distributions and make any material changes to the nature of its businesses. In addition, the Energy Services Credit Agreement requires Energy Services to not exceed a ratio of Consolidated Total Indebtedness, as defined, to Consolidated EBITDA, as defined; a minimum ratio of Consolidated EBITDA to Consolidated Interest Expense, as defined; a maximum ratio of Consolidated Total Indebtedness to Consolidated Total Capitalization, as defined, at any time when Consolidated Total Indebtedness is greater than $250 ; and a minimum Consolidated Net Worth, as defined, of $200 .
Energy Services also has a receivables securitization facility (see Note 19 ).

F-29

Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Restricted Net Assets
At September 30, 2013 , the amount of net assets of UGI’s consolidated subsidiaries that was restricted from transfer to UGI under debt agreements, subsidiary partnership agreements and regulatory requirements under foreign laws totaled approximately $1,500 .

Note 7 — Income Taxes
Income before income taxes comprises the following:

	
												
 	2013	 	2012	 	2011	
Domestic	$	494.1		 	$	245.6		 	$	415.2		
Foreign	96.3		 	59.0		 	50.2		
Total income before income taxes	$	590.4		 	$	304.6		 	$	465.4		

The provisions for income taxes consist of the following:

	
												
 	2013	 	2012	 	2011	
Current expense (benefit):	 	 	 	 	 	
Federal	$	53.3		 	$	(10.4	)	 	$	24.4		
State	25.1		 	11.2		 	14.5		
Foreign	37.3		 	18.8		 	15.0		
Investment tax credit	(1.6	)	 	(2.9	)	 	—		
Total current expense	114.1		 	16.7		 	53.9		
Deferred expense (benefit):	 	 	 	 	 	
Federal	54.6		 	81.7		 	86.0		
State	(0.7	)	 	7.0		 	4.5		
Foreign	(4.9	)	 	1.8		 	1.4		
Investment tax credit amortization	(0.3	)	 	(0.3	)	 	(0.4	)	
Total deferred expense	48.7		 	90.2		 	91.5		
Total income tax expense	$	162.8		 	$	106.9		 	$	145.4		

Federal income taxes for Fiscal 2013 and Fiscal 2012 are net of foreign tax credits of $34.9 and $5.2 , respectively.
A reconciliation from the U.S. federal statutory tax rate to our effective tax rate is as follows:

	
									
 	2013	 	2012	 	2011	
U.S. federal statutory tax rate	35.0	 %	 	35.0	 %	 	35.0	 %	
Difference in tax rate due to:	 	 	 	 	 	
Noncontrolling interests not subject to tax	(8.7	)	 	1.2		 	(5.6	)	
State income taxes, net of federal benefit	3.4		 	4.0		 	2.4		
Valuation allowance adjustments	(0.5	)	 	(1.5	)	 	—		
Effects of foreign operations	(1.8	)	 	(3.3	)	 	(0.5	)	
Other, net	0.2		 	(0.3	)	 	(0.1	)	
Effective tax rate	27.6	 %	 	35.1	 %	 	31.2	 %	

F-30

Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

The effects of foreign operations in the table above for Fiscal 2012 reflects the impact of tax efficient structuring of certain of our international operations and, as a result of the Fiscal 2012 Shell Transaction, also reflects a greater proportion of pretax income in countries in which the statutory income tax rate is less than the U.S. statutory tax rate. The tax restructuring of certain of our international operations also permitted us to reduce our foreign tax credit valuation allowance by $4.6 during Fiscal 2012 which is included as a valuation allowance adjustment in the table above.
Earnings of the Company’s foreign subsidiaries are generally subject to U.S. taxation upon repatriation to the U.S. and the Company’s tax provision reflects the related incremental U.S. tax except for certain foreign subsidiaries whose unremitted earnings are considered to be indefinitely reinvested. Because of the availability of U.S. foreign tax credits, it is likely no U.S. tax would be due if such earnings were repatriated.
Pennsylvania utility ratemaking practice permits the flow through to ratepayers of state tax benefits resulting from accelerated tax depreciation. For Fiscal 2013, Fiscal 2012 and Fiscal 2011, the beneficial effects of state tax flow through of accelerated depreciation reduced income tax expense by $1.5 , $3.2 and $7.9 , respectively. The state tax flow through amounts in Fiscal 2012 and Fiscal 2011 reflect the impact of 2010 U.S. Federal tax legislation that allowed taxpayers to fully deduct qualifying capital expenditures incurred after September 8, 2010, through the end of calendar 2011, when such property was placed in service before 2012. This legislation was also permitted for Pennsylvania state corporate income tax purposes.
Deferred tax liabilities (assets) comprise the following at September 30:

								
 	2013	 	2012	
Excess book basis over tax basis of property, plant and equipment	$	626.9		 	$	582.0		
Investment in AmeriGas Partners	313.0		 	292.8		
Intangible assets and goodwill	65.1		 	61.2		
Utility regulatory assets	101.6		 	140.4		
Foreign currency translation adjustment	9.5		 	3.6		
Other	2.7		 	4.1		
Gross deferred tax liabilities	1,118.8		 	1,084.1		
 	 	 	 	
Pension plan liabilities	(36.2	)	 	(72.7	)	
Employee-related benefits	(47.9	)	 	(43.0	)	
Operating loss carryforwards	(32.1	)	 	(33.4	)	
Foreign tax credit carryforwards	(81.8	)	 	(55.5	)	
Utility regulatory liabilities	(15.5	)	 	(11.8	)	
Derivative financial instruments	(15.0	)	 	(37.7	)	
Other	(20.5	)	 	(31.1	)	
Gross deferred tax assets	(249.0	)	 	(285.2	)	
Deferred tax assets valuation allowance	97.6		 	77.0		
Net deferred tax liabilities	$	967.4		 	$	875.9		

At September 30, 2013 , foreign net operating loss carryforwards principally relating to Flaga and certain operations of Antargaz totaled $47.7 and $5.3 , respectively, with no expiration dates. We have state net operating loss carryforwards primarily relating to certain subsidiaries which approximate $224.9 and expire through 2033 . We also have operating loss carryforwards of $15.7 for certain operations of AmeriGas Propane that expire through 2033 . At September 30, 2013 , deferred tax assets relating to operating loss carryforwards include $11.0 for Flaga, $1.8 for Antargaz, $0.9 for UGI International Holdings BV, $6.1 for AmeriGas Propane and $17.6 for certain other subsidiaries. A valuation allowance of $13.5 has been provided for deferred tax assets related to state net operating loss carryforwards and other state deferred tax assets of certain subsidiaries because, on a state reportable basis, it is more likely than not that these assets will expire unused. Valuation allowances for net operating loss tax benefits decreased by $4.7 primarily due to changes in entities that will now allow carryforward use of previously incurred losses. A valuation allowance of $7.9 was also provided for deferred tax assets related to certain operations of Antargaz, Flaga and UGI International Holdings BV. Operating activities and tax deductions related to the exercise of non-qualified stock options contributed to the state net operating losses disclosed above. We first recognize the utilization of state net operating losses from operations

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

(which exclude the impact of tax deductions for exercises of non-qualified stock options) to reduce income tax expense. Then, to the extent state net operating loss carryforwards, if realized, relate to non-qualified stock option deductions, the resulting benefits will be credited to UGI Corporation stockholders’ equity. The table of deferred tax assets and liabilities do not include $5.6 for Fiscal 2013 and $4.6 for Fiscal 2012 of deferred tax assets and associated valuation allowance for unrealized state tax benefits for equity compensation deductions.
We have foreign tax credit carryforwards of approximately $81.8 expiring through 2023 resulting from the actual and planned repatriation of Antargaz’ accumulated earnings since acquisition which are includable in U.S. taxable income. Because we expect that these credits will expire unused, a valuation allowance has been provided for the entire foreign tax credit carryforward amount. The valuation allowance for all deferred tax assets increased by $20.6 in Fiscal 2013 due to an increase in unusable foreign tax credits of $26.3 partially offset by decreases in unusable state and federal operating loss tax benefits of $4.7 and $1.0 , respectively, as a result of changes in entity status.
We conduct business and file tax returns in the U.S., numerous states, local jurisdictions and in France and certain other European countries. Our U.S. federal income tax returns are settled through the 2009 tax year, our French tax returns are settled through the 2009 tax year. Our Austrian tax returns are settled through 2007 and our other European tax returns are effectively settled for various years from 2005 to 2010. State and other income tax returns in the U.S. are generally subject to examination for a period of three to five years after the filing of the respective returns.
As of September 30, 2013 , we have unrecognized income tax benefits totaling $3.6 including related accrued interest of $0.2 . If these unrecognized tax benefits were subsequently recognized, $2.4 would be recorded as a benefit to income taxes on the Consolidated Statement of Income and, therefore, would impact the reported effective tax rate. Generally, a net reduction in unrecognized tax benefits could occur because of the expiration of the statute of limitations in certain jurisdictions or as a result of settlements with tax authorities. Included in the balance at September 30, 2013 , are $1.1 of tax positions for which the deductibility is highly certain but for which there is uncertainty about the timing of such deductibility. Because of the impact of deferred tax accounting, the disallowance of the current deduction would not affect the annual effective tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. There is an expected change in unrecognized tax benefits and related interest in the next twelve months in the amount of $0.7 .
A reconciliation of the beginning and ending amounts of unrecognized tax benefits is as follows:

	
				
Balance at September 30, 2010	$	5.4		
Additions for tax positions of the current year	0.4		
Additions for tax positions taken in prior years	1.0		
Settlements with tax authorities	(0.5	)	
Balance at September 30, 2011	6.3		
Additions for tax positions of the current year	0.5		
Additions for tax positions taken in prior years	0.6		
Settlements with tax authorities	(4.5	)	
Balance at September 30, 2012	2.9		
Additions for tax positions of the current year	0.7		
Settlements with tax authorities	(0.2	)	
Balance at September 30, 2013	$	3.4		

Note 8 — Employee Retirement Plans
Defined Benefit Pension and Other Postretirement Plans. In the U.S., we currently sponsor one defined benefit pension plan for employees hired prior to January 1, 2009, of UGI, UGI Utilities, PNG, CPG and certain of UGI’s other domestic wholly owned subsidiaries (“U.S. Pension Plan”).
We also provide postretirement health care benefits to certain retirees and active employees and postretirement life insurance benefits to nearly all domestic active and retired employees. In addition, Antargaz employees are covered by certain defined

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

benefit pension and postretirement plans. Although the disclosures in the tables below include amounts related to the Antargaz plans, such amounts are not material.
The following table provides a reconciliation of the projected benefit obligations (“PBOs”) of the U.S. Pension Plan and the Antargaz pension plans, the accumulated benefit obligations (“ABOs”) of our other postretirement benefit plans, plan assets, and the funded status of pension and other postretirement plans as of September 30, 2013 and 2012 . ABO is the present value of benefits earned to date with benefits based upon current compensation levels. PBO is ABO increased to reflect estimated future compensation.

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

	
																
 	Pension
Benefits	 	Other Postretirement
Benefits	
 	2013	 	2012	 	2013	 	2012	
Change in benefit obligations:	 	 	 	 	 	 	 	
Benefit obligations — beginning of year	$	573.4		 	$	462.9		 	$	24.7		 	$	20.5		
Service cost	11.3		 	9.3		 	0.6		 	0.4		
Interest cost	23.8		 	25.1		 	0.9		 	1.1		
Actuarial (gain) loss	(72.7	)	 	82.4		 	(3.6	)	 	3.2		
Plan amendments	1.0		 	0.1		 	(1.8	)	 	1.0		
Acquisitions	—		 	14.6		 	—		 	—		
Foreign currency	1.5		 	(0.7	)	 	0.2		 	(0.1	)	
Benefits paid	(21.8	)	 	(20.3	)	 	(1.3	)	 	(1.4	)	
Benefit obligations — end of year	$	516.5		 	$	573.4		 	$	19.7		 	$	24.7		
 	 	 	 	 	 	 	 	
Change in plan assets:	 	 	 	 	 	 	 	
Fair value of plan assets — beginning of year	$	369.9		 	$	290.0		 	$	11.2		 	$	9.8		
Actual gain on plan assets	42.2		 	51.2		 	1.1		 	1.7		
Foreign currency	0.8		 	(0.5	)	 	—		 	—		
Employer contributions	24.2		 	32.2		 	0.7		 	1.1		
Acquisitions	—		 	17.3		 	—		 	—		
Benefits paid	(21.8	)	 	(20.3	)	 	(1.3	)	 	(1.4	)	
Fair value of plan assets — end of year	$	415.3		 	$	369.9		 	$	11.7		 	$	11.2		
Funded status of the plans — end of year	$	(101.2	)	 	$	(203.5	)	 	$	(8.0	)	 	$	(13.5	)	
 	 	 	 	 	 	 	 	
Assets (liabilities) recorded in the balance sheet:	 	 	 	 	 	 	 	
Assets in excess of liabilities — included in other noncurrent assets	$	—		 	$	—		 	$	3.2		 	$	—		
Unfunded liabilities — included in other current liabilities	(17.9	)	 	(15.8	)	 	(0.4	)	 	(0.6	)	
Unfunded liabilities — included in other noncurrent liabilities	(83.3	)	 	(187.7	)	 	(10.8	)	 	(12.9	)	
Net amount recognized	$	(101.2	)	 	$	(203.5	)	 	$	(8.0	)	 	$	(13.5	)	
 	 	 	 	 	 	 	 	
Amounts recorded in UGI Corporation stockholders’ equity (pre-tax):	 	 	 	 	 	 	 	
Prior service credit	$	(0.1	)	 	$	(0.1	)	 	$	(0.1	)	 	$	(0.1	)	
Net actuarial loss (gain)	16.7		 	25.3		 	(0.4	)	 	0.4		
Total	$	16.6		 	$	25.2		 	$	(0.5	)	 	$	0.3		
 	 	 	 	 	 	 	 	
Amounts recorded in regulatory assets and liabilities (pre-tax):	 	 	 	 	 	 	 	
Prior service cost (credit)	$	2.2		 	$	1.5		 	$	(4.3	)	 	$	(2.8	)	
Net actuarial loss	91.3		 	184.5		 	3.6		 	5.8		
Total	$	93.5		 	$	186.0		 	$	(0.7	)	 	$	3.0		

In Fiscal 2014 , we estimate that we will amortize approximately $7.8 of net actuarial losses, primarily associated with the U.S. Pension Plan, and $0.2 of prior service credits from UGI stockholders’ equity and regulatory assets into retiree benefit cost.
Actuarial assumptions for our domestic plans are described below. Assumptions for the Antargaz plans are based upon market conditions in France. The discount rate assumption was determined by selecting a hypothetical portfolio of high quality corporate bonds appropriate to provide for the projected benefit payments of the plans. The discount rate was then developed as

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

the single rate that equates the market value of the bonds purchased to the discounted value of the plans’ benefit payments. The expected rate of return on assets assumption is based on the current and expected asset allocations as well as historical and expected returns on various categories of plan assets (as further described below).

	
																				
 	Pension Plan	 	 	Other Postretirement Benefits	 	
 	2013	 	2012	 	2011 (a)	 	 	2013	 	2012	 	2011	 	
Weighted-average assumptions:	 	 	 	 	 	 	 	 	 	 	 	 	 	
Discount rate - benefit obligations	5.20	%	 	4.20	%	 	5.30	%	 	 	5.10% - 5.40%		 	4.10% - 4.30%		 	5.30	%	 	
Discount rate - benefit cost	4.20	%	 	5.30	%	 	5.00	%	 	 	4.10% - 4.30%		 	5.30	%	 	5.00	%	 	
Expected return on plan assets	7.75	%	 	7.75	%	 	8.00	%	 	 	5.00	%	 	5.20	%	 	5.50	%	 	
Rate of increase in salary levels	3.25	%	 	3.25	%	 	3.50	%	 	 	3.25	%	 	3.25	%	 	3.50	%	 	
______________
		
(a)	Effective December 31, 2010, we merged our then-existing two U.S. defined benefit pension plans (“U.S. Pension Plans Merger”) to form the U.S. Pension Plan. The discount rates used during Fiscal 2011 to calculate pension expense were rates of 5.0% through December 31, 2010 (the date of the U.S. Pension Plans Merger) and 5.5% for the remainder of Fiscal 2011.	
The ABOs for the U.S. Pension Plan were $451.3 and $496.4 as of September 30, 2013 and 2012 , respectively.
Net periodic pension expense and other postretirement benefit cost includes the following components:

																								
 	Pension Benefits	 	Other Postretirement Benefits	
 	2013	 	2012	 	2011	 	2013	 	2012	 	2011	
Service cost	$	11.3		 	$	9.3		 	$	8.8		 	$	0.6		 	$	0.4		 	$	0.4		
Interest cost	23.8		 	25.1		 	24.1		 	0.9		 	1.1		 	1.1		
Expected return on assets	(27.8	)	 	(26.2	)	 	(25.8	)	 	(0.5	)	 	(0.5	)	 	(0.5	)	
Curtailment gain	—		 	—		 	—		 	—		 	—		 	(3.2	)	
Amortization of:	 	 	 	 	 	 	 	 	 	 	 	
Prior service cost (benefit)	0.3		 	0.2		 	0.2		 	(0.3	)	 	(0.3	)	 	(0.7	)	
Actuarial loss	15.1		 	8.4		 	7.5		 	0.4		 	0.3		 	0.4		
Net benefit cost (income)	22.7		 	16.8		 	14.8		 	1.1		 	1.0		 	(2.5	)	
Change in associated regulatory liabilities	—		 	—		 	—		 	3.3		 	3.2		 	3.1		
Net benefit cost after change in regulatory liabilities	$	22.7		 	$	16.8		 	$	14.8		 	$	4.4		 	$	4.2		 	$	0.6		

U.S. Pension Plan’s assets are held in trust. It is our general policy to fund amounts for U.S. Pension Plan benefits equal to at least the minimum required contribution set forth in applicable employee benefit laws. From time to time we may, at our discretion, contribute additional amounts. During Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , we made cash contributions to the U.S. Pension Plan of $22.4 , $31.2 and $18.7 respectively. We believe that in Fiscal 2014 we will be required to make contributions to the U.S. Pension Plan totaling approximately $18 .
UGI Utilities has established a Voluntary Employees’ Beneficiary Association (“VEBA”) trust to pay retiree health care and life insurance benefits by depositing into the VEBA the annual amount of postretirement benefits costs determined under GAAP. The difference between such amounts and amounts included in UGI Gas’ and Electric Utility’s rates is deferred for future recovery from, or refund to, ratepayers. The required contributions to the VEBA during Fiscal 2014 are not expected to be material.

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Expected payments for pension benefits and for other postretirement welfare benefits are as follows:

								
 	Pension
Benefits	 	Other
Postretirement
Benefits	
Fiscal 2014	$	24.6		 	$	1.4		
Fiscal 2015	24.4		 	1.2		
Fiscal 2016	26.1		 	1.2		
Fiscal 2017	28.8		 	1.1		
Fiscal 2018	30.4		 	1.1		
Fiscal 2019 - 2023	164.3		 	5.3		

The assumed domestic health care cost trend rates for Fiscal 2013 are 7.0% during Fiscal 2013, decreasing to 5.0% in Fiscal 2017. The assumed domestic health care cost trend rates as of September 30, 2013, are 7.5%  decreasing to 5.0% in Fiscal 2019. A one percentage point change in the assumed health care cost trend rate would not have a material impact on the Fiscal 2012 other postretirement benefit cost or September 30, 2013 , other postretirement benefit ABO.
We also sponsor unfunded and non-qualified supplemental executive retirement plans (“Supplemental Defined Benefit Plans”). At September 30, 2013 and 2012 , the PBOs of these plans were $33.9 and $29.5 , respectively. We recorded pre-tax costs for these plans of $3.0 in Fiscal 2013 , $3.0 in Fiscal 2012 and $3.0 in Fiscal 2011 . These costs are not included in the tables above. Amounts recorded in UGI’s stockholders’ equity for these plans include pre-tax losses of $9.4 and $11.0 at September 30, 2013 and 2012 , respectively, principally representing unrecognized actuarial losses. We expect to amortize approximately $0.6 of such pre-tax actuarial losses into retiree benefit cost in Fiscal 2014 . During Fiscal 2013, the Company made payments with respect to the Supplemental Defined Benefit Plans totaling $21.6 , including $21.0 to fund self-directed grantor trusts established by the Company for participants who chose to defer their Supplemental Defined Benefit Plan payment upon retirement. The total fair value of these trust assets, which are included in other assets on the Consolidated Balance Sheets, totaled $23.7 million and $2.0 million at September 30, 2013 and 2012, respectively.
U.S. Pension Plan and VEBA Assets. The assets of the U.S. Pension Plan and the VEBA are held in trust. The investment policies and asset allocation strategies for the assets in these trusts are determined by an investment committee comprising officers of UGI and UGI Utilities. The overall investment objective of the U.S. Pension Plan and the VEBA is to achieve the best long-term rates of return within prudent and reasonable levels of risk. To achieve the stated objective, investments are made principally in publicly-traded diversified equity and fixed income mutual funds and UGI Common Stock.
The targets, target ranges and actual allocations for the U.S. Pension Plan and VEBA trust assets at September 30 are as follows:
U.S. Pension Plan

											
 	Actual	 	Target
Asset
Allocation	 	Permitted
Range	
 	2013	 	2012	 		 		
Equity investments:	 	 	 	 	 	 	 	
Domestic	57.5	%	 	53.5	%	 	52.5	%	 	40.0% - 65.0%	
International	11.1	%	 	10.5	%	 	12.5	%	 	7.5% - 17.5%	
Total	68.6	%	 	64.0	%	 	65.0	%	 	60.0% - 70.0%	
Fixed income funds & cash equivalents	31.4	%	 	36.0	%	 	35.0	%	 	30.0% - 40.0%	
Total	100.0	%	 	100.0	%	 	100.0	%	 	 	

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

VEBA

											
 	Actual	 	Target
Asset
Allocation	 	Permitted
Range	
 	2013	 	2012	 		 		
Domestic equity investments	65.6	%	 	68.5	%	 	65.0	%	 	60.0% - 70.0%	
Fixed income funds & cash equivalents	34.4	%	 	31.5	%	 	35.0	%	 	30.0% - 40.0%	
Total	100.0	%	 	100.0	%	 	100.0	%	 	 	

Domestic equity investments include investments in large-cap mutual funds indexed to the S&P 500 and actively managed mid- and small-cap mutual funds. Investments in international equity mutual funds seek to track performance of companies primarily in developed markets. The fixed income investments comprise investments designed to match the performance and duration of the Barclays U.S. Aggregate Index. According to statute, the aggregate holdings of all qualifying employer securities may not exceed 10% of the fair value of trust assets at the time of purchase. UGI Common Stock represented 8.2% and 7.5% of U.S. Pension Plan assets at September 30, 2013 and 2012 , respectively.
GAAP establishes a hierarchy that prioritizes fair value measurements based upon the inputs and valuation techniques used to measure fair value. This fair value hierarchy groups assets into three levels, as described in Note 2 . We maximize the use of observable inputs and minimize the use of unobservable inputs when determining fair value. The fair values of U.S. Pension Plan and VEBA trust assets are derived from quoted market prices as substantially all of these instruments have active markets. Cash equivalents are valued at the fund’s unit net asset value as reported by the trustee.

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

The fair values of the U.S. Pension Plan and VEBA trust assets at September 30, 2013 and 2012 , by asset class are as follows:

																
 	U.S. Pension Plan	
 	Quoted Prices
in Active
Markets for
Identical Assets
and Liabilities
(Level 1)	 	Significant
Other
Observable
Inputs
(Level 2)	 	Unobservable
Inputs
(Level 3)	 	Total	
September 30, 2013:	 	 	 	 	 	 	 	
Domestic equity investments:	 	 	 	 	 	 	 	
   S&P 500 Index equity mutual funds	$	141.8		 	$	—		 	$	—		 	$	141.8		
   Small and midcap equity mutual funds	54.5		 	—		 	—		 	54.5		
    UGI Corporation Common Stock	32.6		 	—		 	—		 	32.6		
       Total domestic equity investments	228.9		 	—		 	—		 	228.9		
International index equity mutual funds	44.4		 	—		 	—		 	44.4		
Fixed income investments:	 	 	 	 	 	 	 	
   Bond index mutual funds	120.9		 	—		 	—		 	120.9		
   Cash equivalents	—		 	4.0		 	—		 	4.0		
     Total fixed income investments	120.9		 	4.0		 	—		 	124.9		
Total	$	394.2		 	$	4.0		 	$	—		 	$	398.2		
 	 	 	 	 	 	 	 	
September 30, 2012:	 	 	 	 	 	 	 	
Domestic equity investments:	 	 	 	 	 	 	 	
   S&P 500 Index equity mutual funds	$	118.9		 	$	—		 	$	—		 	$	118.9		
   Small and midcap equity mutual funds	42.9		 	—		 	—		 	42.9		
    UGI Corporation Common Stock	26.4		 	—		 	—		 	26.4		
       Total domestic equity investments	188.2		 	—		 	—		 	188.2		
International index equity mutual funds	36.9		 	—		 	—		 	36.9		
Fixed income investments:	 	 	 	 	 	 	 	
   Bond index mutual funds	123.3		 	—		 	—		 	123.3		
   Cash equivalents	—		 	3.1		 	—		 	3.1		
     Total fixed income investments	123.3		 	3.1		 	—		 	126.4		
Total	$	348.4		 	$	3.1		 	$	—		 	$	351.5		

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

	
																
 	VEBA	
 	Quoted Prices
in Active
Markets for
Identical Assets
and Liabilities
(Level 1)	 	Significant
Other
Observable
Inputs
(Level 2)	 	Unobservable
Inputs
(Level 3)	 	Total	
September 30, 2013:	 	 	 	 	 	 	 	
S&P 500 Index equity mutual fund	$	7.7		 	$	—		 	$	—		 	$	7.7		
Bond index mutual fund	3.8		 	—		 	—		 	3.8		
Cash equivalents	—		 	0.2		 	—		 	0.2		
Total	$	11.5		 	$	0.2		 	$	—		 	$	11.7		
 	 	 	 	 	 	 	 	
September 30, 2012:	 	 	 	 	 	 	 	
S&P 500 Index equity mutual fund	$	7.7		 	$	—		 	$	—		 	$	7.7		
Bond index mutual fund	3.4		 	—		 	—		 	3.4		
Cash equivalents	—		 	0.1		 	—		 	0.1		
Total	$	11.1		 	$	0.1		 	$	—		 	$	11.2		

The expected long-term rates of return on U.S. Pension Plan and VEBA trust assets have been developed using a best estimate of expected returns, volatilities and correlations for each asset class. The estimates are based on historical capital market performance data and future expectations provided by independent consultants. Future expectations are determined by using simulations that provide a wide range of scenarios of future market performance. The market conditions in these simulations consider the long-term relationships between equities and fixed income as well as current market conditions at the start of the simulation. The expected rate begins with a risk-free rate of return with other factors being added such as inflation, duration, credit spreads and equity risk premiums. The rates of return derived from this process are applied to our target asset allocation to develop a reasonable return assumption.
Defined Contribution Plans. We sponsor 401(k) savings plans for eligible employees of UGI and certain of UGI’s domestic subsidiaries. Generally, participants in these plans may contribute a portion of their compensation on either a before-tax basis, or on both a before-tax and after-tax basis. These plans also provide for employer matching contributions at various rates. The cost of benefits under the savings plans totaled $14.0 in Fiscal 2013 , $13.7 in Fiscal 2012 and $10.4 in Fiscal 2011 . The Company also sponsors certain nonqualified supplemental defined contribution executive retirement plans. These plans generally provide supplemental benefits to certain executives that would otherwise be provided under retirement plans but are prohibited due to limitations imposed by the Internal Revenue Code. Costs associated with these plans were not material in Fiscal 2013, Fiscal 2012 or Fiscal 2011.

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Note 9 — Utility Regulatory Assets and Liabilities and Regulatory Matters
The following regulatory assets and liabilities associated with Utilities are included in our accompanying balance sheets at September 30:

								
 	2013	 	2012	
Regulatory assets:	 	 	 	
Income taxes recoverable	$	106.1		 	$	103.2		
Underfunded pension and postretirement plans	94.5		 	188.2		
Environmental costs	17.1		 	16.8		
Deferred fuel and power costs	8.3		 	11.6		
Removal costs, net	13.3		 	12.7		
Other	5.6		 	5.9		
Total regulatory assets	$	244.9		 	$	338.4		
 	 	 	 	
Regulatory liabilities:	 	 	 	
Postretirement benefits	$	16.5		 	$	13.1		
Environmental overcollections	2.6		 	2.9		
Deferred fuel and power refunds	8.3		 	4.4		
State tax benefits — distribution system repairs	8.4		 	7.4		
Other	1.5		 	0.5		
Total regulatory liabilities	$	37.3		 	$	28.3		

Income taxes recoverable . This regulatory asset is the result of recording deferred tax liabilities pertaining to temporary tax differences principally as a result of the pass through to ratepayers of accelerated tax depreciation for state income tax purposes, and the flow through of accelerated tax depreciation for federal income tax purposes for certain years prior to 1981. These deferred taxes have been reduced by deferred tax assets pertaining to utility deferred investment tax credits. Utilities has recorded regulatory income tax assets related to these deferred tax liabilities representing future revenues recoverable through the ratemaking process over the average remaining depreciable lives of the associated property ranging from 1 to approximately 50 years.
Underfunded pension and other postretirement plans . This regulatory asset represents the portion of prior service cost and net actuarial losses associated with pension and other postretirement benefits which are probable of being recovered through future rates based upon established regulatory practices. These regulatory assets are adjusted annually or more frequently under certain circumstances when the funded status of the plans is recorded in accordance with GAAP. These costs are amortized over the average remaining future service lives of plan participants.
Environmental costs . Environmental costs represent amounts actually spent by UGI Gas to clean up sites in Pennsylvania as well as the portion of estimated probable future environmental remediation and investigation costs principally at manufactured gas plant (“MGP”) sites that CPG and PNG expect to incur in conjunction with remediation consent orders and agreements with the Pennsylvania Department of Environmental Protection (see Note 16 ). UGI Gas is currently permitted to include in rates, through future base rate proceedings, a five-year average of prudently incurred remediation costs at Pennsylvania sites. PNG and CPG are currently recovering and expect to continue to recover environmental remediation and investigation costs in base rate revenues. At September 30, 2013 , the period over which PNG and CPG expect to recover these costs will depend upon future remediation activity.
Deferred fuel and power — costs and refunds. Gas Utility’s and Electric Utility’s tariffs contain clauses which permit recovery of all prudently incurred purchased gas and power costs through the application of purchased gas cost (“PGC”) rates in the case of Gas Utility and delivery service (“DS”) tariffs in the case of Electric Utility. The clauses provide for periodic adjustments to PGC and DS rates for differences between the total amount of purchased gas and electric generation supply costs collected from customers and recoverable costs incurred. Net undercollected costs are classified as a regulatory asset and net overcollections are classified as a regulatory liability.
Gas Utility uses derivative financial instruments to reduce volatility in the cost of gas it purchases for firm- residential, commercial and industrial (“retail core-market”) customers. Realized and unrealized gains or losses on natural gas derivative

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

financial instruments are included in deferred fuel costs or refunds. Net unrealized (losses) gains on such contracts at September 30, 2013 and 2012 were $(1.7) and $5.3 , respectively.
Electric Utility enters into forward electricity purchase contracts to meet a substantial portion of its electricity supply needs. Because these contracts currently do not qualify for the normal purchases and normal sales exception under GAAP related to derivative financial instruments, these electricity supply contracts are recognized on the balance sheet at fair value with an associated adjustment to regulatory assets or liabilities in accordance with GAAP related to rate-regulated entities. At September 30, 2013 and 2012 , the fair values of Electric Utility’s electricity supply contracts were losses of $4.8 and $9.2 , respectively, which amounts are reflected in current derivative financial instruments and other noncurrent liabilities on the Consolidated Balance Sheets with equal and offsetting amounts reflected in deferred fuel and power costs in the table above.
In order to reduce volatility associated with a substantial portion of its electric transmission congestion costs, Electric Utility obtains financial transmission rights (“FTRs”). FTRs are derivative financial instruments that entitle the holder to receive compensation for electricity transmission congestion charges when there is insufficient electricity transmission capacity on the electric transmission grid. Because Electric Utility is entitled to fully recover its DS costs, realized and unrealized gains or losses on FTRs are included in deferred fuel and power costs or deferred fuel and power refunds. At September 30, 2013 and 2012 , such gains or losses were not material.
Removal costs, net . This regulatory asset represents costs incurred, net of salvage, associated with the retirement of depreciable utility plant. At September 30, 2013 , UGI Utilities expects to recover these costs over periods of 1 to 5 years .
Postretirement benefits . Gas Utility and Electric Utility are recovering ongoing postretirement benefit costs at amounts permitted by the PUC in prior base rate proceedings. With respect to UGI Gas and Electric Utility, the difference between the amounts recovered through rates and the actual costs incurred in accordance with accounting for postretirement benefits are being deferred for future refund to or recovery from ratepayers. Such amounts are reflected in regulatory liabilities in the table above. In addition, this regulatory liability includes the portion of prior service credits and net actuarial gains associated with certain other postretirement benefit plans.
Environmental overcollections. This regulatory liability represents the difference between amounts recovered in rates and actual costs incurred (net of insurance proceeds) associated with the terms of a consent order agreement between CPG and the Pennsylvania Department of Environmental Protection to remediate certain gas plant sites.
State income tax benefits — distribution system repairs. This regulatory liability represents Pennsylvania state income tax benefits, net of federal income tax expense, resulting from the deduction for income tax purposes of repair and maintenance costs associated with Gas Utility or Electric Utility assets which are capitalized for regulatory and GAAP reporting. The tax benefits associated with these repair and maintenance deductions will be reflected as a reduction to income tax expense over the remaining tax lives of the related book assets.
Other . Other regulatory assets comprise a number of items including, among others, deferred postretirement costs, deferred asset retirement costs, deferred rate case expenses, customer choice implementation costs and deferred software development costs. At September 30, 2013 , UGI Utilities expects to recover these costs over periods of approximately 1 to 5 years .
UGI Utilities’ regulatory liabilities relating to postretirement benefits, environmental overcollections and state tax benefits — distribution system repairs are included in other noncurrent liabilities on the Consolidated Balance Sheets. UGI Utilities does not recover a rate of return on its regulatory assets.
Other Regulatory Matters

Allentown, Pennsylvania Natural Gas Incident.  On February 19, 2013, the PUC entered a final order (the “Final Order”) settling all regulatory compliance issues pertaining to a natural gas explosion on February 9, 2011, in Allentown, PA. The Final Order requires UGI Utilities to (i) pay a civil penalty in the amount of $0.5 ; (ii) conduct a pilot new technology leak detection program in Allentown; and (iii) accept new reporting requirements governing its agreed upon 14 -year cast iron and 30 -year bare steel pipeline replacement program and distribution integrity management program. The Final Order makes no findings that UGI Utilities has violated any regulation or operating procedure. The Company does not believe that the cost of complying with the requirements of the Final Order will have a material impact on UGI Utilities' consolidated financial position, results of operations or cash flows.

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

CPG Base Rate Filing. On August 11, 2011, the PUC approved a settlement agreement with CPG that resulted in an increase in annual base rate revenues of $8.0 as well as $0.9 in revenues per year to fund system improvements and operations necessary to maintain safe and reliable natural gas service and fund new programs that would provide rebates and other incentives for customers to install new high-efficiency equipment (collectively, “Energy and Efficiency Conservation Program”). The increase became effective August 30, 2011. During Fiscal 2012, the PUC reversed its earlier decision related to the $0.9 increase in revenues associated with the Energy and Efficiency Conservation Program and required CPG to refund revenue it had collected for that program.
Transfers of Assets . On February 1, 2012, CPG filed an application with the PUC for review and approval of the transfer of an 11-mile natural gas pipeline, related facilities and right of way located in Delmar Township, Pennsylvania (“TL-96 line”) to Energy Services.   The PUC approved the transfer and, in April 2013, the TL-96 line was dividended to UGI and subsequently contributed to Energy Services.  The net book value of the TL-96 line is approximately $2.6 .
On October 21, 2010, the Federal Energy Regulatory Commission (“FERC”) approved and later affirmed CPG’s application to abandon a storage service and approved the transfer of its Tioga, Meeker and Wharton natural gas storage facilities, along with related assets, to UGI Storage Company, a subsidiary of Energy Services. The PUC approved the transfer subject to, among other things, a reduction in base rates and CPG’s agreement to charge PGC customers, for a period of three years, no more for storage services from the transferred assets than they would have paid before the transfer, to the extent used. On April 1, 2011, the storage facilities were dividended to UGI and subsequently contributed to UGI Storage Company. The net book value of the storage facility assets was $10.9 . Compliance with the provisions of the PUC Order approving the transfer of the storage assets did not have a material impact on the results of operations of Gas Utility. Concurrent with the April 1, 2011 transfer, CPG entered into a one -year firm storage service agreement with UGI Storage Company.
On December 1, 2010, PNG filed an application with the PUC for expedited review and approval of the transfer of a 9 -mile natural gas pipeline, related facilities, and right of way located in Mehoopany, Pennsylvania (the “Auburn Line”) to Energy Services. The PUC approved the transfer and in September 2011 the Auburn Line was dividended to UGI and subsequently contributed to Energy Services. The net book value of the Auburn Line was $1.1 .

Note 10 — Inventories
Inventories comprise the following at September 30:

	
								
 	2013	 	2012	
Non-utility LPG and natural gas	$	230.0		 	$	237.9		
Gas Utility natural gas	78.9		 	57.7		
Materials, supplies and other	56.6		 	58.5		
Total inventories	$	365.5		 	$	354.1		

At September 30, 2013 , UGI Utilities is a party to three principal storage contract administrative agreements (“SCAAs”), one of which expired in October 2013 and two of which expire in October 2015. Pursuant to SCAAs, UGI Utilities has, among other things, released certain storage and transportation contracts for the terms of the SCAAs. UGI Utilities also transferred certain associated storage inventories upon commencement of the SCAAs, will receive a transfer of storage inventories at the end of the SCAAs, and makes payments associated with refilling storage inventories during the terms of the SCAAs. The historical cost of natural gas storage inventories released under the SCAAs, which represents a portion of Gas Utility’s total natural gas storage inventories, and any exchange receivable (representing amounts of natural gas inventories used by the other parties to the agreement but not yet replenished), are included in the caption “Gas Utility natural gas” in the table above.

As of September 30, 2013, UGI Utilities’ principal SCAAs are with Energy Services. The carrying values of gas storage inventories released under the SCAAs to non-affiliates at September 30, 2013 and 2012 , comprising 0.6  billion cubic feet (“bcf”) and 3.8 bcf of natural gas was $2.4 and $11.4 , respectively. Effective November 1, 2013, UGI Utilities entered into a new SCAA with Energy Services having a term of one year and another with a third party having a term of three years.

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Note 11 — Property, Plant and Equipment
Property, plant and equipment comprise the following at September 30:

								
 	2013	 	2012	
Utilities:	 	 	 	
Distribution	$	2,162.6		 	$	2,047.8		
Transmission	86.6		 	85.4		
General and other, including work in process	178.6		 	162.5		
Total Utilities	2,427.8		 	2,295.7		
 	 	 	 	
Non-utility:	 	 	 	
Land	178.4		 	175.0		
Buildings and improvements	308.1		 	282.0		
Transportation equipment	273.8		 	246.5		
Equipment, primarily cylinders and tanks	3,184.4		 	3,043.4		
Electric generation	264.8		 	254.3		
Other, including work in process	403.2		 	222.7		
Total non-utility	4,612.7		 	4,223.9		
Total property, plant and equipment	$	7,040.5		 	$	6,519.6		

Note 12 — Goodwill and Intangible Assets
Goodwill and intangible assets comprise the following at September 30:

	
								
 	2013	 	2012	
Goodwill (not subject to amortization)	$	2,873.7		 	$	2,818.3		
Intangible assets:	 	 	 	
Customer relationships, noncompete agreements and other	$	704.8		 	$	691.9		
Trademarks and tradenames (not subject to amortization)	130.2		 	137.2		
Gross carrying amount	835.0		 	829.1		
Accumulated amortization	(227.1	)	 	(170.9	)	
Intangible assets, net	$	607.9		 	$	658.2		

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Changes in the carrying amount of goodwill are as follows:

																												
 	 	 	 	 	 	 	UGI International	 	 	 	 	
 	AmeriGas
Propane	 	Gas
Utility	 	Energy Services	 	Antargaz	 	Flaga & Other	 	Corporate &
Other	 	Total	
Balance September 30, 2011	$	696.3		 	$	182.1		 	$	2.8		 	$	591.8		 	$	82.2		 	$	7.0		 	$	1,562.2		
Acquisitions	1,223.1		 	—		 	—		 	46.4		 	13.7		 	—		 	1,283.2		
Purchase accounting adjustments	(0.2	)	 	—		 	—		 	—		 	—		 	—		 	(0.2	)	
Foreign currency translation	—		 	—		 	—		 	(26.2	)	 	(0.7	)	 	—		 	(26.9	)	
Balance September 30, 2012	1,919.2		 	182.1		 	2.8		 	612.0		 	95.2		 	7.0		 	2,818.3		
Acquisitions	12.5		 	—		 	—		 	—		 	—		 	—		 	12.5		
Correcting adjustment	9.3		 	—		 	—		 	—		 	—		 	—		 	9.3		
Foreign currency translation	—		 	—		 	—		 	31.7		 	1.9		 	—		 	33.6		
Balance September 30, 2013	$	1,941.0		 	$	182.1		 	$	2.8		 	$	643.7		 	$	97.1		 	$	7.0		 	$	2,873.7		

The decrease in trademarks and tradenames and the correcting adjustment to goodwill during the year ended September 30, 2013 primarily reflects a correcting adjustment associated with the Heritage Acquisition. We amortize customer relationships and noncompete agreement intangibles over their estimated periods of benefit which do not exceed 15  years. Amortization expense of intangible assets was $52.8 in Fiscal 2013 , $44.5 in Fiscal 2012 and $20.4 in Fiscal 2011 . Estimated amortization expense of intangible assets during the next five fiscal years is as follows: Fiscal 2014 — $51.2 ; Fiscal 2015 — $48.4 ; Fiscal 2016 — $42.4 ; Fiscal 2017 — $35.9 ; Fiscal 2018 — $34.5 . There were no accumulated impairment losses at September 30, 2013 .

Note 13 — Series Preferred Stock
UGI has 10,000,000 shares of UGI Series Preferred Stock authorized for issuance, including both series subject to and series not subject to mandatory redemption. We had no shares of UGI Series Preferred Stock outstanding at September 30, 2013 or 2012 .
UGI Utilities has 2,000,000 shares of UGI Utilities Series Preferred Stock authorized for issuance, including both series subject to and series not subject to mandatory redemption. At September 30, 2013 and 2012 , there were no shares of UGI Utilities Series Preferred Stock outstanding.

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Note 14 — Common Stock and Equity-Based Compensation
UGI Common Stock share activity for Fiscal 2011 , Fiscal 2012 and Fiscal 2013 follows:

									
 	Issued	 	Treasury	 	Outstanding	
Balance, September 30, 2010	115,400,294		 	(5,026,707	)	 	110,373,587		
Issued:	 	 	 	 	 	
Employee and director plans	106,800		 	1,263,065		 	1,369,865		
Dividend reinvestment plan	—		 	92,570		 	92,570		
Balance, September 30, 2011	115,507,094		 	(3,671,072	)	 	111,836,022		
Issued:	 	 	 	 	 	
Employee and director plans	117,500		 	824,925		 	942,425		
Dividend reinvestment plan	—		 	104,994		 	104,994		
Shares reacquired - employee and director plans	—		 	(263,020	)	 	(263,020	)	
Balance, September 30, 2012	115,624,594		 	(3,004,173	)	 	112,620,421		
Issued:	 	 	 	 	 	
Employee and director plans	159,200		 	2,622,338		 	2,781,538		
Dividend reinvestment plan	—		 	62,169		 	62,169		
Shares reacquired - employee and director plans	—		 	(1,035,270	)	 	(1,035,270	)	
Balance, September 30, 2013	115,783,794		 	(1,354,936	)	 	114,428,858		
As a result of the January 2012 issuance of 29,567,362 AmeriGas Partners Common Units to ETP in conjunction with the Heritage Acquisition and related General Partner Common Unit transactions (see Note 5 ), and the March 2012 issuance of 7,000,000 AmeriGas Partners Common Units pursuant to AmeriGas Partners’ public offering (see Note 15 ), the Company recorded a $196.3 increase in UGI Corporation stockholders’ equity (which amount is net of deferred income taxes) and an associated $321.4 pre-tax decrease in noncontrolling interests equity.

Equity-Based Compensation
The Company grants equity-based awards to employees and non-employee directors comprising UGI stock options, grants of UGI stock-based equity instruments and grants of AmeriGas Partners Common Unit-based equity instruments as further described below. We recognized total pre-tax equity-based compensation expense of $17.6 ( $11.4 after-tax), $14.5 ( $8.7 after-tax) and $15.6 ( $10.3 after-tax) in Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , respectively.
UGI Equity-Based Compensation Plans and Awards. On January 24, 2013, the Company’s shareholders approved the UGI Corporation 2013 Omnibus Incentive Compensation Plan (the “2013 OICP”). The 2013 OICP succeeds the UGI Corporation 2004 Omnibus Equity Compensation Plan Amended and Restated as of December 5, 2006 (the “2004 OECP”) for awards granted on or after January 24, 2013. The 2004 OECP will continue in effect but all future grants issued pursuant to it will be solely in the form of options to acquire Common Stock. Under the 2013 OICP, we may grant options to acquire shares of UGI Common Stock, stock appreciation rights (“SARs”), UGI Units (comprising “Stock Units” and “UGI Performance Units”), other equity-based awards and cash to key employees and non-employee directors. The exercise price for options may not be less than the fair market value on the grant date. Awards granted under the 2013 OICP may vest immediately or ratably over a period of years, and stock options can be exercised no later than ten years from the grant date . In addition, the 2013 OICP provides that awards of UGI Units may also provide for the crediting of dividend equivalents to participants’ accounts. Except in the event of retirement, death or disability, each grant, unless paid, will terminate when the participant ceases to be employed. There are certain change of control and retirement eligibility conditions that, if met, generally result in accelerated vesting or elimination of further service requirements.
Under the 2004 OECP, we could grant options to acquire shares of UGI Common Stock, UGI Units and other equity-based awards to key employees and non-employee directors through January 23, 2013 (except with respect to the granting of stock option awards as previously mentioned). Under the 2004 OECP, the exercise price for stock options could not be less than the fair market value on the grant date. Awards granted under the 2004 OECP could vest immediately or ratably over a period of years, and stock options could be exercised no later than ten years from the date of grant. In addition, the 2004 OECP provided that the awards of UGI Units could include the crediting of dividend equivalents.

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Under the 2013 OICP, awards representing up to 14,500,000 shares of UGI Common Stock may be granted. Dividend equivalents on UGI Unit awards to employees will be paid in cash. Dividend equivalents on non-employee director awards are accumulated in additional Stock Units. UGI Unit awards granted to employees and non-employee directors are settled in shares of Common Stock and cash. UGI Unit awards granted to Antargaz employees are settled in shares of Common Stock. With respect to UGI Performance Unit awards, the actual number of shares (or their cash equivalent) ultimately issued, and the actual amount of dividend equivalents paid, is generally dependent upon the achievement of market performance goals and service conditions. It is currently our practice to issue treasury shares to satisfy substantially all option exercises and UGI Unit awards. We may choose to repurchase shares on the market for such purposes during Fiscal 2014 . Beginning during Fiscal 2012, options granted under the 2004 OECP, and option awards granted under the 2013 OICP, may be net exercised whereby shares equal to the option price and grantee’s minimum applicable payroll tax withholding are withheld from the number of shares payable (“net exercise”). We record shares withheld under option net exercises as shares reacquired.
UGI Stock Option Awards . Stock option transactions under the 2013 OICP, the 2004 OECP and predecessor plans during Fiscal 2011 , Fiscal 2012 and Fiscal 2013 follow:

													
 	Shares	 	Weighted
Average
Option Price	 	Total
Intrinsic
Value	 	Weighted
Average
Contract Term
(Years)	
Shares under option — September 30, 2010	7,557,045		 	$	23.81		 	$	36.2		 	6.5	
Granted	1,443,558		 	$	31.55		 	 	 	 	
Cancelled	(235,437	)	 	$	27.79		 	 	 	 	
Exercised	(1,091,987	)	 	$	20.95		 	$	11.4		 	 	
Shares under option — September 30, 2011	7,673,179		 	$	25.55		 	$	15.1		 	6.2	
Granted	1,508,050		 	$	29.26		 	 	 	 	
Cancelled	(321,600	)	 	$	27.74		 	 	 	 	
Exercised	(801,857	)	 	$	20.93		 	$	7.2		 	 	
Shares under option — September 30, 2012	8,057,772		 	$	26.62		 	$	41.4		 	6.1	
Granted	1,516,900		 	$	33.57		 	 	 	 	
Cancelled	(89,836	)	 	$	30.51		 	 	 	 	
Exercised	(2,688,868	)	 	$	24.58		 	$	35.4		 	 	
Shares under option — September 30, 2013	6,795,968		 	$	28.92		 	$	69.6		 	6.8	
Options exercisable — September 30, 2011	4,879,784		 	$	24.15		 	 	 	 	
Options exercisable — September 30, 2012	5,317,698		 	$	25.32		 	 	 	 	
Options exercisable — September 30, 2013	3,914,061		 	$	26.93		 	$	47.8		 	5.6	
Options not exercisable — September 30, 2013	2,881,907		 	$	31.63		 	$	21.8		 	8.5	

Cash received from stock option exercises and associated tax benefits were $30.8 and $12.1 , $9.4 and $2.3 , and $22.9 and $3.8 in Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , respectively. As of September 30, 2013 , there was $5.4 of unrecognized compensation cost associated with unvested stock options that is expected to be recognized over a weighted-average period of 1.9  years.
The following table presents additional information relating to stock options outstanding and exercisable at September 30, 2013 :

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

	
																
 	Range of exercise prices	
 	Under
$25.00	 	$25.01 -
$30.00	 	$30.01 -
$35.00	 	Over
$35.00	
Options outstanding at September 30, 2013:	 	 	 	 	 	 	 	
Number of options	1,778,435		 	2,265,255		 	2,559,678		 	192,600		
Weighted average remaining contractual life (in years)	5.2		 	6.5		 	8.1		 	9.6		
Weighted average exercise price	$	23.92		 	$	28.34		 	$	32.12		 	$	39.45		
Options exercisable at September 30, 2013:	 	 	 	 	 	 	 	
Number of options	1,718,735		 	1,358,454		 	836,872		 	—		
Weighted average exercise price	$	23.91		 	$	27.80		 	$	31.70		 	$	—		

UGI Stock Option Fair Value Information. The per share weighted-average fair value of stock options granted under our option plans was $4.93 in Fiscal 2013 , $4.31 in Fiscal 2012 and $5.40 in Fiscal 2011 . These amounts were determined using a Black-Scholes option pricing model which values options based on the stock price at the grant date, the expected life of the option, the estimated volatility of the stock, expected dividend payments and the risk-free interest rate over the expected life of the option. The expected life of option awards represents the period of time during which option grants are expected to be outstanding and is derived from historical exercise patterns. Expected volatility is based on historical volatility of the price of UGI’s Common Stock. Expected dividend yield is based on historical UGI dividend rates. The risk free interest rate is based on U.S. Treasury bonds with terms comparable to the options in effect on the date of grant.
The assumptions we used for valuing option grants during Fiscal 2013 , Fiscal 2012 and Fiscal 2011 are as follows:

	
						
 	2013	 	2012	 	2011	
Expected life of option	5.75 years	 	5.75 years	 	5.75 years	
Weighted average volatility	24.9%	 	24.7%	 	24.3%	
Weighted average dividend yield	3.6%	 	3.5%	 	3.4%	
Expected volatility	24.4% - 24.9%	 	24.7%	 	23.8% - 24.3%	
Expected dividend yield	3.2% - 3.7%	 	3.3% - 3.7%	 	3.1% - 3.4%	
Risk free rate	0.8% - 1.7%	 	0.8% - 1.1%	 	1.2% - 2.4%	

UGI Unit Awards . UGI Stock Unit and UGI Performance Unit awards entitle the grantee to shares of UGI Common Stock or cash once the service condition is met and, with respect to UGI Performance Unit awards, subject to market performance conditions. UGI Performance Unit grant recipients are awarded a target number of Performance Units. The number of UGI Performance Units ultimately paid at the end of the performance period (generally three years) may be higher or lower than the target amount, or even zero, based on UGI’s Total Shareholder Return (“TSR”) percentile rank relative to (i) companies in the Standard & Poor’s Utilities Index for grants prior to January 1, 2011 and (ii) the Russell Midcap Utility Index, excluding telecommunication companies, for grants on or after January 1, 2011 (each a respective “UGI comparator group”). For grants issued on or after January 1, 2013, grantees may receive 0% to 200% of the target award granted. For such grants, if UGI’s TSR ranks below the 25th percentile compared to the UGI comparator group, the employee will not be paid. At the 40th percentile, the employee will be paid an award equal to 70% of the target award; at the 50th percentile, 100%; and at the 90th percentile, 200% . For grants issued prior to January 1, 2013, grantees may receive 0% to 200% of the target award granted. For such grants, if UGI’s TSR ranks below the 40th percentile compared to the UGI comparator group, the employee will not be paid. At the 40th percentile, the employee will be paid an award equal to 50% of the target award; at the 50th percentile, 100%; and at the 100th percentile, 200% . The actual amount of the award is interpolated between these percentile rankings. Dividend equivalents are paid in cash only on UGI Performance Units that eventually vest.
The fair value of UGI Stock Units on the grant date is equal to the market price of UGI Stock on the grant date. Under GAAP, UGI Performance Units are equity awards with a market-based condition which, if settled in shares, results in the recognition of compensation cost over the requisite employee service period regardless of whether the market-based condition is satisfied. The fair values of UGI Performance Units are estimated using a Monte Carlo valuation model. The fair value associated with the target award is accounted for as equity and the fair value of the award over the target, as well as all dividend equivalents, is

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

accounted for as a liability. The expected term of the UGI Performance Unit awards is three years based on the performance period. Expected volatility is based on the historical volatility of UGI Common Stock over a three-year period. The risk-free interest rate is based on the yields on U.S. Treasury bonds at the time of grant. Volatility for all companies in the UGI comparator group is based on historical volatility.
The following table summarizes the weighted average assumptions used to determine the fair value of UGI Performance Unit awards and related compensation costs:

	
									
 	Grants Awarded in Fiscal	
 	2013	 	2012	 	2011	
Risk free rate	0.4	%	 	0.4	%	 	1.0	%	
Expected life	3 years		 	3 years		 	3 years		
Expected volatility	21.1	%	 	22.2	%	 	27.6	%	
Dividend yield	3.3	%	 	3.5	%	 	3.2	%	

The weighted-average grant date fair value of UGI Performance Unit awards was estimated to be $37.97 for Units granted in Fiscal 2013 , $27.25 for Units granted in Fiscal 2012 and $35.19 for Units granted in Fiscal 2011 .
The following table summarizes UGI Unit award activity for Fiscal 2013 :

																					
 	Total	 	Vested	 	Non-Vested	
 	Number of
UGI
Units	 	Weighted
Average
Grant Date
Fair Value
(per Unit)	 	Number of
UGI
Units	 	Weighted
Average
Grant Date
Fair Value
(per Unit)	 	Number of
UGI
Units	 	Weighted
Average
Grant Date
Fair Value
(per Unit)	
September 30, 2012	885,338		 	$	24.09		 	580,122		 	$	21.72		 	305,216		 	$	28.59		
UGI Performance Units:	 	 	 	 	 	 	 	 	 	 	 	
Granted	220,575		 	$	37.97		 	26,818		 	$	38.13		 	193,757		 	$	37.94		
Forfeited	(9,319	)	 	$	33.78		 	—		 	$	—		 	(9,319	)	 	$	33.78		
Vested	—		 	$	—		 	117,703		 	$	26.69		 	(117,703	)	 	$	26.69		
Unit awards paid	(103,759	)	 	$	22.22		 	(103,759	)	 	$	22.22		 	—		 	$	—		
Performance criteria not met	(70,079	)	 	$	22.22		 	(70,079	)	 	$	22.22		 	—		 	$	—		
UGI Stock Units:	 	 	 	 	 	 	 	 	 	 	 	
Granted (a)	34,025		 	$	33.05		 	34,025		 	$	33.05		 	—		 	$	—		
Unit awards paid	(36,180	)	 	$	36.37		 	(36,180	)	 	$	36.37		 	—		 	$	—		
September 30, 2013	920,601		 	$	27.52		 	548,650		 	$	23.18		 	371,951		 	$	33.93		
		
(a)	Generally, shares granted under UGI Stock Unit awards are paid approximately 70% in shares . UGI Stock Unit awards granted in Fiscal 2012 and Fiscal 2011 were 42,445 and 61,945 , respectively.	
During Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , the Company paid UGI Performance Unit and UGI Stock Unit awards in shares and cash as follows:

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

	
												
 	2013	 	2012	 	2011	
UGI Performance Unit awards:	 	 	 	 	 	
Number of original awards granted	218,683		 	210,750		 	197,917		
Fiscal year granted	2010		 	2009		 	2008		
Payment of awards:	 	 	 	 	 	
Shares of UGI Common Stock issued	65,081		 	—		 	142,494		
Cash paid	$	1.6		 	$	—		 	$	7.5		
 	 	 	 	 	 	
UGI Stock Unit awards:	 	 	 	 	 	
Number of original awards granted	36,179		 	32,898		 	22,400		
Payment of awards:	 	 	 	 	 	
Shares of UGI Common Stock issued	23,516		 	21,757		 	17,545		
Cash paid	$	0.5		 	$	0.2		 	$	0.2		

During Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , we granted UGI Unit awards representing 254,600 , 239,845 and 285,470 shares, respectively, having weighted-average grant date fair values per Unit of $37.31 , $27.68 and $34.78 , respectively.
As of September 30, 2013 , there was a total of approximately $8.3 of unrecognized compensation cost associated with 920,601 UGI Unit awards outstanding that is expected to be recognized over a weighted-average period of 2.0  years. The total fair values of UGI Units that vested during Fiscal 2013 , Fiscal 2012 and Fiscal 2011 were $6.0 , $3.6 and $6.8 , respectively. As of September 30, 2013 and 2012 , total liabilities of $8.0 and $5.0 , respectively, associated with UGI Unit awards are reflected in employee compensation and benefits accrued and other noncurrent liabilities in the Consolidated Balance Sheets.
At September 30, 2013 , 13,449,649 shares of Common Stock were available for future grants under the 2013 OICP, and up to 187,543 shares of Common Stock were available for future grants of stock options under the 2004 OECP.
AmeriGas Partners Equity-Based Compensation Plans and Awards. Under the AmeriGas Propane, Inc. 2010 Long-Term Incentive Plan on Behalf of AmeriGas Partners, L.P. (“2010 Propane Plan”), the General Partner may award to employees and non-employee directors grants of AmeriGas Partners Units (comprising “AmeriGas Stock Units” and “AmeriGas Performance Units”), options, unit appreciation rights and other Common Unit-based awards. The 2010 Propane Plan succeeded the AmeriGas Propane, Inc. 2000 Long-Term Incentive Plan (“2000 Propane Plan”) which expired on December 31, 2009, and replaced the AmeriGas Propane, Inc. Discretionary Long-Term Incentive Plan for Non-Executive Key Employees (“Nonexecutive Propane Plan”). The total aggregate number of Common Units that may be issued under the 2010 Propane Plan is 2,800,000 . The exercise price for options may not be less than the fair market value on the date of grant. Awards granted under the 2010 Propane Plan may vest immediately or ratably over a period of years, and options can be exercised no later than ten years from the grant date . In addition, the 2010 Propane Plan provides that Common Unit-based awards may also provide for the crediting of Common Unit distribution equivalents to participants’ accounts.
Recipients of AmeriGas Performance Unit awards are awarded a target number of AmeriGas Performance Units. The number of AmeriGas Performance Units ultimately paid at the end of the performance period (generally three years ) may be higher or lower than the target number based upon AmeriGas Partners’ Total Unitholder Return (“TUR”) percentile rank relative to entities in a peer group. Percentile rankings and payout percentages are generally the same as those used for the UGI Performance Unit awards. Any Common Unit distribution equivalents earned are paid in cash. Generally, except in the event of retirement, death or disability, each grant, unless paid, will terminate when the participant ceases to be employed by the General Partner. There are certain change of control and retirement eligibility conditions that, if met, generally result in accelerated vesting or elimination of further service requirements.
As a result of the Heritage Acquisition, certain Heritage Propane employees were awarded AmeriGas Performance Units, AmeriGas Stock Units (in the form of phantom units), or a combination of AmeriGas Performance Units and AmeriGas Stock Units. The terms of the Performance Unit awards granted to Heritage Propane employees are generally the same as those described above. The AmeriGas Stock Units awards granted to Heritage employees vest in tranches with certain awards beginning to vest in January 2013 through January 2016. Certain of the AmeriGas Stock Unit awards provide for accelerated vesting under certain conditions. Under certain conditions all or a portion of these awards could be forfeited. The AmeriGas Stock Unit awards granted to Heritage Propane employees provide for the crediting of distribution equivalents to participants’ accounts.

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Under GAAP, AmeriGas Performance Units are equity awards with a market-based condition which, if settled in Common Units, results in the recognition of compensation cost over the requisite employee service period regardless of whether the market-based condition is satisfied. The fair values of AmeriGas Performance Units are estimated using a Monte Carlo valuation model. The fair value associated with the target award and the award above the target, if any, which will be paid in Common Units, is accounted for as equity and the fair value of all Common Unit distribution equivalents, which will be paid in cash, is accounted for as a liability. The expected term of the AmeriGas Performance Unit awards is three years based on the performance period. Expected volatility is based on the historical volatility of Common Units over a three-year period. The risk-free interest rate is based on the rates on U.S. Treasury bonds at the time of grant. Volatility for all limited partnerships in the peer group is based on historical volatility.
The following table summarizes the weighted-average assumptions used to determine the fair value of AmeriGas Performance Unit awards and related compensation costs:

	
									
 	Grants Awarded in Fiscal	
 	2013	 	2012	 	2011	
Risk-free rate	0.4	%	 	0.4	%	 	1.0	%	
Expected life	3 years		 	3 years		 	3 years		
Expected volatility	20.7	%	 	23.0	%	 	34.6	%	
Dividend yield	8.2	%	 	6.4	%	 	5.8	%	

The General Partner granted awards under the 2010 Propane Plan representing 65,136 , 248,818 and 49,287 Common Units in Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , respectively, having weighted-average grant date fair values per Common Unit subject to award of $42.58 , $43.22 and $53.19 , respectively. At September 30, 2013 , 2,484,839 Common Units were available for future award grants under the 2010 Propane Plan.
The following table summarizes AmeriGas Common Unit-based award activity for Fiscal 2013 :

																					
 	Total	 	Vested	 	Non-Vested	
 	Number of
AmeriGas
Partners
Common
Units
Subject
to Award	 	Weighted
Average
Grant Date
Fair Value
(per Unit)	 	Number of
AmeriGas
Partners
Common
Units
Subject
to Award	 	Weighted
Average
Grant Date
Fair Value
(per Unit)	 	Number of
AmeriGas
Partners
Common
Units
Subject
to Award	 	Weighted
Average
Grant Date
Fair Value
(per Unit)	
September 30, 2012	263,967		 	$	44.70		 	65,651		 	$	45.42		 	198,316		 	$	44.47		
AmeriGas Performance Units:			 			 			 			 			 			
  Granted	44,800		 	$	42.36		 	1,332		 	$	41.64		 	43,468		 	$	42.38		
  Forfeited	(14,869	)	 	$	47.04		 	—		 	$	—		 	(14,869	)	 	$	47.04		
  Vested	—		 	$	—		 	20,115		 	$	43.68		 	(20,115	)	 	$	43.68		
  Performance criteria not met	(43,350	)	 	$	42.10		 	(43,350	)	 	$	42.10		 	—		 	$	—		
AmeriGas Stock Units:	 	 	 	 	 	 	 	 	 	 	 	
  Granted	20,336		 	$	43.06		 	8,442		 	$	39.07		 	11,894		 	$	45.90		
  Forfeited	(11,333	)	 	$	48.79		 	—		 	$	—		 	(11,333	)	 	$	48.79		
  Vested	—		 	$	—		 	30,909		 	$	48.92		 	(30,909	)	 	$	48.92		
  Awards paid	(35,384	)	 	$	47.04		 	(35,384	)	 	$	47.04		 	—		 	$	—		
September 30, 2013	224,167		 	$	47.88		 	47,715		 	$	47.92		 	176,452		 	$	47.87		

During Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , the Partnership paid AmeriGas Common Unit-based awards in Common Units and cash as follows:

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

	
												
 	2013 (a)	 	2012 (a)	 	2011	
Number of Common Units subject to original awards granted	54,750		 	60,200		 	41,064		
Fiscal year granted	2010		 	2009		 	2008		
Payment of awards:	 	 	 	 	 	
AmeriGas Partners Common Units issued	3,850		 	3,500		 	35,787		
Cash paid	$	0.1		 	$	0.1		 	$	1.2		
(a) In addition, during Fiscal 2013 and 2012, 19,342 AmeriGas Stock Units and $0.5 in cash, and 40,516 AmeriGas Stock Units and $0.9 in cash, respectively, were paid to former Heritage Propane employees associated with awards granted in Fiscal 2012.

As of September 30, 2013 , there was a total of approximately $3.0 of unrecognized compensation cost associated with 224,168 Common Units subject to award that is expected to be recognized over a weighted-average period of 1.8  years. The total fair value of Common Unit-based awards that vested during Fiscal 2013 , Fiscal 2012 and Fiscal 2011 was $2.8 , $5.1 and $2.0 , respectively. As of September 30, 2013 and 2012 , total liabilities of $1.1 and $1.1 associated with Common Unit-based awards are reflected in employee compensation and benefits accrued and other noncurrent liabilities in the Consolidated Balance Sheets.

Note 15 — Partnership Distributions and Common Unit Offerings
The Partnership makes distributions to its partners approximately 45 days after the end of each fiscal quarter in a total amount equal to its Available Cash (as defined in the Partnership Agreement) for such quarter . Available Cash generally means:

1.	all cash on hand at the end of such quarter,	
		
2.	plus all additional cash on hand as of the date of determination resulting from borrowings after the end of such quarter,	
		
3.	less the amount of cash reserves established by the General Partner in its reasonable discretion.	
The General Partner may establish reserves for the proper conduct of the Partnership’s business and for distributions during the next four quarters.
Distributions of Available Cash are made 98% to limited partners and 2% to the General Partner (representing a 1% General Partner interest in AmeriGas Partners and 1.01% interest in AmeriGas OLP) until Available Cash exceeds the Minimum Quarterly Distribution of $0.55 and the First Target Distribution of $0.055 per Common Unit (or a total of $0.605 per Common Unit). When Available Cash exceeds $0.605 per Common Unit in any quarter, the General Partner will receive a greater percentage of the total Partnership distribution (the “incentive distribution”) but only with respect to the amount by which the distribution per Common Unit to limited partners exceeds $0.605 .
During Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , the Partnership made quarterly distributions to Common Unitholders in excess of $0.605 per limited partner unit. As a result, the General Partner has received a greater percentage of the total Partnership distribution than its aggregate 2% general partner interest in AmeriGas OLP and AmeriGas Partners. The total amount of distributions received by the General Partner with respect to its aggregate 2% general partner ownership interests totaled $27.4 in Fiscal 2013 , $19.7 in Fiscal 2012 and $9.0 in Fiscal 2011 . Included in these amounts are incentive distributions received by the General Partner during Fiscal 2013 , Fiscal 2012 and Fiscal 2011 of $19.3 , $13.0 and $5.0 , respectively.
In March 2012, AmeriGas Partners sold 7,000,000 Common Units in an underwritten public offering at a public offering price of $41.25 per unit. The net proceeds of the public offering totaling $276.6 and the associated capital contributions from the General Partner totaling $2.8 were used to redeem $200 of 6.50% Senior Notes pursuant to a tender offer (see Note 6 ), to reduce bank loan borrowings and for general partnership purposes.
Note 16 — Commitments and Contingencies
Commitments
We lease various buildings and other facilities and vehicles, computer and office equipment under operating leases. Certain of our leases contain renewal and purchase options and also contain step-rent provisions. Our aggregate rental expense for such leases was $82.5 in Fiscal 2013 , $77.9 in Fiscal 2012 and $69.8 in Fiscal 2011 .

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Minimum future payments under operating leases with non-affiliates that have initial or remaining noncancelable terms in excess of one year are as follows:

																								
 	2014	 	2015	 	2016	 	2017	 	2018	 	After 2018	
AmeriGas Propane	$	51.0		 	$	41.4		 	$	33.7		 	$	26.6		 	$	21.7		 	$	55.8		
UGI Utilities	5.5		 	4.7		 	4.2		 	2.7		 	2.0		 	1.3		
UGI International	8.2		 	5.8		 	4.5		 	3.3		 	1.8		 	1.0		
Other	2.0		 	1.6		 	1.4		 	0.6		 	0.2		 	0.1		
Total	$	66.7		 	$	53.5		 	$	43.8		 	$	33.2		 	$	25.7		 	$	58.2		

Our businesses enter into contracts of varying lengths and terms to meet their supply, pipeline transportation, storage, capacity and energy needs. Gas Utility has gas supply agreements with producers and marketers with terms not exceeding one year. Gas Utility also has agreements for firm pipeline transportation and natural gas storage services, which Gas Utility may terminate at various dates through Fiscal 2025. Gas Utility’s costs associated with transportation and storage capacity agreements are included in its annual PGC filings with the PUC and are recoverable through PGC rates. In addition, Gas Utility has short-term gas supply agreements which permit it to purchase certain of its gas supply needs on a firm or interruptible basis at spot-market prices. Electric Utility purchases its electricity needs under contracts with various suppliers and on the spot market. Contracts with producers for energy needs expire at various dates through Fiscal 2014. Midstream & Marketing enters into fixed-price contracts with suppliers to purchase natural gas and electricity to meet its sales commitments. Generally, these contracts have terms of less than two years. The Partnership enters into fixed-price and variable-price contracts to purchase a portion of its supply requirements. These contracts currently have terms that do not exceed three years. UGI International enters into fixed-price and variable-priced contracts to purchase a portion of its supply requirements that currently do not exceed three years.
The following table presents contractual obligations with non-affiliates under Gas Utility, Electric Utility, Midstream & Marketing, AmeriGas Propane and UGI International supply, storage and service contracts existing at September 30, 2013 :

																								
 	2014	 	2015	 	2016	 	2017	 	2018	 	After 2018	
UGI Utilities supply, storage and transportation contracts	$	151.6		 	$	80.3		 	$	50.9		 	$	31.2		 	$	28.0		 	$	72.1		
Midstream & Marketing supply contracts	244.4		 	109.1		 	12.3		 	1.2		 	—		 	—		
AmeriGas Propane supply contracts	176.9		 	97.1		 	22.2		 	—		 	—		 	—		
UGI International supply contracts	198.1		 	189.9		 	101.0		 	—		 	—		 	—		
Total	$	771.0		 	$	476.4		 	$	186.4		 	$	32.4		 	$	28.0		 	$	72.1		

The Partnership and UGI International also enter into other contracts to purchase LPG to meet supply requirements. Generally, these contracts are one - to three -year agreements subject to annual price and quantity adjustments.
Contingencies
Environmental Matters
UGI Utilities
CPG is party to a Consent Order and Agreement (“CPG-COA”) with the Pennsylvania Department of Environmental Protection (“DEP”) requiring CPG to perform a specified level of activities associated with environmental investigation and remediation work at certain properties in Pennsylvania on which manufactured gas plant (“MGP”) related facilities were operated (“CPG MGP Properties”) and to plug a minimum number of non-producing natural gas wells per year. In addition, PNG is a party to a Multi-Site Remediation Consent Order and Agreement (“PNG-COA”) with the DEP. The PNG-COA requires PNG to perform annually a specified level of activities associated with environmental investigation and remediation work at certain properties on which MGP-related facilities were operated (“PNG MGP Properties”). Under these agreements, environmental expenditures relating to the CPG MGP Properties and the PNG MGP Properties are capped at $1.8 and $1.1 , respectively, in any calendar year. The CPG-COA is currently scheduled to terminate at the end of 2013. The PNG-COA terminates in 2019 but may be terminated

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

by either party effective at the end of any two-year period beginning with the original effective date in March 2004. At September 30, 2013 and 2012 , our accrued liabilities for environmental investigation and remediation costs related to the CPG-COA and the PNG-COA totaled $14.0 and $15.0 , respectively. Because CPG and PNG are currently receiving regulatory recovery of estimated environmental investigation and remediation costs associated with Pennsylvania sites, in accordance with GAAP related to rate-regulated entities we have recorded associated regulatory assets in equal amounts.
From the late 1800s through the mid-1900s, UGI Utilities and its former subsidiaries owned and operated a number of MGPs prior to the general availability of natural gas. Some constituents of coal tars and other residues of the manufactured gas process are today considered hazardous substances under the Superfund Law and may be present on the sites of former MGPs. Between 1882 and 1953, UGI Utilities owned the stock of subsidiary gas companies in Pennsylvania and elsewhere and also operated the businesses of some gas companies under agreement. Pursuant to the requirements of the Public Utility Holding Company Act of 1935, by the early 1950s UGI Utilities divested all of its utility operations other than certain Pennsylvania operations, including those which now constitute UGI Gas and Electric Utility.
UGI Utilities does not expect its costs for investigation and remediation of hazardous substances at Pennsylvania MGP sites to be material to its results of operations because (1) UGI Gas is currently permitted to include in rates, through future base rate proceedings, a five -year average of such prudently incurred remediation costs and (2) CPG and PNG are currently receiving regulatory recovery of estimated environmental investigation and remediation costs associated with Pennsylvania sites. At September 30, 2013 , neither the undiscounted nor the accrued liability for environmental investigation and cleanup costs for UGI Gas was material.
From time to time, UGI Utilities is notified of sites outside Pennsylvania on which private parties allege MGPs were formerly owned or operated by it or owned or operated by its former subsidiaries. Such parties generally investigate the extent of environmental contamination or perform environmental remediation. Management believes that under applicable law UGI Utilities should not be liable in those instances in which a former subsidiary owned or operated an MGP. There could be, however, significant future costs of an uncertain amount associated with environmental damage caused by MGPs outside Pennsylvania that UGI Utilities directly operated, or that were owned or operated by former subsidiaries of UGI Utilities if a court were to conclude that (1) the subsidiary’s separate corporate form should be disregarded or (2) UGI Utilities should be considered to have been an operator because of its conduct with respect to its subsidiary’s MGP.
Omaha, Nebraska . By letter dated October 20, 2011, the City of Omaha and the Metropolitan Utilities District (“MUD”) notified UGI Utilities that they had been requested by the United States Environmental Protection Agency (“EPA”) to remediate a former manufactured gas plant site located in Omaha, Nebraska. According to a report prepared on behalf of the EPA identifying potentially responsible parties, a former subsidiary of a UGI Utilities predecessor is identified as an owner and operator of the site. The City of Omaha and MUD have requested that UGI Utilities participate in the cost of remediation for this site. Because of the preliminary nature of available environmental information, the ultimate amount or range of possible clean up costs cannot be reasonably estimated. In addition, UGI Utilities believes that it has strong defenses to any claims that may arise relating to the remediation of this site. By letter dated November 10, 2011, the EPA notified UGI Utilities of its investigation of the site in Omaha, Nebraska, and issued an information request to UGI Utilities. UGI Utilities responded to the EPA’s information request on January 17, 2012. There have been no recent developments in this matter.
AmeriGas Propane
AmeriGas OLP Saranac Lake. By letter dated March 6, 2008, the New York State Department of Environmental Conservation (“DEC”) notified AmeriGas OLP that DEC had placed property owned by the Partnership in Saranac Lake, New York, on its Registry of Inactive Hazardous Waste Disposal Sites. A site characterization study performed by DEC disclosed contamination related to former MGP operations on the site. DEC has classified the site as a significant threat to public health or environment with further action required. The Partnership has researched the history of the site and its ownership interest in the site. The Partnership has reviewed the preliminary site characterization study prepared by the DEC, the extent of contamination and the possible existence of other potentially responsible parties. The Partnership communicated the results of its research to DEC in January 2009. There have been no recent developments in this matter. Because of the preliminary nature of available environmental information, the ultimate amount or range of possible clean up costs cannot be reasonably estimated.  
Claremont, New Hampshire and Chestertown, Maryland.  In connection with the Heritage Acquisition on January 12, 2012, a predecessor of Titan Propane LLC (“Titan LLC”), a former subsidiary acquired in the Heritage Acquisition, is purportedly the beneficial holder of title with respect to two former MGPs discussed below. The Contribution Agreement provides for indemnification from ETP for certain expenses associated with remediation of these sites. By letter dated September 30, 2010, the EPA notified Titan LLC that it may be a potentially responsible party (“PRP”) for clean up costs associated with contamination

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

at a former MGP in Claremont, New Hampshire. In June 2010, the Maryland Attorney General (“MAG”) identified Titan LLC as a PRP in connection with contamination at a former MGP in Chestertown, Maryland and requested that Titan LLC participate in characterization and remediation activities. Titan LLC has supplied the EPA and MAG with corporate and bankruptcy information for its predecessors to support its claim that it is not liable for any remediation costs at the sites. Because of the preliminary nature of available environmental information, the ultimate amount or range of possible clean up costs cannot be reasonably estimated.
Other Matters
AmeriGas Cylinder Investigation. On or about October 21, 2009, the General Partner received a notice that the Offices of the District Attorneys of Santa Clara, Sonoma, Ventura, San Joaquin and Fresno Counties and the City Attorney of San Diego (the “District Attorneys”) had commenced an investigation into AmeriGas OLP's cylinder labeling and filling practices in California as a result of the Partnership’s decision in 2008 to reduce the volume of propane from 17 pounds to 15 pounds in the cylinders it provides to retailers who then sell them to consumers. At that time, the District Attorneys issued an administrative subpoena seeking documents and information relating to those practices. We have responded to the administrative subpoena. On or about July 20, 2011, the General Partner received a second subpoena from the District Attorneys. The subpoena sought additional information and documents regarding AmeriGas OLP’s cylinder exchange program. We responded to that subpoena. In connection with this matter, the District Attorneys have alleged potential violations of California's antitrust and unfair competition laws, California’s slack-fill law, and California’s principal false advertising statute. On November 20, 2013, the District Attorneys filed a complaint against the General Partner and AmeriGas OLP and simultaneously filed a proposed stipulated final consent judgment (the “Judgment”) which was approved by the court on December 2, 2013 and resolved all claims against those defendants that were known to the District Attorneys at that time. The Judgment requires the General Partner to pay a civil penalty and to certain injunctive relief including the posting of a consumer notice on all cylinder cages in California.  That notice informs consumers, among other things, of the reduction of propane in weight from 17 pounds to 15 pounds.  The Judgment will not have a material effect on our consolidated financial position, results of operations or cash flows.

Federal Trade Commission Investigation of Propane Grill Cylinder Filling Practices. On or about November 4, 2011, the General Partner received notice that the Federal Trade Commission (“FTC”) is conducting an antitrust and consumer protection investigation into certain practices of the Partnership that relate to the filling of portable propane cylinders. On February 2, 2012, the Partnership received a Civil Investigative Demand from the FTC that requested documents and information concerning, among other things, (i) the Partnership’s decision, in 2008, to reduce the volume of propane in cylinders it sells to consumers from 17 pounds to 15 pounds and (ii) cross-filling, related service arrangements and communications regarding the foregoing with competitors. The Partnership responded to that subpoena and has continued to cooperate with the FTC’s requests for information. The Partnership believes it has good defenses to any claims that may result from this investigation. We are not able to assess the financial impact this investigation or any related claims may have on the Partnership.
Purported Class Action Lawsuit. In 2005, Samuel and Brenda Swiger (the “Swigers”) filed what purports to be a class action lawsuit in the Circuit Court of Harrison County, West Virginia, against UGI, an insurance subsidiary of UGI, certain officers of UGI and the General Partner, and their insurance carriers and insurance adjusters. In this lawsuit, the Swigers are seeking compensatory and punitive damages on behalf of the putative class for alleged violations of the West Virginia Insurance Unfair Trade Practice Act, negligence, intentional misconduct, and civil conspiracy. The Court has not certified the class. We believe we have good defenses to the claims in this action.

Antargaz Competition Authority Matter. On July 21, 2009, Antargaz received a Statement of Objections (“Statement”) from France’s Autorité de la concurrence (“Competition Authority”) with respect to the investigation of Antargaz by the General Division of Competition, Consumption and Fraud Punishment. The Statement alleged that Antargaz engaged in certain anti-competitive practices in violation of French competition laws related to the cylinder market during the period from 1999 through 2004. On December 17, 2010, the Competition Authority issued its decision dismissing all objections against Antargaz. The appeal period expired without an appeal being filed. As a result of the decision, during the three-month period ended December 31, 2010, the Company reversed its previously recorded nontaxable accrual for this matter which increased Fiscal 2011 net income by $9.4 .

We cannot predict the final results of any of the environmental or other pending claims or legal actions described above. However, it is reasonably possible that some of them could be resolved unfavorably to us and result in losses in excess of recorded amounts. We are unable to estimate any possible losses in excess of recorded amounts. Although we currently believe, after consultation with counsel, that damages or settlements in amounts in excess of recorded amounts, if any, recovered by the plaintiffs in such claims or actions will not have a material adverse effect on our financial position, damages or settlements could be material to our operating results or cash flows in future periods depending on the nature and timing of future developments with respect to these matters and the amounts of future operating results and cash flows. In addition to the matters described above, there are other

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

pending claims and legal actions arising in the normal course of our businesses. We believe, after consultation with counsel, the final outcome of such other matters will not have a material effect on our consolidated financial position, results of operations or cash flows.

Note 17 — Fair Value Measurements
Derivative Financial Instruments
The following table presents our financial assets and financial liabilities that are measured at fair value on a recurring basis for each of the fair value hierarchy levels, including both current and noncurrent portions, as of September 30, 2013 and 2012 :

	
																
 	Asset (Liability)	
 	Quoted Prices
in Active
Markets for
Identical Assets
and Liabilities
(Level 1)	 	Significant
Other
Observable
Inputs
(Level 2)	 	Unobservable
Inputs
(Level 3)	 	Total	
September 30, 2013:	 	 	 	 	 	 	 	
Assets:	 	 	 	 	 	 	 	
Derivative financial instruments:	 	 	 	 	 	 	 	
Commodity contracts	$	2.1		 	$	21.2		 	$	—		 	$	23.3		
Foreign currency contracts	$	—		 	$	0.9		 	$	—		 	$	0.9		
Liabilities:	 	 	 	 	 	 	 	
Derivative financial instruments:	 	 	 	 	 	 	 	
Commodity contracts	$	(9.7	)	 	$	(6.3	)	 	$	—		 	$	(16.0	)	
Foreign currency contracts	$	—		 	$	(7.2	)	 	$	—		 	$	(7.2	)	
Interest rate contracts	$	—		 	$	(31.0	)	 	$	—		 	$	(31.0	)	
Cross-currency swaps	$	—		 	$	(1.2	)	 	$	—		 	$	(1.2	)	
 	 	 	 	 	 	 	 	
September 30, 2012:	 	 	 	 	 	 	 	
Assets:	 	 	 	 	 	 	 	
Derivative financial instruments:	 	 	 	 	 	 	 	
Commodity contracts	$	8.6		 	$	4.5		 	$	—		 	$	13.1		
Foreign currency contracts	$	—		 	$	1.8		 	$	—		 	$	1.8		
Liabilities:	 	 	 	 	 	 	 	
Derivative financial instruments:	 	 	 	 	 	 	 	
Commodity contracts	$	(7.8	)	 	$	(53.2	)	 	$	—		 	$	(61.0	)	
Interest rate contracts	$	—		 	$	(71.9	)	 	$	—		 	$	(71.9	)	

The fair values of our Level 1 exchange-traded commodity futures and option contracts and non exchange-traded commodity futures and forward contracts are based upon actively-quoted market prices for identical assets and liabilities. The remainder of our derivative financial instruments are designated as Level 2. The fair values of certain non-exchange traded commodity derivatives designated as Level 2 are based upon indicative price quotations available through brokers, industry price publications or recent market transactions and related market indicators. For commodity option contracts designated as Level 2 which are not traded on an exchange, we use a Black Scholes option pricing model that considers time value and volatility of the underlying commodity. The fair values of our Level 2 interest rate contracts and foreign currency contracts are based upon third-party quotes or indicative values based on recent market transactions. There were no transfers between Level 1 and Level 2 during the periods presented.
Other Financial Instruments

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

The carrying amounts of other financial instruments included in current assets and current liabilities (except for current maturities of long-term debt) approximate their fair values because of their short-term nature. At September 30, 2013 , the carrying amount and estimated fair value of our long-term debt (including current maturities) were $3,609.4 and $3,761.8 , respectively. At September 30, 2012 , the carrying amount and estimated fair value of our long-term debt (including current maturities) were $3,514.3 and $3,787.6 , respectively. We estimate the fair value of long-term debt by using current market rates and by discounting future cash flows using rates available for similar type debt (Level 2).
Financial instruments other than derivative financial instruments, such as our short-term investments and trade accounts receivable, could expose us to concentrations of credit risk. We limit our credit risk from short-term investments by investing only in investment-grade commercial paper, money market mutual funds, securities guaranteed by the U.S. Government or its agencies and FDIC insured bank deposits. The credit risk from trade accounts receivable is limited because we have a large customer base which extends across many different U.S. markets and several foreign countries. For information regarding concentrations of credit risk associated with our derivative financial instruments, see Note 18 . Our investment in a private equity partnership is measured at fair value on a non-recurring basis. Generally this measurement uses Level 3 fair value inputs because the investment does not have a readily available market value.

Note 18 — Disclosures About Derivative Instruments and Hedging Activities
We are exposed to certain market risks related to our ongoing business operations. Management uses derivative financial and commodity instruments, among other things, to manage these risks. The primary risks managed by derivative instruments 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 risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes. The use of derivative instruments is controlled by our risk management and credit policies which govern, among other things, the derivative instruments we can use, counterparty credit limits and contract authorization limits. A substantial portion of our derivative financial instruments, other than commodity derivative instruments at Midstream & Marketing, are designated and qualify as cash flow hedges or net investment hedges. Substantially all of Midstream & Marketing’s commodity derivative instruments are not accounted for as hedges under GAAP. Because a substantial portion of our derivative instruments qualify for and are designated as hedges under GAAP or are subject to regulatory rate recovery mechanisms, we expect that changes in the fair value of derivative instruments used to manage commodity, interest rate or currency exchange rate risk would be substantially offset by gains or losses on the associated anticipated transactions.
Commodity Price Risk
In order to manage market price risk associated with the Partnership’s fixed-price programs which permit customers to lock in the prices they pay for propane principally during the months of October through March, the Partnership uses over-the-counter derivative commodity instruments, principally price swap contracts. In addition, the Partnership, certain other domestic business units and our UGI International operations also use over-the-counter price swap and option contracts to reduce commodity price volatility associated with a portion of their forecasted LPG purchases. In addition, the Partnership from time to time enters into price swap and put option agreements to reduce the effects of short-term commodity price volatility which agreements are generally not designated as hedges for accounting purposes.
Gas Utility’s tariffs contain clauses that permit recovery of all of the prudently incurred costs of natural gas it sells to retail core-market customers, including the cost of financial instruments used to hedge purchased gas costs. As permitted and agreed to by the PUC pursuant to Gas Utility’s annual PGC filings, Gas Utility currently uses New York Mercantile Exchange (“NYMEX”) natural gas futures and option contracts to reduce commodity price volatility associated with a portion of the natural gas it purchases for its retail core-market customers. At September 30, 2013 and 2012 , the volumes of natural gas associated with Gas Utility’s unsettled NYMEX natural gas futures and option contracts totaled 15.0  million dekatherms and 19.2  million dekatherms, respectively. At September 30, 2013 , the maximum period over which Gas Utility is hedging natural gas market price risk is 12  months. Gains and losses on natural gas futures contracts and any gains on natural gas option contracts are recorded in regulatory assets or liabilities on the Consolidated Balance Sheets in accordance with GAAP related to rate-regulated entities and reflected in cost of sales through the PGC mechanism (see Note 9 ).
Electric Utility’s DS tariffs permit the recovery of all prudently incurred costs of electricity it sells to DS customers, including the cost of financial instruments used to hedge electricity costs. Electric Utility enters into forward electricity purchase contracts to meet a substantial portion of its electricity supply needs. Because these contracts currently do not qualify for the normal purchases and normal sales exception under GAAP, the fair values of these contracts are required to be recognized on the balance sheet. At September 30, 2013 and 2012 , the fair values of Electric Utility’s forward purchase power agreements comprising losses of $4.8

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

and $9.2 , respectively, are reflected in current derivative financial instrument liabilities and other noncurrent liabilities in the accompanying Consolidated Balance Sheets. In accordance with GAAP related to rate-regulated entities, Electric Utility has recorded equal and offsetting amounts in regulatory assets. At September 30, 2013 and 2012 , the volumes of Electric Utility’s forward electricity purchase contracts were 245.8 million kilowatt hours and 570.4  million kilowatt hours, respectively. At September 30, 2013 , the maximum period over which these contracts extend is 8  months.
In order to reduce volatility associated with a substantial portion of its electricity transmission congestion costs, Electric Utility obtains FTRs through an annual allocation process and by purchases of FTRs at monthly auctions. Midstream & Marketing purchases FTRs to economically hedge electricity transmission congestion costs associated with its fixed-price electricity sales contracts. FTRs are derivative financial instruments that entitle the holder to receive compensation for electricity transmission congestion charges that result when there is insufficient electricity transmission capacity on the electric transmission grid. Because Electric Utility is entitled to fully recover its DS costs, gains and losses on Electric Utility FTRs are recorded in regulatory assets or liabilities in accordance with GAAP related to rate-regulated entities and reflected in cost of sales through the DS recovery mechanism (see Note 9 ). Midstream & Marketing from time to time also enters into New York Independent System Operator (“NYISO”) capacity swap contracts to economically hedge the locational basis differences for customers it serves on the NYISO electricity grid. At September 30, 2013 and 2012 , the volumes associated with Electric Utility FTRs totaled 189.3 million kilowatt hours and 189.7  million kilowatt hours, respectively. Midstream & Marketing’s FTRs and capacity swap contracts are recorded at fair value with changes in fair value reflected in cost of sales. At September 30, 2013 and 2012 , the volumes associated with Midstream & Marketing’s FTRs and NYISO capacity swap contracts totaled 1,401.9  million kilowatt hours and 988.8  million kilowatt hours, respectively.
In order to manage market price risk relating to fixed-price sales contracts for natural gas and electricity, Midstream & Marketing enters into NYMEX and over-the-counter natural gas futures contracts, IntercontinentalExchange (“ICE”) natural gas basis swap contracts, and electricity futures contracts. Midstream & Marketing also uses NYMEX and over the counter electricity futures contracts to hedge the price of a portion of its anticipated future sales of electricity from its electric generation facilities. In addition, Midstream & Marketing uses NYMEX futures contracts to economically hedge the gross margin associated with the purchase and anticipated later sale of natural gas or propane. Substantially all of Midstream & Marketing’s derivative financial instruments described above are not accounted for as hedges under GAAP. These derivative instruments are recorded at fair value with changes in fair value reflected in income. As a result, volatility in Midstream and Marketing’s results can occur due to changes in the fair value of unsettled derivative instruments. Volatility can also occur as a result of timing differences between the settlement of financial derivatives and the sale or purchase of the corresponding physical commodity that was economically hedged.
At September 30, 2013 and September 30, 2012, total volumes associated with Midstream & Marketing’s natural gas futures contracts associated with forecasted purchases of natural gas totaled 24.3 million dekatherms and 23.6 million dekatherms, respectively. At September 30, 2013 and 2012, total volumes associated with Midstream & Marketing’s electricity call contracts and electricity put contracts totaled 754.4 million kilowatt hours and 393.0 million kilowatt hours, and 1,415.7 million kilowatt hours and 135.3 million kilowatt hours, respectively. At September 30, 2013 , the volumes associated with Midstream & Marketing’s natural gas and propane storage NYMEX contracts totaled 2.9  million dekatherms and 2.8  million gallons, respectively. At September 30, 2012 , the volumes associated with Midstream & Marketing’s natural gas and propane storage NYMEX contracts totaled 4.3 million dekatherms and 3.1 million gallons, respectively.
In order to reduce operating expense volatility, UGI Utilities from time to time enters into NYMEX gasoline futures and swap contracts for a portion of gasoline volumes expected to be used in the operation of its vehicles and equipment. Associated volumes, fair values and effects on net income were not material for all periods presented.
At September 30, 2013 and 2012 , we had the following outstanding derivative commodity instruments volumes that qualify for hedge accounting treatment:

	
							
 	 	Volumes	
Commodity	 	2013	 	2012	
LPG (millions of gallons)	 	279.0		 	243.9		
Electricity calls (millions of kilowatt hours)	 	594.8		 	1,151.7		

At September 30, 2013 , the maximum period over which we are hedging our exposure to the variability in cash flows associated with LPG commodity price risk is 24  months with a weighted average of 6  months and the maximum period over which

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

we are hedging our exposure to the variability in cash flows associated with electricity price risk (excluding Electric Utility) is 24   months for electricity forward purchase contracts, with a weighted average of 8  months.
We account for commodity price risk contracts (other than Midstream & Marketing’s contracts that are not designated as accounting hedges and Gas Utility and Electric Utility contracts that are subject to regulatory treatment) as cash flow hedges. Changes in the fair values of contracts qualifying for cash flow hedge accounting are recorded in AOCI and, with respect to the Partnership, noncontrolling interests, to the extent effective in offsetting changes in the underlying commodity price risk. When earnings are affected by the hedged commodity, gains or losses are recorded in cost of sales in the Consolidated Statements of Income. At September 30, 2013 , the amount of net losses associated with commodity price risk hedges expected to be reclassified into earnings during the next twelve months based upon current fair values is $13.6 .
Interest Rate Risk
Antargaz’ and Flaga’s long-term debt agreements have interest rates that are generally indexed to short-term market interest rates. Antargaz has entered into pay-fixed, receive-variable interest rate swap agreements to hedge the underlying euribor rate of interest on its variable-rate term loan, and Flaga has entered into pay-fixed, receive-variable interest rate swap agreements to hedge the underlying euribor rate of interest on its term loans, in each case through the respective scheduled maturity dates. As of September 30, 2013 and 2012 , the total notional amounts of variable-rate debt subject to interest rate swap agreements (excluding Flaga’s cross-currency swap as described below) were €440.5 and €441.9 , respectively.
Our domestic businesses’ long-term debt is typically issued at fixed rates of interest. As these long-term debt issues mature, we typically refinance such debt with new debt having interest rates reflecting then-current market conditions. In order to reduce market rate risk on the underlying benchmark rate of interest associated with near- to medium-term forecasted issuances of fixed-rate debt, from time to time we enter into interest rate protection agreements (“IRPAs”). At September 30, 2013 , we had no unsettled IRPAs. At September 30, 2012 , the total notional amount of unsettled IRPAs was $173.0 .
During Fiscal 2012, UGI Utilities reclassified pre-tax losses of $0.7 from AOCI into income as a result of the discontinuance of cash flow hedge accounting for a portion of expected interest payments associated with the issuance of long-term debt originally anticipated to occur in September 2012. Such losses are included in other income, net, in the 2012 Consolidated Statement of Income.
We account for interest rate swaps and IRPAs as cash flow hedges. Changes in the fair values of interest rate swaps and IRPAs are recorded in AOCI and, with respect to the Partnership, noncontrolling interests, to the extent effective in offsetting changes in the underlying interest rate risk, until earnings are affected by the hedged interest expense. At such time, gains and losses are recorded in interest expense. At September 30, 2013 , the amount of net losses associated with interest rate hedges (excluding pay-fixed, receive-variable interest rate swaps) expected to be reclassified into earnings during the next twelve months is $2.7 .
Foreign Currency Exchange Rate Risk
In order to reduce volatility, Antargaz hedges a portion of its anticipated U.S. dollar-denominated LPG product purchases through the use of forward foreign currency exchange contracts. The amount of dollar-denominated purchases of LPG associated with such contracts generally represents approximately 15% to 30% of estimated dollar-denominated purchases of LPG to occur during the heating-season months of October through March. At September 30, 2013 and 2012 , we were hedging a total of $200.2 and $174.5 of U.S. dollar-denominated LPG purchases, respectively. At September 30, 2013 , the maximum period over which we are hedging our exposure to the variability in cash flows associated with dollar-denominated purchases of LPG is 30  months with a weighted average of 11  months. From time to time we also enter into forward foreign currency exchange contracts to reduce the volatility of the U.S. dollar value on a portion of our International Propane euro-denominated net investments. At September 30, 2013 and 2012, we had no euro-dominated net investment hedges.
We account for foreign currency exchange contracts associated with anticipated purchases of U.S. dollar-denominated LPG as cash flow hedges. Changes in the fair values of these foreign currency exchange contracts are recorded in AOCI, to the extent effective in offsetting changes in the underlying currency exchange rate risk, until earnings are affected by the hedged LPG purchase, at which time gains and losses are recorded in cost of sales. At September 30, 2013 , the amount of net losses associated with currency rate risk (other than net investment hedges) expected to be reclassified into earnings during the next twelve months based upon current fair values is $2.5 . Gains and losses on net investment hedges are included in AOCI until such foreign operations are liquidated.

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

From time to time, the Company may enter into foreign currency exchange transactions to economically hedge the local-currency purchase price of anticipated foreign business acquisitions. These transactions do not qualify for hedge accounting treatment and any changes in fair value are recorded in other income, net.
Cross-Currency Swaps
During Fiscal 2013, Flaga entered into a cross-currency swap to hedge its exposure to the variability in expected future cash flows associatd with foreign currency and interest rate risk resulting from the issuance of $52.0 million of U.S. dollar denominated variable-rate debt. The cross-currency hedge includes initial and final exchanges of principal from a fixed euro denomination to a fixed U.S. denominated amount, to be exchanged at a specified rate, which was determined by the market spot rate on the date of issuance. The cross-currency swap also includes an interest rate swap of a fixed foreign-denominated interest rate to a fixed U.S. denominated interest rate. We have designated this cross-currency swap as a cash flow hedge. Changes in the fair value of our cross-currency swap is recorded in AOCI to the extent effective in offsetting changes in the underlying foreign currency exchange and interest rate risk. At September 30, 2013 , the amount of net losses associated with this cross-currency swap expected to be reclassified into earnings over the next twelve months is not material.
Derivative Financial Instrument Credit Risk
We are exposed to risk of loss in the event of nonperformance by our derivative financial instrument counterparties. Our derivative financial instrument counterparties principally comprise large energy companies and major U.S. and international financial institutions. We maintain credit policies with regard to our counterparties that we believe reduce overall credit risk. These policies include evaluating and monitoring our counterparties’ financial condition, including their credit ratings, and entering into agreements with counterparties that govern credit limits or entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. Certain of these agreements call for the posting of collateral by the counterparty or by the Company in the form of letters of credit, parental guarantees or cash. Additionally, our natural gas and electricity exchange-traded futures contracts generally require cash deposits in margin accounts. At September 30, 2013 and 2012 , restricted cash in brokerage accounts totaled $7.0 and $3.0 , respectively. Although we have concentrations of credit risk associated with derivative financial instruments, the maximum amount of loss, based upon the gross fair values of the derivative financial instruments, we would incur if these counterparties failed to perform according to the terms of their contracts was not material at September 30, 2013 . 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, 2013 , if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material.

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

The following table provides information regarding the balance sheet location and fair value of derivative assets and liabilities existing as of September 30, 2013 and 2012 :

	
																				
 	Derivative Assets	 	Derivative Liabilities	
 	 	 	Fair Value	 	 	 	Fair Value	
 	 	 	September 30,	 	 	 	September 30,	
 	Balance Sheet
Location	 	2013	 	2012	 	Balance Sheet
Location	 	2013	 	2012	
Derivatives Designated as Hedging Instruments:	 	 	 	 	 	 	 	 	 	 	 	
 Commodity contracts	Derivative financial instruments
and Other assets	 	$	16.1		 	$	3.3		 	Derivative financial instruments
and Other noncurrent liabilities	 	$	(2.6	)	 	$	(43.6	)	
Foreign currency contracts	Derivative financial instruments
and Other assets	 	0.9		 	1.8		 	Derivative financial instruments
and Other noncurrent liabilities	 	(7.2	)	 	—		
Cross-currency contracts	 	 	—		 	—		 	Derivative financial instruments
and Other noncurrent liabilities	 	(1.2	)	 	—		
Interest rate contracts	 	 	—		 	—		 	Derivative financial instruments
and Other noncurrent liabilities	 	(31.0	)	 	(71.9	)	
Total Derivatives Designated as Hedging Instruments	 	 	$	17.0		 	$	5.1		 	 	 	$	(42.0	)	 	$	(115.5	)	
Derivatives Accounted for Under ASC 980:	 	 	 	 	 	 	 	 	 	 	 	
Commodity contracts	Derivative financial instruments	 	$	—		 	$	5.3		 	Derivative financial instruments
and Other noncurrent liabilities	 	$	(6.7	)	 	$	(9.4	)	
Derivatives Not Designated as Hedging Instruments:	 	 	 	 	 	 	 	 	 	 	 	
Commodity contracts	Derivative financial instruments
and Other assets	 	$	7.2		 	$	4.5		 	Derivative financial instruments	 	$	(6.7	)	 	$	(8.0	)	
Total Derivatives	 	 	$	24.2		 	$	14.9		 	 	 	$	(55.4	)	 	$	(132.9	)	

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

The following tables provide information on the effects of derivative instruments in the Consolidated Statement of Income and changes in AOCI and noncontrolling interest for Fiscal 2013 and 2012 :

																										
 	Gain or (Loss)
Recognized in
AOCI and
Noncontrolling Interests	 	Gain or (Loss)
Reclassified from
AOCI and Noncontrolling
Interests into Income	 	Location of Gain or (Loss) Reclassified from
AOCI and Noncontrolling
Interests into Income	
 	2013	 	2012	 	2011	 	2013	 	2012	 	2011	 		
Cash Flow Hedges:	 	 	 	 	 	 	 	 	 	 	 	 	 	
Commodity contracts	$	8.3		 	$	(98.0	)	 	$	27.3		 	$	(49.5	)	 	$	(61.4	)	 	$	35.3		 	Cost of sales	
Foreign currency contracts	(8.3	)	 	(0.5	)	 	6.9		 	(0.1	)	 	2.1		 	(0.8	)	 	Cost of sales	
Cross-currency contracts	(1.2	)	 	—		 	—		 	—		 	—		 	—		 	 	
Interest rate contracts	22.9		 	(36.8	)	 	(35.8	)	 	(14.2	)	 	(11.5	)	 	(14.1	)	 	Interest expense /other income	
Total	$	21.7		 	$	(135.3	)	 	$	(1.6	)	 	$	(63.8	)	 	$	(70.8	)	 	$	20.4		 	 	
Net Investment Hedges:	 	 	 	 	 	 	 	 	 	 	 	 	 	
Foreign currency contracts	$	—		 	$	0.6		 	$	0.2		 	 	 	 	 	 	 	 	

	
														
Derivatives Not Designated as Hedging Instruments:	 	 	 	 	 	 	 	
 	Gain or (Loss)
Recognized in Income	Location of
Gain or (Loss)
Recognized in Income	 	
 	2013	 	2012	 	2011			
Commodity contracts	$	9.3		 	$	0.1		 	$	29.7		Cost of sales	 	
Commodity contracts	—		 	0.2		 	0.3		Operating expenses / other income	 	
Foreign currency contracts	(0.4	)	 	0.5		 	(6.1	)	Other income	 	
Total	$	8.9		 	$	0.8		 	$	23.9		 	 	

The amounts of derivative gains or losses representing ineffectiveness, and the amounts of gains or losses recognized in income as a result of excluding derivatives from ineffectiveness testing, were not material for Fiscal 2013 , Fiscal 2012 and Fiscal 2011 .
As a result of the Partnership’s refinancing of its 7.125% Senior Notes (see Note 6 ), during the three months ended September 30, 2011, the Partnership discontinued cash flow hedge accounting for settled but unamortized IRPA losses associated with AmeriGas Partners Senior Notes and recorded a loss of $2.6 which amount is included in loss on extinguishments of debt on the Fiscal 2011 Consolidated Statement of Income.
We are also a party to a number of other contracts that have elements of a derivative instrument. These contracts include, among others, binding purchase orders, contracts which provide for the purchase and delivery, or sale, of natural gas, LPG and electricity, and service contracts that require the counterparty to provide commodity storage, transportation or capacity service to meet our normal sales commitments. Although many of these contracts have the requisite elements of a derivative instrument, these contracts qualify for normal purchases and normal sales exception accounting under GAAP because they provide for the delivery of products or services in quantities that are expected to be used in the normal course of operating our business and the price in the contract is based on an underlying that is directly associated with the price of the product or service being purchased or sold.

Note 19 — Energy Services Accounts Receivable Securitization Facility
At September 30, 2013, Energy Services had a $100 million receivables purchase facility (“Receivables Facility”) with an issuer of receivables-backed commercial paper. Prior to its scheduled expiration on November 1, 2013, Energy Services extended its Receivables Facility until October 31, 2014, and amended the Receivables Facility to better align its borrowing limits with

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Energy Services’ seasonal borrowing needs. The Receivables Facility, as amended, provides Energy Services with the ability to borrow up to $150 million of eligible receivables during the period November 1, 2013 to May 31, 2014, and up to $75 million of eligible receivables during the period June 1, 2014 to October 31, 2014.
Under the Receivables Facility, Energy Services transfers, on an ongoing basis and without recourse, its trade accounts receivable to its wholly owned, special purpose subsidiary, Energy Services Funding Corporation (“ESFC”), which is consolidated for financial statement purposes. ESFC, in turn, has sold, and subject to certain conditions, may from time to time sell, an undivided interest in some or all of the receivables to a commercial paper conduit of a major bank (through September 30, 2013) and, subsequent to September 30, 2013, to the bank itself . ESFC was created and has been structured to isolate its assets from creditors of Energy Services and its affiliates, including UGI. Trade receivables sold to the commercial paper conduit or the bank remain on the Company’s balance sheet and the Company reflects a liability equal to the amount advanced by the commercial paper conduit or the bank. The Company records interest expense on amounts owed to the commercial paper conduit or the bank. Energy Services continues to service, administer and collect trade receivables on behalf of the commercial paper issuer and ESFC.
During Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , Energy Services transferred trade receivables totaling $975.3 , $836.0 and $1,134.9 , respectively, to ESFC. During Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , ESFC sold an aggregate $291.0 , $286.0 and $88.0 , respectively, of undivided interests in its trade receivables to the commercial paper conduit. At September 30, 2013 , the outstanding balance of ESFC trade receivables was $55.0 of which $30.0 was sold to the commercial paper conduit and reflected on the Consolidated Balance Sheet as bank loans. At September 30, 2012 , the outstanding balance of ESFC trade receivables was $43.5 of which no amount was sold to the commercial paper conduit. Losses on sales of receivables to the commercial paper conduit during Fiscal 2013 , Fiscal 2012 and Fiscal 2011 , which amounts are included in interest expense on the Consolidated Statements of Income, totaled $0.7 , $1.0 and $1.2 , respectively.

Note 20 — Other Income, Net
Other income, net, comprises the following:

	
												
 	2013	 	2012	 	2011	
Interest and interest-related income	$	2.2		 	$	2.4		 	$	2.3		
Antargaz Competition Authority matter	—		 	—		 	9.4		
Utility non-tariff service income	2.8		 	2.7		 	6.4		
Foreign currency hedge (loss) gain	(0.4	)	 	0.5		 	(6.1	)	
Finance charges	21.4		 	18.8		 	15.1		
Loss on private equity partnership investment	(6.3	)	 	—		 	—		
Other, net	13.1		 	15.4		 	18.4		
Total other income, net	$	32.8		 	$	39.8		 	$	45.5		

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Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Note 21 — Quarterly Data (unaudited)
The following unaudited quarterly data includes adjustments (consisting only of normal recurring adjustments with the exception of those indicated below) which we consider necessary for a fair presentation unless otherwise indicated and reflects the revisions or restatements to correct the errors described in Note 3. Our quarterly results fluctuate because of the seasonal nature of our businesses.

																																		
 	December 31, 2012	 	March 31, 2013	 	June 30, 2013	 	September 30, 2013 (a)	
 	As Previously Reported	Adjustments	As Revised (See Note 3)	 	As Previously Reported	Adjustments	As Restated (See Note 3)	 	As Previously Reported	Adjustments	As Revised (See Note 3)	 		
Revenues	$	2,023.2		$	(4.5	)	$	2,018.7		 	$	2,537.1		$	5.6		$	2,542.7		 	$	1,372.3		$	2.0		$	1,374.3		 	$	1,259.0		
Costs and expenses:	 	 	 	 	 	 	 	 	 	 	 	 	 	
Cost of sales (excluding depreciation shown below)	1,218.8		(3.3	)	1,215.5		 	1,500.6		(13.9	)	1,486.7		 	827.9		8.9		836.8		 	785.4		
Operating and administrative expenses	426.9		—		426.9		 	465.8		(4.3	)	461.5		 	404.7		2.8		407.5		 	396.1		
Utility taxes other than income taxes	4.3		—		4.3		 	4.7		—		4.7		 	3.7		—		3.7		 	4.2		
Depreciation	71.8		0.7		72.5		 	71.7		2.3		74.0		 	76.5		(0.1	)	76.4		 	78.5		
Amortization	15.3		—		15.3		 	15.6		—		15.6		 	15.4		—		15.4		 	15.4		
Other income, net	(10.0	)	—		(10.0	)	 	(7.5	)	—		(7.5	)	 	(9.0	)	2.0		(7.0	)	 	(8.3	)	
 	1,727.1		(2.6	)	1,724.5		 	2,050.9		(15.9	)	2,035.0		 	1,319.2		13.6		1,332.8		 	1,271.3		
Operating income (loss)	296.1		(1.9	)	294.2		 	486.2		21.5		507.7		 	53.1		(11.6	)	41.5		 	(12.3	)	
Income (loss) from equity investees	—		—		—		 	0.1		—		0.1		 	—		—		—		 	(0.5	)	
Interest expense	(60.3	)	(1.2	)	(61.5	)	 	(60.1	)	—		(60.1	)	 	(59.2	)	—		(59.2	)	 	(59.5	)	
Income (loss) before income taxes	235.8		(3.1	)	232.7		 	426.2		21.5		447.7		 	(6.1	)	(11.6	)	(17.7	)	 	(72.3	)	
Income tax (expense) benefit	(65.1	)	0.2		(64.9	)	 	(100.0	)	(6.0	)	(106.0	)	 	(9.0	)	3.9		(5.1	)	 	13.2		
Net income (loss)	170.7		(2.9	)	167.8		 	326.2		15.5		341.7		 	(15.1	)	(7.7	)	(22.8	)	 	(59.1	)	
(Deduct net income) add net loss attributable to noncontrolling interests, principally in AmeriGas Partners	(68.1	)	2.8		(65.3	)	 	(154.3	)	(6.7	)	(161.0	)	 	29.8		2.1		31.9		 	44.9		
Net income (loss) attributable to UGI Corporation	$	102.6		$	(0.1	)	$	102.5		 	$	171.9		$	8.8		$	180.7		 	$	14.7		$	(5.6	)	$	9.1		 	$	(14.2	)	
Earnings (loss) per common share attributable to UGI Corporation stockholders:	 	 	 	 	 	 	 	 	 	 	 	
Basic	$	0.91		 	$	0.91		 	$	1.51		 	$	1.59		 	$	0.13		 	$	0.08		 	$	(0.12	)	
Diluted	$	0.90		 	$	0.90		 	$	1.49		 	$	1.57		 	$	0.13		 	$	0.08		 	$	(0.12	)	
Average common shares outstanding (thousands):	 	 	 	 	 	 	 	 	 	 	 	
Basic	113,136		 	113,136		 	113,709		 	113,709		 	114,240		 	114,240		 	114,598		
Diluted	114,490		 	114,490		 	115,199		 	115,199		 	116,196		 	116,196		 	114,598		

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UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

	
																																								
 	December 31, 2011 (b)	 	March 31, 2012 (c)	 	June 30, 2012	 	September 30, 2012	
 	As Previously Reported	Adjustments	As Restated (See Note 3)	 	As Previously Reported	Adjustments	As Revised (See Note 3)	 	As Previously Reported	Adjustments	As Restated (See Note 3)	 	As Previously Reported	Adjustments	As Revised (See Note 3)	
Revenues	$	1,688.8		$	(2.0	)	$	1,686.8		 	$	2,427.5		$	0.3		$	2,427.8		 	$	1,277.2		$	3.5		$	1,280.7		 	$	1,125.7		$	0.3		$	1,126.0		
Costs and expenses:	 	 	 	 	 	 	 	 	 	 	 	 	—	 	 	
Cost of sales (excluding depreciation shown below)	1,101.8		20.5		1,122.3		 	1,526.6		(2.3	)	1,524.3		 	810.2		(17.5	)	792.7		 	672.6		(12.8	)	659.8		
Operating and administrative expenses	342.4		0.3		342.7		 	443.3		0.5		443.8		 	405.8		(1.3	)	404.5		 	400.2		(0.1	)	400.1		
Utility taxes other than income taxes	4.1		—		4.1		 	4.9		—		4.9		 	3.9		—		3.9		 	4.4		—		4.4		
Depreciation	52.8		0.1		52.9		 	68.7		(0.2	)	68.5		 	69.5		(0.1	)	69.4		 	73.2		(0.8	)	72.4		
Amortization	7.5		—		7.5		 	14.1		—		14.1		 	15.1		—		15.1		 	15.1		—		15.1		
Other income, net	(8.1	)	—		(8.1	)	 	(10.9	)	(1.9	)	(12.8	)	 	(8.1	)	—		(8.1	)	 	(11.2	)	0.4		(10.8	)	
 	1,500.5		20.9		1,521.4		 	2,046.7		(3.9	)	2,042.8		 	1,296.4		(18.9	)	1,277.5		 	1,154.3		(13.3	)	1,141.0		
Operating income (loss)	188.3		(22.9	)	165.4		 	380.8		4.2		385.0		 	(19.2	)	22.4		3.2		 	(28.6	)	13.6		(15.0	)	
Loss from equity investees	(0.1	)	—		(0.1	)	 	—		—		—		 	(0.1	)	—		(0.1	)	 	(0.1	)	—		(0.1	)	
Loss on extinguishments of debt	—		—		—		 	(13.4	)	—		(13.4	)	 	0.1		—		0.1		 	—		—		—		
Interest expense	(36.0	)	—		(36.0	)	 	(65.3	)	2.8		(62.5	)	 	(61.3	)	0.4		(60.9	)	 	(58.9	)	(2.1	)	(61.0	)	
Income (loss) before income taxes	152.2		(22.9	)	129.3		 	302.1		7.0		309.1		 	(80.5	)	22.8		(57.7	)	 	(87.6	)	11.5		(76.1	)	
Income tax (expense) benefit	(42.1	)	8.8		(33.3	)	 	(75.1	)	(2.1	)	(77.2	)	 	4.0		(8.1	)	(4.1	)	 	13.6		(5.9	)	7.7		
Net income (loss)	110.1		(14.1	)	96.0		 	227.0		4.9		231.9		 	(76.5	)	14.7		(61.8	)	 	(74.0	)	5.6		(68.4	)	
(Deduct net income) add net loss attributable to noncontrolling interests, principally in AmeriGas Partners	(23.1	)	2.0		(21.1	)	 	(93.6	)	(2.0	)	(95.6	)	 	70.2		(3.1	)	67.1		 	59.3		2.8		62.1		
Net income (loss) attributable to UGI Corporation	$	87.0		$	(12.1	)	$	74.9		 	$	133.4		$	2.9		$	136.3		 	$	(6.3	)	$	11.6		$	5.3		 	$	(14.7	)	$	8.4		$	(6.3	)	
Earnings (loss) per common share attributable to UGI Corporation stockholders:	 	 	 	 	 	 	 	 	 	 	 	 	 	
Basic	$	0.78		 	$	0.67		 	$	1.19		 	$	1.21		 	$	(0.06	)	 	$	0.05		 	$	(0.13	)	 	$	(0.06	)	
Diluted	$	0.77		 	$	0.66		 	$	1.18		 	$	1.20		 	$	(0.06	)	 	$	0.05		 	$	(0.13	)	 	$	(0.06	)	
Average common shares outstanding (thousands):	 	 	 	 	 	 	 	 	 	 	 	 	 	
Basic	112,240		 	112,240		 	112,510		 	112,510		 	112,726		 	112,726		 	112,868		 	112,868		
Diluted	113,152		 	113,152		 	113,239		 	113,239		 	112,726		 	113,504		 	112,868		 	112,868		

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

The impacts of the corrections on the key financial metrics operating income (loss), net income (loss) attributable to UGI Corporation and diluted earnings (loss) per share for each of the relevant quarters in the two years ended September 30, 2013 is are follows:

	
																							
 	Fiscal 2013	 	Fiscal 2012	
 	December 31, 2012	March 31, 2013	June 30, 2013	 	December 31, 2011	March 31, 2012	June 30, 2012	September 30, 2012	
Operating income (loss):	 	 	 	 	 	 	 	 	
Midstream & Marketing hedge accounting	$	0.7		$	12.5		$	(6.9	)	 	(19.3	)	2.2		18.5		15.5		
Partnership customer credits	(2.8	)	7.0		—		 	(3.2	)	(0.4	)	3.2		(1.4	)	
Other (1)	0.2		2.0		(4.7	)	 	(0.4	)	2.4		0.7		(0.5	)	
Total	$	(1.9	)	$	21.5		$	(11.6	)	 	$	(22.9	)	$	4.2		$	22.4		$	13.6		
 	 	 	 	 	 	 	 	 	
Net income (loss) attributable to UGI Corporation:	 	 	 	 	 	 	 	 	
Midstream & Marketing hedge accounting	$	0.4		$	7.3		$	(4.1	)	 	$	(11.3	)	$	1.3		$	10.8		$	9.1		
Partnership customer credits	(0.4	)	1.1		—		 	(0.8	)	(0.1	)	0.5		(0.2	)	
Other (1)	(0.1	)	0.4		(1.5	)	 	—		1.7		0.3		(0.5	)	
Total	$	(0.1	)	$	8.8		$	(5.6	)	 	$	(12.1	)	$	2.9		$	11.6		$	8.4		
 	 	 	 	 	 	 	 	 	
Diluted earnings (loss) per share attributable to UGI Corporation stockholders:	 	 	 	 	 	 	 	 	
Midstream & Marketing hedge accounting	$	—		$	0.06		$	(0.04	)	 	$	(0.10	)	$	0.01		$	0.10		$	0.08		
Partnership customer credits	—		0.01		—		 	(0.01	)	—		—		—		
Other (1)	—		0.01		(0.01	)	 	—		0.02		—		(0.01	)	
Total	$	—		$	0.08		$	(0.05	)	 	$	(0.11	)	$	0.03		$	0.10		$	0.07		

(1) Other adjustments principally relate to the timing of certain expense and income accruals. Other diluted earnings (loss) per share attributable to UGI Corporation stockholders also includes the impact of rounding.

The adjustments reflected in the tables above did not affect cash flows from operating activities, investing activities or financing activities for any of the quarterly periods. In addition, the adjustments above relating to the Midstream & Marketing hedge accounting did not affect total stockholders’ equity as these adjustments resulted in changes to accumulated other comprehensive income and retained earnings in equal and offsetting amounts. In addition, the adjustments related to Midstream & Marketing hedge accounting had no effect on consolidated assets and liabilities. The Partnership customer credits and other adjustments did not have a material effect on the consolidated balance sheets for all periods presented.

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

(a)	Includes impairment loss on private equity partnership investment which increased operating loss by $6.3 and net loss attributable to UGI Corporation by $3.7 or $0.03 per share (see Note 2 ).	
		
(b)	Includes adjustment to foreign tax credit valuation allowance which increased net income by $5.5 or $0.05 per diluted share (see Note 7 ).	
		
(c)	Includes loss on extinguishment of Partnership long-term debt which decreased net income attributable to UGI Corporation by $2.2 or $0.02 per diluted share (see Note 6 ).	

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

Note 22 — Segment Information
Our operations comprise six reportable segments generally based upon products sold, geographic location and regulatory environment. Our reportable segments comprise: (1) AmeriGas Propane; (2) an international LPG segment comprising Antargaz; (3) an international LPG segment principally comprising Flaga and AvantiGas; (4) Gas Utility; (5) Energy Services; and (6) Electric Generation. We refer to both international segments together as “UGI International” and Energy Services and Electric Generation together as “Midstream & Marketing.”
AmeriGas Propane derives its revenues principally from the sale of propane and related equipment and supplies to retail customers in all 50 states. Antargaz’ revenues are derived principally from the distribution of LPG to retail customers in France and, to a much lesser extent, Belgium, the Netherlands and Luxembourg. Flaga & Other revenues are derived principally from the distribution of LPG to customers in northern, central and eastern Europe and the United Kingdom. Gas Utility’s revenues are derived principally from the sale and distribution of natural gas to customers in eastern, northeastern and central Pennsylvania. Energy Services revenues are derived from the sale of natural gas and, to a lesser extent, LPG, electricity and fuel oil as well as storage and other energy services to customers located primarily in the Mid-Atlantic region of the United States. Electric Generation revenues are derived principally from the sale of electricity through PJM, a regional electricity transmission organization in the eastern U.S.
The accounting policies of our reportable segments are the same as those described in Note 2 . We evaluate AmeriGas Propane’s performance principally based upon the Partnership’s earnings before interest expense, income taxes, depreciation and amortization (“Partnership EBITDA”). Although we use Partnership EBITDA to evaluate AmeriGas Propane’s profitability, it should not be considered as an alternative to net income (as an indicator of operating performance) or as an alternative to cash flow (as a measure of liquidity or ability to service debt obligations) and is not a measure of performance or financial condition under GAAP. Our definition of Partnership EBITDA may be different from that used by other companies. We evaluate the performance of our other reportable segments principally based upon their income before income taxes.
No single customer represents more than ten percent of our consolidated revenues. In addition, all of our reportable segments’ revenues, other than those of UGI International, are derived from sources within the United States, and all of our reportable segments’ long-lived assets, other than those of UGI International, are located in the United States.

																																				
 	 	 	 	 	 	 	 	 	Midstream & Marketing	 	UGI International	 	 	
 	Total	 	Elim-
inations	 	AmeriGas
Propane	 	Gas Utility	 	Energy Services	 	Electric Generation	 	Antargaz	 	Flaga &
Other	 	Corporate &
Other (b)	
2013	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Revenues	$	7,194.7		 	$	(223.8	)	(c)	$	3,168.8		 	$	839.0		 	$	969.4		 	$	71.4		 	$	1,322.6		 	$	856.6		 	$	190.7		
Cost of sales	$	4,324.4		 	$	(217.5	)	(c)	$	1,657.2		 	$	407.2		 	$	836.9		 	$	39.9		 	$	845.0		 	$	653.4		 	$	102.3		
Operating income	$	831.1		 	$	(1.1	)	 	$	394.4		 	$	196.5		 	$	82.5		 	$	7.5		 	$	111.4		 	$	35.6		 	$	4.3		
Loss from equity investees	$	(0.4	)	 	—		 	—		 	—		 	—		 	—		 	(0.4	)	 	—		 	—		
Interest expense	$	(240.3	)	 	—		 	(166.6	)	 	(37.4	)	 	(3.2	)	 	—		 	(25.3	)	 	(5.1	)	 	(2.7	)	
Income before income taxes	$	590.4		 	$	(1.1	)	 	$	227.8		 	$	159.1		 	$	79.3		 	$	7.5		 	$	85.7		 	$	30.5		 	$	1.6		
Net income attributable to UGI	$	278.1		 	$	(0.6	)	 	$	47.5		 	$	94.3		 	$	46.3		 	$	6.2		 	$	57.2		 	$	25.5		 	$	1.7		
Depreciation and amortization	$	363.1		 	$	—		 	$	205.9		 	$	51.7		 	$	7.6		 	$	10.0		 	$	57.6		 	$	24.1		 	$	6.2		
Noncontrolling interests’ net income (loss)	$	149.5		 	$	—		 	$	149.6		 	$	—		 	$	—		 	$	—		 	$	(0.2	)	 	$	0.1		 	$	—		
Partnership EBITDA (a)	 	 		 	$	596.5		 		 		 		 		 		 		
Total assets	$	10,008.8		 	$	(100.3	)	 	$	4,429.3		 	$	2,069.0		 	$	501.2		 	$	269.7		 	$	1,784.4		 	$	667.1		 	$	388.4		
Bank loans	$	227.9		 	$	—		 	$	116.9		 	$	17.5		 	$	87.0		 	$	—		 	$	—		 	$	6.5		 	$	—		
Capital expenditures	$	489.1		 	$	(1.1	)	 	$	111.1		 	$	144.4		 	$	133.8		 	$	22.6		 	$	53.4		 	$	17.4		 	$	7.5		
Investments in equity investees	$	0.3		 	$	—		 	$	—		 	$	—		 	$	—		 	$	—		 	$	—		 	$	0.3		 	$	—		
Goodwill	$	2,873.7		 	$	—		 	$	1,941.0		 	$	182.1		 	$	2.8		 	$	—		 	$	643.7		 	$	97.1		 	$	7.0		

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Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

	
																																				
 	 	 	 	 	 	 	 	 	Midstream & Marketing	 	UGI International	 	 	
 	Total	 	Elim-
inations	 	AmeriGas
Propane	 	Gas Utility	 	Energy Services	 	Electric Generation	 	Antargaz	 	Flaga &
Other	 	Corporate &
Other (b)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
2012	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Revenues	$	6,521.3		 	$	(178.8	)	(c)	$	2,921.5		 	$	785.4		 	$	816.4		 	$	43.9		 	$	1,121.4		 	$	824.7		 	$	186.8		
Cost of sales	$	4,099.1		 	$	(174.0	)	(c)	$	1,722.4		 	$	402.5		 	$	701.9		 	$	28.0		 	$	685.5		 	$	640.3		 	$	92.5		
Operating income (loss)	$	538.6		 	$	—		 	$	168.7		 	$	174.1		 	$	70.8		 	$	(6.5	)	 	$	88.3		 	$	23.6		 	$	19.6		
Loss from equity investees	$	(0.3	)	 	—		 	—		 	—		 	—		 	—		 	(0.3	)	 	—		 	—		
Loss on extinguishments of debt	$	(13.3	)	 	—		 	(13.3	)	 	—		 	—		 	—		 	—		 	—		 	—		
Interest expense	$	(220.4	)	 	—		 	(141.5	)	 	(40.1	)	 	(4.8	)	 	—		 	(26.3	)	 	(4.6	)	 	(3.1	)	
Income (loss) before income taxes	$	304.6		 	$	—		 	$	13.9		 	$	134.0		 	$	66.0		 	$	(6.5	)	 	$	61.7		 	$	19.0		 	$	16.5		
Net income (loss) attributable to UGI	$	210.2		 	$	—		 	$	15.4		 	$	81.6		 	$	38.7		 	$	(1.0	)	 	$	51.4		 	$	13.8		 	$	10.3		
Depreciation and amortization	$	315.0		 	$	—		 	$	168.1		 	$	49.0		 	$	3.7		 	$	9.0		 	$	57.1		 	$	22.1		 	$	6.0		
Noncontrolling interests’ net (loss) income	$	(12.5	)	 	$	—		 	$	(12.7	)	 	$	—		 	$	—		 	$	—		 	$	0.2		 	$	—		 	$	—		
Partnership EBITDA (a)	 	 		 	$	322.1		 		 		 		 		 		 		
Total assets	$	9,676.9		 	$	(104.1	)	 	$	4,533.8		 	$	2,045.5		 	$	368.5		 	$	258.2		 	$	1,686.5		 	$	531.8		 	$	356.7		
Bank loans	$	165.1		 	$	—		 	$	49.9		 	$	9.2		 	$	85.0		 	$	—		 	$	—		 	$	21.0		 	$	—		
Capital expenditures	$	343.2		 	$	—		 	$	103.1		 	$	109.0		 	$	36.0		 	$	24.4		 	$	47.3		 	$	16.9		 	$	6.5		
Investments in equity investees	$	0.3		 	$	—		 	$	—		 	$	—		 	$	—		 	$	—		 	$	—		 	$	0.3		 	$	—		
Goodwill	$	2,818.3		 	$	—		 	$	1,919.2		 	$	182.1		 	$	2.8		 	$	—		 	$	612.0		 	$	95.2		 	$	7.0		
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
2011	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Revenues	$	6,090.9		 	$	(233.0	)	(c)	$	2,538.2		 	$	1,026.4		 	$	1,023.8		 	$	48.6		 	$	1,050.6		 	$	438.1		 	$	198.2		
Cost of sales	$	3,982.7		 	$	(228.6	)	(c)	$	1,605.4		 	$	610.6		 	$	904.5		 	$	30.4		 	$	649.8		 	$	321.0		 	$	89.6		
Operating income (loss)	$	642.4		 	$	—		 	$	241.6		 	$	199.6		 	$	81.9		 	$	(1.1	)	 	$	89.2		 	$	(3.1	)	 	$	34.3		
Loss from equity investees	$	(0.9	)	 	—		 	—		 	—		 	—		 	—		 	(0.9	)	 	—		 	—		
Loss on extinguishments of debt	$	(38.1	)	 	—		 	(38.1	)	 	—		 	—		 	—		 	—		 	—		 	—		
Interest expense	$	(138.0	)	 	—		 	(63.5	)	 	(40.4	)	 	(2.0	)	 	(0.7	)	 	(25.5	)	 	(2.7	)	 	(3.2	)	
Income (loss) before income taxes	$	465.4		 	$	—		 	$	140.0		 	$	159.2		 	$	79.9		 	$	(1.8	)	 	$	62.8		 	$	(5.8	)	 	$	31.1		
Net income attributable to UGI	$	245.4		 	$	—		 	$	39.5		 	$	99.3		 	$	47.1		 	$	0.9		 	$	44.2		 	$	(3.2	)	 	$	17.6		
Depreciation and amortization	$	227.7		 	$	—		 	$	94.5		 	$	48.4		 	$	2.4		 	$	5.6		 	$	52.1		 	$	18.5		 	$	6.2		
Noncontrolling interests’ net income	$	74.6		 	$	—		 	$	74.3		 	$	—		 	$	—		 	$	—		 	$	0.3		 	$	—		 	$	—		
Partnership EBITDA (a)	 	 		 	$	295.6		 		 		 		 		 		 		
Total assets	$	6,660.9		 	$	(93.3	)	 	$	1,798.0		 	$	2,028.7		 	$	338.2		 	$	242.5		 	$	1,636.6		 	$	428.8		 	$	281.4		
Bank loans	$	138.7		 	$	—		 	$	95.5		 	$	—		 	$	24.3		 	$	—		 	$	—		 	$	18.9		 	$	—		
Capital expenditures	$	355.6		 	$	—		 	$	77.2		 	$	91.3		 	$	63.1		 	$	49.7		 	$	48.9		 	$	16.5		 	$	8.9		
Investments in equity investees	$	0.3		 	$	—		 	$	—		 	$	—		 	$	—		 	$	—		 	$	—		 	$	0.3		 	$	—		
Goodwill	$	1,562.2		 	$	—		 	$	696.3		 	$	182.1		 	$	2.8		 	$	—		 	$	591.8		 	$	82.2		 	$	7.0		

F-68

Table of Contents
UGI Corporation and Subsidiaries
Notes to Consolidated Financial Statements
(Millions of dollars and euros, except per share amounts and where indicated otherwise)

(a)	The following table provides a reconciliation of Partnership EBITDA to AmeriGas Propane operating income:	

													
Year ended September 30,	 	2013	 	2012	 	2011	
Partnership EBITDA	 	$	596.5		 	$	322.1		 	$	295.6		
Depreciation and amortization	 	(205.9	)	 	(168.1	)	 	(94.5	)	
Loss on extinguishments of debt	 	—		 	13.3		 	38.1		
Noncontrolling interests (i)	 	3.8		 	1.4		 	2.4		
Operating income	 	$	394.4		 	$	168.7		 	$	241.6		
		
(i)	Principally represents the General Partner’s 1.01% interest in AmeriGas OLP.	
		
(b)	Corporate & Other results principally comprise (1) Electric Utility, (2) Enterprises’ heating, ventilation, air-conditioning, refrigeration and electrical contracting businesses (“HVAC”), (3) changes in the fair values of Midstream & Marketing’s unsettled commodity derivative instruments and gains and losses on settled commodity derivative instruments not associated with current period transactions, (4) net expenses of UGI’s captive general liability insurance company, and (5) UGI Corporation’s unallocated corporate and general expenses and interest income. Corporate & Other assets principally comprise cash, short-term investments, the assets of Electric Utility and HVAC, and an intercompany loan. The intercompany loan and associated interest is removed in the segment presentation.	
		
(c)	Represents the elimination of intersegment transactions principally among Midstream & Marketing, Gas Utility and AmeriGas Propane.	

F-69

Table of Contents

UGI CORPORATION AND SUBSIDIARIES
SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)

BALANCE SHEETS
(Millions of dollars)

	
								
 	September 30,	
 	2013	 	2012(a)	
ASSETS	 	 	 	
Current assets:	 	 	 	
Cash and cash equivalents	$	0.9		 	$	1.9		
Accounts and notes receivable	2.9		 	4.0		
Deferred income taxes	0.4		 	0.4		
Prepaid expenses and other current assets	0.3		 	0.3		
Total current assets	4.5		 	6.6		
Investments in subsidiaries	2,488.7		 	2,241.1		
Other assets	49.9		 	28.3		
Total assets	$	2,543.1		 	$	2,276.0		
 	 	 	 	
LIABILITIES AND COMMON STOCKHOLDERS’ EQUITY	 	 	 	
 	 	 	 	
Current liabilities:	 	 	 	
Accounts and notes payable	$	11.0		 	$	11.1		
Derivative financial instruments	—		 	—		
Accrued liabilities	3.9		 	2.4		
Total current liabilities	14.9		 	13.5		
Noncurrent liabilities	35.7		 	32.7		
Commitments and contingencies (Note 1)		 		
Common stockholders’ equity:	 	 	 	
Common Stock, without par value (authorized - 300,000,000 shares; issued - 115,783,794 and 115,624,594 shares, respectively)	1,208.1		 	1,157.7		
Retained earnings	1,308.3		 	1,156.0		
Accumulated other comprehensive income (loss)	8.4		 	(55.2	)	
Treasury stock, at cost	(32.3	)	 	(28.7	)	
Total common stockholders’ equity	2,492.5		 	2,229.8		
Total liabilities and common stockholders’ equity	$	2,543.1		 	$	2,276.0		

(a) Investments in subsidiaries and common stockholder’s equity have been revised to reflect the effects of corrections to consolidated financial statements (see Note 3 to Consolidated Financial Statements).

Note 1 — Commitments and Contingencies:
In addition to the guarantees of Flaga’s and Antargaz’ debt as described in Note 6 to Consolidated Financial Statements, at September 30, 2013 , UGI Corporation had agreed to indemnify the issuers of $52.5 of surety bonds issued on behalf of certain UGI subsidiaries. UGI Corporation is authorized to guarantee up to $425.0 of obligations to suppliers and customers of UGI Energy Services, Inc. and subsidiaries of which $368.6 of such obligations were outstanding as of September 30, 2013 . UGI Corporation has guaranteed the floating to fixed rate interest rate swaps at Flaga which obligations totaled $4.3 at September 30, 2013 .

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Table of Contents

UGI CORPORATION AND SUBSIDIARIES
SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)

STATEMENTS OF INCOME
(Millions of dollars, except per share amounts)

	
												
 	Year Ended
September 30,	
 	2013	 	2012(a)	 	2011(a)	
Revenues	$	—		 	$	—		 	$	—		
Costs and expenses:	 	 	 	 	 	
Operating and administrative expenses	36.9		 	27.8		 	31.0		
Other income, net (1)	(36.7	)	 	(28.1	)	 	(24.8	)	
 	0.2		 	(0.3	)	 	6.2		
Operating (loss) income	(0.2	)	 	0.3		 	(6.2	)	
Intercompany interest income	0.2		 	0.2		 	0.1		
Income (loss) before income taxes	—		 	0.5		 	(6.1	)	
Income tax expense (benefit) 	3.1		 	0.3		 	(1.1	)	
(Loss) income before equity in income of unconsolidated subsidiaries	(3.1	)	 	0.2		 	(5.0	)	
Equity in income of unconsolidated subsidiaries	281.2		 	210.0		 	250.4		
Net income	$	278.1		 	$	210.2		 	$	245.4		
Earnings per common share:	 	 	 	 	 	
Basic	$	2.44		 	$	1.87		 	$	2.20		
Diluted	$	2.41		 	$	1.85		 	$	2.17		
Average common shares outstanding (thousands):	 	 	 	 	 	
Basic	113,923		 	112,581		 	111,674		
Diluted	115,521		 	113,432		 	112,944		

(a) Equity in income of unconsolidated subsidiaries have been revised to reflect the effects of corrections to consolidated financial statements (see Note 3 to Consolidated Financial Statements).

(1)	UGI provides certain financial and administrative services to certain of its subsidiaries. UGI bills these subsidiaries monthly for all direct expenses incurred by UGI on behalf of its subsidiaries as well as allocated shares of indirect corporate expense incurred or paid with respect to services provided by UGI. The allocation of indirect UGI corporate expenses to certain of its subsidiaries utilizes a weighted, three-component formula comprising revenues, operating expenses, and net assets employed and considers the relative percentage of such items for each subsidiary to the total of such items for all UGI operating subsidiaries for which general and administrative services are provided. Management believes that this allocation method is reasonable and equitable to its subsidiaries. These billed expenses are classified as “Other income, net” in the Statements of Income above.	

S-2

Table of Contents

UGI CORPORATION AND SUBSIDIARIES
SCHEDULE I — CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)

STATEMENTS OF CASH FLOWS
(Millions of dollars)

	
												
 	Year Ended
September 30,	
 	2013	 	2012	 	2011	
NET CASH PROVIDED BY OPERATING ACTIVITIES (a)	$	139.4		 	$	158.3		 	$	201.6		
 	 	 	 	 	 	
CASH FLOWS FROM INVESTING ACTIVITIES:	 	 	 	 	 	
Net investments in unconsolidated subsidiaries	(59.1	)	 	(54.4	)	 	(119.4	)	
Net cash used by investing activities	(59.1	)	 	(54.4	)	 	(119.4	)	
 	 	 	 	 	 	
CASH FLOWS FROM FINANCING ACTIVITIES:	 	 	 	 	 	
Payment of dividends on Common Stock	(125.8	)	 	(119.1	)	 	(113.8	)	
Issuance of Common Stock	44.5		 	16.7		 	31.0		
Net cash used by financing activities	(81.3	)	 	(102.4	)	 	(82.8	)	
Cash and cash equivalents (decrease) increase	$	(1.0	)	 	$	1.5		 	$	(0.6	)	
Cash and cash equivalents:	 	 	 	 	 	
End of year	$	0.9		 	$	1.9		 	$	0.4		
Beginning of year	1.9		 	0.4		 	1.0		
(Decrease) increase	$	(1.0	)	 	$	1.5		 	$	(0.6	)	

(a)	Includes dividends received from unconsolidated subsidiaries of $155.2 , $156.0 and $188.9 , for the years ended September 30, 2013 , 2012 and 2011 , respectively.	

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Table of Contents

UGI CORPORATION AND SUBSIDIARIES
SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS
(Millions of dollars)

	
																	
 	Balance at
beginning
of year	 	Charged
(credited)
to costs and
expenses	 	Other	 	Balance at
end of
year	 	
Year Ended September 30, 2013	 	 	 	 	 	 	 	 	
Reserves deducted from assets in the consolidated balance sheet:	 	 	 	 	 	 	 	 	
Allowance for doubtful accounts	$	36.1		 	$	30.2		 	$	(26.8	)	(1)	$	39.5		 	
Other reserves:	 	 	 	 	 	 	 	 	
Deferred tax assets valuation allowance	$	77.0		 	$	(5.7	)	 	26.3		(2)	$	97.6		 	
 	 	 	 	 	 	 	 	 	
Year Ended September 30, 2012	 	 	 	 	 	 	 	 	
Reserves deducted from assets in the consolidated balance sheet:	 	 	 	 	 	 	 	 	
Allowance for doubtful accounts	$	36.8		 	$	26.5		 	$	(27.2	)	(1)	$	36.1		 	
Other reserves:	 	 	 	 	 	 	 	 	
Deferred tax assets valuation allowance	$	78.2		 	$	(4.0	)	 	2.8		(3)	$	77.0		 	
 	 	 	 	 	 	 	 	 	
Year Ended September 30, 2011	 	 	 	 	 	 	 	 	
Reserves deducted from assets in the consolidated balance sheet:	 	 	 	 	 	 	 	 	
Allowance for doubtful accounts	$	34.6		 	$	20.0		 	$	(17.8	)	(1)	$	36.8		 	
Other reserves:	 	 	 	 	 	 	 	 	
Deferred tax assets valuation allowance	$	74.7		 	$	3.5		 	$	—		 	$	78.2		 	

(1)	Uncollectible accounts written off, net of recoveries.	
		
(2)	Foreign tax credit valuation allowance adjustment.	
		
(3)	Acquisition.	

S-4

Table of Contents

EXHIBIT INDEX

	
		
Exhibit No.	Description	
10.2	UGI Corporation 2004 Omnibus Equity Compensation Plan Amended and Restated as of December 5, 2006 - Terms and Conditions as amended and restated effective November, 2012.	
 	 	
10.16	UGI Corporation 2004 Omnibus Equity Compensation Plan Nonqualified Stock Option Grant Letter for Mr. Kirk R. Oliver dated October 1, 2012.	
 	 	
10.17	UGI Corporation 2004 Omnibus Equity Compensation Plan Performance Unit Grant Letter for Mr. Kirk R. Oliver dated October 1, 2012.	
 	 	
10.34	UGI Corporation 2013 Omnibus Incentive Compensation Plan Nonqualified Stock Option Grant Letter for Mr. John L. Walsh dated April 1, 2013.	
 	 	
10.35	UGI Corporation 2013 Omnibus Incentive Compensation Plan Performance Unit Grant Letter for Mr. John L. Walsh dated April 1, 2013.	
 	 	
10.37	Description of oral compensation arrangements for Messrs. Walsh, Hall, and Oliver and Ms. Gaudiosi.	
 	 	
10.39	Summary of Director Compensation as of October 1, 2013.	
 	 	
10.72	Amendment No. 13, dated as of October 1, 2013, 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, Market Street Funding LLC, as issuer, and PNC Bank, National Association, as administrator.	
 	 	
10.73	Amendment No. 4 dated as of October 1, 2013 to Purchase and Sale Agreement dated as of November 30, 2001 by and between UGI Energy Services, LLC and Energy Services Funding Corporation.	
 	 	
10.74	Amendment No. 14, dated as of October 1, 2013, 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, Market Street Funding LLC, as issuer, and PNC Bank, National Association, as administrator.	
 	 	
21	Subsidiaries of the Registrant	
 	 	
23	Consent of PricewaterhouseCoopers 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, 2013 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, 2013 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, 2013, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002	
 	 	
101.INS	XBRL.Instance	
 	 	
101.SCH	XBRL Taxonomy Extension Schema	
 	 	
101.CAL	XBRL Taxonomy Extension Calculation Linkbase	
 	 	
101.DEF	XBRL Taxonomy Extension Definition Linkbase	
 	 	
101.LAB	XBRL Taxonomy Extension Labels Linkbase	
 	 	
101.PRE	XBRL Taxonomy Extension Presentation Linkbase	

EXHIBIT 10.2

UGI CORPORATION
2004 OMNIBUS EQUITY COMPENSATION PLAN
TERMS AND CONDITIONS
Effective November, 2012

UGI Corporation
2004 Omnibus Equity Compensation Plan
Terms and Conditions
Table of Contents
Stock Options, Performance Units and Stock Units for Employees

1.	Definitions 1	
		
2.	Options 2	
		
3.	Performance Units 3	
		
4.	Stock Units 5	
		
5.	Reduction of Responsibilities 7	
		
6.	Change of Control 7	
		
7.	French Employees 7	
		
8.	Section 409A. 7	
		
9.	Company Policies 7	

Stock Options and Stock Units for Non-Employee Directors

1 .	Definitions 8	
		
2.	Options 9	
		
3.	Award of Stock Units 10	
		
4.	Events Requiring Redemption of Stock Units 10	
		
5.	Company Policies 12	

Exhibit A - Change of Control with Respect to AmeriGas
Exhibit B - Change of Control with Respect to Utilities
Exhibit C - Non-Employee Director Grants

i

UGI Corporation
2004 Omnibus Equity Compensation Plan
Stock Options, Performance Units and Stock Units For Employees
Terms and Conditions
The following Terms and Conditions shall be used for purposes of administering Options, Performance Units and Stock Units granted to Employees under the Plan. The Committee has discretion to modify or deviate from the Terms and Conditions at any time, and in all events the specific terms of the Grant Letter shall control. The defined terms shall have the meanings given those terms in the Plan or in these Terms and Conditions, if not defined in the Plan.
1. DEFINITIONS
Whenever used in these Terms and Conditions for Employees, the following terms will have the meanings set forth below:
(a)      “Account” means a bookkeeping account established on the records of the Company to record Performance Units, Stock Units and Dividend Equivalents credited under the Plan.
(b)      “AmeriGas” means AmeriGas Propane, Inc.
(c)      “Code” means the Internal Revenue Code of 1986, as amended.
(d)      “Disabled” or “Disability” means a long-term disability as defined in the Company’s long-term disability plan applicable to the Participant.
(e)      “Employed by, or provide service to, the Company” shall mean employment or service as an Employee or a Non-Employee Director (so that, for purposes of satisfying conditions with respect to Grants, a Participant shall not be considered to have terminated employment or service until the Participant ceases to be an Employee and Non-Employee Director).
(f)      “Good Reason Termination” shall mean a termination of employment initiated by the Participant upon or after a Change of Control upon one or more of the following events:
(i)      a material diminution in the authority, duties or responsibilities held by the Participant immediately prior to the Change of Control;
(ii)      a material diminution in the Participant’s base salary as in effect immediately prior to the Change of Control; or

1

(iii)      a material change in the geographic location at which the Participant must perform services (which, for purposes of this Agreement, means the Participant is required to report, other than on a temporary basis (less than 12 months), to a location which is more than 50 miles from the participant’s principal place of business immediately before the Change of Control, without the Participant’s express written consent).
Notwithstanding the foregoing, the Participant shall be considered to have a Good Reason Termination only if the Participant provides written notice to the Company, specifying in reasonable detail the events or conditions upon which the Participant is basing such good Reason Termination and the Participant provides such notice within 90 days after the event that gives rise to the Good Reason Termination. Within 30 days after notice has been provided, the Company shall have the opportunity, but shall have no obligation, to cure such events or conditions that give rise to the Good Reason Termination. If the Company does not cure such events or conditions within the 30-day period, the Participant may terminate employment with the Company based on Good Reason Termination within 30 days after the expiration of the cure period.
Notwithstanding the foregoing, if the Participant has in effect a Change in Control Agreement with the Company, the term “Good Reason Termination” shall have the meaning given that term in the Change in Control Agreement.
(g)      “Retirement” means an Employee’s retirement under the Retirement Income Plan for Employees of UGI Utilities, Inc., for Employees covered by that Retirement Income Plan. “Retirement” for other Company Employees means termination of employment after attaining (i) age 55 with ten or more years of service with the Company or (ii) for grants made in November 2012 and thereafter, age 65 with five or more years of service with the Company.
(h)      “Severance Plan” means any severance plan maintained by the Company that is applicable to the Employee.
(i)      “Termination without Cause” means termination of employment for the convenience of the Company for any reason other than (i) misappropriation of funds, (ii) habitual insobriety or substance abuse, (iii) conviction of a crime involving moral turpitude, or (iv) gross negligence in the performance of duties, which gross negligence has had a material adverse effect on the business, operations, assets, properties or financial condition of the Company. The Committee may determine in its sole discretion whether, and under what circumstances, a Participant’s voluntary termination upon a significant reduction in the Participant’s duties and responsibilities will constitute a Termination without Cause for purposes of the Plan.
(j)      “Utilities” means UGI Utilities, Inc.
2.      Options
(a)      Grant of Options . The Committee will select the Employees who shall receive Options, and will determine the number of shares subject to each Option, the Option Price and the other terms of the Options. The terms of each Option shall be set forth in the Grant Letter.

2

Unless the Committee determines otherwise, no Dividend Equivalents will be granted with respect to Options.
(b)      Exercise and Vesting .
(i)      Except as otherwise specified by the Committee in the Grant Letter, each Option shall become exercisable in equal one-third installments on the first, second and third anniversaries of the Date of Grant. The Committee may accelerate the exercisability of any or all outstanding Options at any time for any reason. No Option will be exercisable on or after the tenth anniversary of the Date of Grant.
(ii)      Except as otherwise specified by the Committee, in the event that a Participant holding an Option ceases to be employed by, or provide service to, the Company, the Options held by such Participant will terminate on the date such Participant ceases such employment or service. However, if a Participant holding an Option ceases to be employed by, or provide service to, the Company by reason of (i) Termination without Cause, (ii) Retirement, (iii) Disability, or (iv) death, the Option held by the Participant will thereafter be exercisable pursuant to the following:
(A)      Termination Without Cause . If a Participant terminates employment or service on account of a Termination without Cause, the Option held by such Participant will thereafter be exercisable only with respect to that number of shares of Stock with respect to which the Option is already exercisable on the date such Participant’s employment or service terminates. Such Option will terminate upon the earlier of the expiration date of the Option or the expiration of the 13-month period commencing on the date the Participant ceases to be employed by, or provide service to, the Company.
(B)      Retirement . If a Participant ceases to be employed by, or provide service to, the Company on account of Retirement, the Option held by such Participant will thereafter become exercisable as if such Participant had continued to be employed by, or provide service to, the Company after the date of such Retirement. The Option shall terminate upon the expiration date of the Option. However, for all Options granted prior to July 26, 2008, and all Options granted to Participants who retire prior to July 26, 2011, the Option held by such Participant may be exercised at any time prior to the earlier of the expiration date of the Option or the expiration of the 36-month period following the Participant’s Retirement.
(C)      Disability . If a Participant ceases to be employed by, or provide service to, the Company by reason of Disability, the Option held by such Participant will thereafter become exercisable as if such Participant had continued to provide service to the Company for 36 months after the date of such termination of employment or service. The Option will terminate upon the earlier of the expiration date of the Option or the expiration of such 36-month period.
(D)      Death . In the event of the death of a Participant while employed by, or providing service to, the Company, the Option held by such Participant will be fully and immediately exercisable and may be exercised at any time prior to the earlier of the expiration

3

date of the Option or the expiration of the 12-month period following the Participant’s death. Death of a Participant after the Participant has ceased to be employed by, or provide service to, the Company will not affect the otherwise applicable period for vesting and exercise of the Option determined pursuant to subsections (A), (B) or (C) above. After a Participant’s death, the Participant’s Option may be exercised by the Participant’s estate.
(c)      Payment . An Option may be exercised, and the Option Price paid, in any method permitted by the Plan.
(d)      Change of Control.  Outstanding Options granted before November, 2012 shall become fully vested upon a Change of Control. Outstanding Options granted in November 2012 and thereafter shall vest upon Termination without Cause or Good Reason Termination upon, or during a specified period after, a Change of Control as described in the Grant Letter (“double trigger” vesting).
3.      Performance Units
(a)      Grant of Performance Units . The Committee will select the Employees who will receive Performance Units and will determine the number of shares subject to Performance Units and the terms of the Performance Units. Unless the Committee determines otherwise, Dividend Equivalents will be granted with respect to Performance Units. The Committee shall specify in the Grant Letter for Performance Units the terms and conditions of the Performance Units and the applicable restrictions and performance goals, including the objective goals, employment requirements, period during which the Performance Units shall be subject to restrictions and other conditions of the Grant.
(b)      Terms . The Committee will establish performance goals and terms for Performance Units in accordance with Section 13 of the Plan. The Committee will establish appropriate threshold, Target Amount and maximum payments to be made with respect to the Performance Units.
(c)      Requirements of Employment or Service . If the Participant ceases to be employed by, or provide service to, the Company during the applicable period specified in the Grant Letter, all of the Participant’s the Performance Units will terminate. However, if a Participant holding Performance Units ceases to be employed by, or provide service to, the Company by reason of Retirement, Disability, or death, the restrictions on Performance Units held by the Participant will lapse pursuant to the following:
(i)      If a Participant terminates employment or service on account of Retirement, Disability or death, the restrictions on a pro-rata portion of the Participant’s outstanding Performance Units will lapse at the end of the restriction period set forth in the Grant Letter, if the performance goals and all requirements of the Grant Letter (other than continued employment) are met. The prorated portion will be determined, for each Performance Unit, as the amount that would otherwise be paid according to the terms of the Performance Unit, based on achievement of the performance goals, multiplied by a fraction, the numerator of which is the number of years during the restriction period in which the Participant has been employed by, or

4

provided service to, the Company and the denominator of which is the number of years in the entire restriction period applicable to such Performance Units. For purposes of the proration calculation, the year in which the Participant’s Retirement, Disability, or death occurs will be counted as a full year.
(ii)      In the event of Retirement, Disability or death, the prorated portion of the Performance Units shall be paid at the date specified for payment of the Performance Units in the Grant Letter, or at an earlier date determined by the Committee in the Grant Letter.
(d)      Payment of Performance Units. If the Committee determines that the conditions to payment of the Performance Units have been met, the Company shall pay to the Participant, within 2½ months after the end of the restriction period, (i) shares of Stock or cash, or a combination of the two, as the Committee determines, equal to the amount to be paid according to achievement of the performance goals, up to the target award specified in the Participant’s Grant Letter and (ii) cash in an amount equal to the Fair Market Value of the shares of Stock underlying the Performance Units for any amounts payable in excess of the target amount specified by the Committee for the Performance Units.
(e)      Coordination with Severance Plan . Notwithstanding any other provisions of these Terms and Conditions, if a Participant receives severance benefits under a Severance Plan, the terms of which require that severance compensation payable under the Severance Plan be reduced by benefits payable under this Plan, any amount payable to the Participant under Performance Units and Dividend Equivalents after the Participant’s termination of employment shall be reduced by the amount of severance compensation paid to the Participant under the Severance Plan, as required by, and according to the terms of, the Severance Plan, if permitted by section 409A of the Code.
(f)      Dividend Equivalents with Respect to Performance Units . Dividend Equivalents, if granted, shall accrue with respect to Performance Units and shall be payable subject to the same performance goals and terms as the Performance Units to which they relate. Dividend Equivalents shall be credited with respect to Performance Units from the Date of Grant until the date on which the Performance Units are paid. If and to the extent that the underlying Performance Units are forfeited, all related Dividend Equivalents shall also be forfeited.
(g)      Accounts.  While Performance Units are outstanding, the Company will keep records in an Account for each Participant who holds Performance Units. On each payment date for a dividend paid by UGI on its Stock, the Company shall credit to the Participant’s Account an amount equal to the Dividend Equivalents associated with the Performance Units held by the Participant on the record date for the dividend. No interest will be credited to any such Account. Notwithstanding the foregoing, a Participant may not accrue Dividend Equivalents in excess of $750,000 during any calendar year.
(h)      Payment of Dividend Equivalents. Dividend Equivalents will be paid after the performance goals and other requirements specified in the Grant Letter have been met, at the same time as the underlying Performance Units are paid or as otherwise determined by the

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Committee. Dividend Equivalents will be paid in cash, Stock or a combination of the two, as the Committee determines.
(i)      Change of Control.  Upon a Change of Control, outstanding Performance Units granted before November 2012, and related Dividend Equivalents shall be paid in cash in an amount equal to the greater of (i) the target amount or (ii) the amount earned as of the date of the Change of Control based on the Company’s achievement of the performance goals as of the Change of Control, as determined by the Committee. If a former Participant is entitled to receive a prorated award for the restriction period pursuant to Section 3(c) above, the award will be the prorated portion of the amount described in the preceding sentence. The Performance Units and Dividend Equivalents shall be paid on the closing date of the Change of Control. Outstanding Performance Units granted in November 2012 and thereafter, and related Dividend Equivalents, shall vest upon Termination without Cause or Good Reason Termination upon, or during a specified period after, a Change of Control as described in the Grant Letter (“double trigger” vesting).
4.      Stock Units
(a)      Grants of Stock Units . The Committee will select the Employees who will receive Stock Units and will determine the number of shares subject to Stock Units and the terms of the Stock Units. Unless the Committee determines otherwise, Dividend Equivalents will be granted with respect to Stock Units. The Committee shall specify in the Participant’s Grant Letter the terms and conditions of the Stock Units and the applicable restrictions, including the period during which the Stock Units will be subject to vesting requirements, if any, and other conditions of the Grant.
(b)      Vesting of Stock Units . Stock Units will vest on such terms as the Committee determines and specifies in the Grant Letter. If the Participant ceases to be employed by, or provide service to the Company, any unvested Stock Units will immediately terminate, except as provided below. The Committee may authorize payment of Stock Units on a prorated or other basis in such circumstances as the Committee deems appropriate, including in the event that a Participant ceases to be employed by, or provide service to, the Company, on account of Retirement, Disability or death.
(c)      Payment of Stock Units.  A Participant will receive payment with respect to Stock Units as the Stock Units vest, within 30 business days after the vesting date. Payment shall be made in Stock, in cash or in a combination of the two, as determined by the Committee.
(d)      Coordination with Severance Plan . Notwithstanding any other provisions of these Terms and Conditions, if a Participant receives severance benefits under a Severance Plan, the terms of which require that severance compensation payable under the Severance Plan be reduced by benefits payable under this Plan, any amount payable to the Participant under Stock Units and Dividend Equivalents after the Participant’s termination of employment shall be reduced by the amount of severance compensation paid to the Participant under the Severance Plan, as required by, and according to the terms of, the Severance Plan, if permitted by section 409A of the Code.

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(e)      Dividend Equivalents with Respect to Stock Units . Dividend Equivalents, if granted, shall accrue with respect to Stock Units and shall be payable subject to the same terms as the Stock Units to which they relate. Dividend Equivalents shall be credited with respect to Stock Units from the Date of Grant until the date on which the Stock Units are paid. If the underlying Stock Units are forfeited, all related Dividend Equivalents shall also be forfeited.
(f)      Accounts.  While Stock Units are outstanding, the Company will keep records in an Account for each Participant who holds Stock Units. On each payment date for a dividend paid by UGI on its Stock, the Company shall credit to the Participant’s Account an amount equal to the Dividend Equivalents associated with the Stock Units held by the Participant on the record date for the dividend. No interest will be credited to any such Account. Notwithstanding the foregoing, a Participant may not accrue Dividend Equivalents in excess of $750,000 during any calendar year.
(g)      Payment of Dividend Equivalents.  Dividend Equivalents will be paid after the vesting and other requirements specified in the Grant Letter have been met, at the same time as the underlying Stock Units are paid or as otherwise determined by the Committee. Dividend Equivalents will be paid in cash, Stock or a combination of the two, as the Committee determines.
(h)      Change of Control.  Outstanding Stock Units granted before November, 2012 shall become fully vested upon a Change of Control and shall be paid in cash on the closing date of the Change of Control, and related Dividend Equivalents shall become fully vested and paid when the underlying Stock Units are paid. Notwithstanding the foregoing, if the Stock Units are subject to section 409A of the Code, the Stock Units shall be paid upon a Change of Control only if the transaction constituting a Change of Control is also a change in control event under section 409A of the Code (“409A Change in Control Event”). If the transaction constituting a Change of Control does not constitute a 409A Change in Control Event, the outstanding Stock Units will vest upon the Change of Control, and any outstanding Stock Units that are subject to section 409A will be paid in cash (based on the value of the Stock Units on the payment date as determined by the Committee) within 30 days after the first to occur of (i) the vesting date set forth in the Participant’s Grant Letter or (ii) the Participant’s termination of employment or service (subject to the section 409A six-month delay, if applicable). If payment is delayed after the Change of Control, the Committee may provide for the Stock Units to be valued as of the date of the Change of Control and interest to be credited on the amount so determined at a market rate for the period between the Change of Control date and the payment date. Outstanding Stock Units granted in November 2012 and thereafter, and related Dividend Equivalents, shall vest upon Termination without Cause or Good Reason Termination upon, or during a specified period after, a Change of Control as described in the Grant Letter (“double trigger” vesting).

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5.      Reduction of Responsibilities
The Committee shall have discretion to adjust a Participant’s Options that are not yet exercisable and a Participant’s outstanding Performance Units and Stock Units, if the Participant’s authority, duties or responsibilities are significantly reduced.
6.      Change of Control
(a)      Authorization. In the event of a Change of Control, the provisions of Sections 2(d), 3(i) and 4(h) above shall apply to Options, Performance Units and Stock Units, and the Committee may take such other actions with respect to outstanding Options as it deems appropriate pursuant to the Plan. The term “Change of Control” shall mean a Change of Control of UGI, as defined in the Plan, except as provided below.
(b)      AmeriGas Employees . For Participants who are employees of AmeriGas, or a subsidiary of AmeriGas, the term “Change of Control” shall mean (i) a Change of Control of UGI, as defined in the Plan, or (ii) one of the events set forth in Exhibit A with respect to AmeriGas.
(c)      Utilities Employees . For Participants who are employees of Utilities or a subsidiary of Utilities, the term “Change of Control” shall mean (i) a Change of Control of UGI as defined in the Plan, or (ii) one of the events set forth on Exhibit B with respect to Utilities.
(d)      Other Subsidiaries . The Committee may determine in a Grant Letter that a sale or other transaction with respect to any other Company subsidiary shall be considered a Change of Control for purposes of the Plan, for Participants who are employees of that subsidiary.
7.      French Employees . The terms of the Sub-Plan for French Employees shall apply to the grant of Options to Employees who are, or may become, subject to taxation on compensation in France.
8.      Section 409A . Performance Units, Stock Units and Dividend Equivalents shall meet the requirements of section 409A of the Code or an exemption from such requirements.
9.      Company Policies . All Shares issued pursuant to an Option, Performance Unit or Stock Unit shall be subject to the UGI Corporation Stock Ownership Policy, if applicable. All Options, Performance Units and Stock Units shall be subject to any applicable clawback and other policies implemented by the Board of Directors of UGI, as in effect from time to time.

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UGI Corporation
2004 Omnibus Equity Compensation Plan
Stock Options and Stock Units For Non-Employee Directors
Terms and Conditions
The following Terms and Conditions shall be used for purposes of administering Options and Stock Units granted to Non-Employee Directors under the Plan. The Terms and Conditions were amended and restated to allow Non-Employee Directors to defer their Stock Units to the UGI Corporation 2009 Deferral Plan, effective as of January 1, 2009 and are now further amended. The Committee has discretion to modify or deviate from the Terms and Conditions at any time, and in all events the specific terms of the Grant Letter shall control. The defined terms shall have the meanings given those terms in the Plan or in these Terms and Conditions, if not defined in the Plan.
1.      Definitions
Whenever used in these Terms and Conditions for Non-Employee Directors, the following terms will have the meanings set forth below:
(k)      “ Account ” means the Company’s record established pursuant to Section 3, which reflects the number of Stock Units and the amount of Dividend Equivalents standing to the credit of a Participant under the Plan.
(l)      “Beneficiary” means the person designated by a Non-Employee Director to receive any benefits payable after the Non-Employee Director’s death. The Company shall provide a form for this purpose. In the event a Non-Employee Director has not filed a Beneficiary designation with the Company or none of the designated Beneficiaries are living at the date of the Non-Employee Director’s death, the Beneficiary shall be the Non-Employee Director’s estate.
(m)      “Committee” means, for purposes of Grants to Non-Employee Directors, the Board or its delegate.
(n)      “Deferral Plan” means the UGI Corporation 2009 Deferral Plan, as amended from time to time.
(o)      “ Plan Year ” means the calendar year.
(p)      “Retirement” means a Non-Employee Director’s Separation from Service after (1) attaining age 65 with five or more years of service with the Company, or (2) ten or more years of service with the Company.

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(q)      “ Separates from Service ” means the Non-Employee Director's termination of service as a Non-Employee Director and as an Employee of the Company for any reason other than death.
(r)      “ Unit Value ” means, at any time, the value of each Unit issued under the Plan, which value shall be equal to the Fair Market Value of a share of Stock on such date.
2.      Options
(e)      Grant of Options . The Board shall grant Options annually to Non-Employee Directors in the amounts set forth on the attached Exhibit C, on the fifth business day of each Plan Year. The Option Price will equal the Fair Market Value on the Date of Grant.
(f)      Exercise and Vesting . Except as otherwise specified in the Grant Letter, an Option will be fully and immediately exercisable on the Date of Grant. In the event that any Options are not by their terms immediately exercisable, the Committee may accelerate the exercisability of any or all outstanding Options at any time for any reason. No Option will be exercisable on or after the tenth anniversary of the Date of Grant.
(g)      S eparation from Service . Except as otherwise specified by the Committee, each Option, to the extent that it has not previously been exercised, will terminate when the Participant holding such Option Separates from Service. However, if a Participant holding an Option Separates from Service by reason of retirement, disability, or death, the Option held by any such Participant will be fully and immediately exercisable and will thereafter be exercisable pursuant to the following:
(A)      Retirement . If a Participant Separates from Service on account of Retirement, the Option held by such Participant will continue in effect and terminate upon the expiration date of the Option. However, for all Options granted prior to January 1, 2009, and all Options granted to Participants who retire prior to September 27, 2011, the Option held by such Participant may be exercised at any time prior to the earlier of the expiration date of the Option or the expiration of the 36-month period following the Participant’s Retirement.
(2)      Disability . The Committee shall have sole discretion to determine whether or not a Participant is “disabled.” If a Participant is determined to be "disabled" by the Committee, the Option held by such Participant may be exercised at any time prior to the earlier of the expiration date of the Option or the expiration of the 36-month period following the Participant's Separation from Service on account of disability.
(3)      Death . In the event of the death of a Participant while serving as a Non-Employee Director or Employee of the Company, the Option held by such Participant may be exercised at any time prior to the earlier of the expiration date of the Option or the expiration of the 12-month period following the Participant's death. Such Option may be exercised by the Participant’s estate.

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(h)      Payment . An Option may be exercised, and the Option Price paid, in any method permitted by the Plan.
3.      Award of Stock Units
(j)      Annual Award of Stock Units . On the fifth business day of each Plan Year, each Non-Employee Director shall receive an award of Stock Units in the amount set forth on the attached Exhibit C . Such Stock Units shall be credited to each Participant's Account as specified in Section 3(c) below. Any Non-Employee Director who becomes a Non-Employee Director after the fifth business day of the Plan Year shall receive, on the date such individual becomes a Non-Employee Director, a pro-rata share of the annual award of Stock Units determined based on the number of calendar quarters during the Plan Year that he or she is expected to serve as a Non-Employee Director. A Non-Employee Director will be deemed to serve for the entire quarter if he or she is a Non-Employee Director on at least one day of the quarter.
(k)      Dividend Equivalents
(i)      Dividend Equivalent to be Credited.  From the Date of Grant of each Stock Unit until the Participant’s Account has been fully distributed, on each payment date for a dividend paid by UGI on its Stock, the Company shall credit to each Participant’s Account an amount equal to the Dividend Equivalent associated with the Stock Units held by the Participant on the record date for the dividend.
(ii)      Conversion to Stock Units. On the last day of each Plan Year, the amount of the Dividend Equivalents credited to the Participant’s Account during that Plan Year shall be converted to a number of Stock Units, based on the Unit Value on the last day of the Plan Year. Notwithstanding the foregoing, in the event of a Change of Control or in the event the Non-Employee Director dies or Separates from Service prior to the last day of the Plan Year, as soon as practicable following such event and in no event later than the date on which Stock Units are redeemed in accordance with Section 4, the Company shall convert the amount of the Dividend Equivalents credited to the Participant’s Account as of the date of the Change of Control, death or Separation from Service (the “Conversion Date”) to a number of Stock Units based on the Unit Value on the Conversion Date.
(l)      Accounts.  The Company shall keep records to reflect the number of Stock Units and Dividend Equivalents credited to each Non-Employee Director hereunder. Fractional Stock Units shall accumulate in the Participant’s Account and shall be added to fractional Stock Units held in such Account to create whole Stock Units.
(m)      Directors’ Equity Compensation Plan . On and after the Effective Date, Dividend Equivalents shall be credited and paid on all Stock Units that are outstanding under the Directors’ Equity Plan on the Effective Date, on the same terms as described in this Section 3 and Section 4 below. All Units outstanding under the Directors’ Equity Plan on the Effective Date, including accrued Dividend Equivalents, shall be paid according to Section 4 below.

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4.      Events Requiring Redemption of Stock Units
The Company shall redeem Stock Units credited to a Participant's Account only at the times and in the manner prescribed by the terms of this Section 4
(a)     Death.  In the event a Participant dies, the Company shall redeem all of the Stock Units then credited to the Participant’s Account as of the date of the Participant’s death, based on the Unit Value of the Stock Units credited to the Participants’ Account as of the date of the Participant’s death. An amount equal to 65% of the aggregate Unit Value will be paid in the form of whole Shares (with fractional Shares paid in cash), and the remaining 35% of the aggregate Unit Value will be paid in cash. The redemption amount shall be paid to the Participant’s estate within 60 business days after the Participant’s death.
(b)     Separation from Service.  In the event a Participant Separates from Service, the Company shall redeem all of the Stock Units then credited to the Participant's Account as of the date of such Separation from Service, based on the Unit Value of the Stock Units credited to the Participant’s Account as of the date of the Participant’s Separation from Service. An amount equal to 65% of the aggregate Unit Value will be paid in the form of whole Shares (with fractional Shares paid in cash), and the remaining 35% of the aggregate Unit Value will be paid in cash, within 30 business days after the date of the Participant’s Separation from Service.
(c)     Change of Control.  In the event of a Change of Control, the Company shall redeem all the Stock Units then credited to the Participant’s Account. The redemption amount shall be paid in cash on the closing date of the Change of Control (except as described below). The amount paid shall equal the product of the number of Stock Units being redeemed multiplied by the Unit Value at the date of the Change of Control. However, in the event that the transaction constituting a Change of Control is not a change in control event under section 409A of the Code, the Participant’s Stock Units shall be redeemed and paid in cash upon Separation from Service or death on the applicable date described in subsection (a) or (b) above (based on the aggregate Unit Value on the date of Separation from Service or death as determined by the Committee), instead of upon the Change of Control pursuant to this subsection (c). If payment is delayed after the Change of Control, pursuant to the preceding sentence, the Committee may provide for the Stock Units to be valued as of the date of the Change of Control and interest to be credited on the amount so determined at a market rate for the period between the Change of Control date and the payment date.
(d)     Effect on Outstanding Stock Units and Dividend Equivalents.  The provisions of this Section 4 relating to the medium of payment ( i.e. , payment in cash or in a combination of cash and Shares) shall apply to all outstanding Stock Units and Dividend Equivalents.
(e)     Section 409A.  Stock Units and Dividend Equivalents shall meet the requirements of section 409A of the Internal Revenue Code or an exemption from such requirements. All Stock Units and Dividend Equivalents that were earned and vested as of December 31, 2004 shall be administered in accordance with their terms as in effect on October 3, 2004, except for changes that are not considered “material modifications” under the regulations issued under section 409A of the Internal Revenue Code.

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(f)     Deferral Elections . Notwithstanding the foregoing, a Non-Employee Director may make a one-time, irrevocable election to elect to have all of the Non-Employee Director’s Stock Units credited to the Non-Employee Director’s account under the Deferral Plan on the date of the Non-Employee Director’s Separation from Service, in lieu of the redemption and payments described in subsections (a), (b) and (c). If the Non-Employee Director makes a deferral election, the Non-Employee Director’s Stock Units will be credited to the Non-Employee Director’s account under the Deferral Plan at Separation from Service and the amount credited to the Deferral Plan shall be distributed in accordance with the provisions of the Deferral Plan. If the Non-Employee Director makes a deferral election and a Change of Control occurs: (i) subsection (c) above shall apply if the Change of Control occurs before the Non-Employee Director’s Separation from Service and (ii) the terms of the Deferral Plan shall apply if the Change of Control occurs after or simultaneously with the Non-Employee Director’s Separation from Service. An election under this subsection (f) shall be made in writing, on a form and at a time prescribed by the Committee and shall be irrevocable upon submission to the Corporate Secretary.
5.      Company Policies . All Shares issued pursuant to an Option or Stock Unit shall be subject to any applicable policies implemented by the Board of Directors of UGI, as in effect from time to time.

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Exhibit A 

Change of Control with Respect to AmeriGas
For Participants who are employees of AmeriGas, or a subsidiary of AmeriGas, the term “Change of Control” shall include the events set forth in this Exhibit A with respect to AmeriGas, and the defined terms used in this Exhibit A shall have the following meanings:
1.    “Change of Control” shall include any of the following events:
(A)      Completion by AmeriGas, the Public Partnership or the Operating Partnership of a reorganization, merger or consolidation (a "Propane Business Combination"), in each case, with respect to which all or substantially all of the individuals and entities who were the respective Beneficial Owners of the AmeriGas voting securities or of the outstanding units of AmeriGas Partners, L.P. ("Outstanding Units") immediately prior to such Propane Business Combination do not, following such Propane Business Combination, Beneficially Own, directly or indirectly, (a) if the entity resulting from such Propane Business Combination is a corporation, more than fifty percent (50%) of, respectively, the then outstanding shares of common stock and the combined voting power of the then outstanding voting securities entitled to vote generally in the election of directors, as the case may be, of such corporation in substantially the same proportion as their ownership immediately prior to such Combination of the AmeriGas’ voting securities or the Outstanding Units, as the case may be, or, (b) if the entity resulting from such Propane Business Combination is a partnership, more than fifty percent (50%) of the then outstanding common units of such partnership in substantially the same proportion as their ownership immediately prior to such Propane Business Combination of AmeriGas’ voting securities or the Outstanding Units, as the case may be; or
(B)      (a) Completion of a complete liquidation or dissolution of AmeriGas, the Public Partnership or the Operating Partnership or (b) sale or other disposition of all or substantially all of the assets of AmeriGas, the Public Partnership or the Operating Partnership other than to an entity with respect to which, following such sale or disposition, (I) if such entity is a corporation, more than fifty percent (50%) of, respectively, the then outstanding shares of common stock and the combined voting power of the then outstanding voting securities entitled to vote generally in the election of directors is then owned beneficially, directly or indirectly, by all or substantially all of the individuals and entities who were the Beneficial Owners, respectively, of AmeriGas’ voting securities or of the Outstanding Units, as the case may be, immediately prior to such sale or disposition in substantially the same proportion as their ownership of AmeriGas’ voting securities or of the Outstanding Units, as the case may be, immediately prior to such sale or disposition, or, (II) if such entity is a partnership, more than fifty percent (50%) of the then outstanding common units is then owned beneficially, directly or indirectly, by all or substantially all of the individuals and entities who were the Beneficial Owners, respectively, of AmeriGas’ voting securities or of the Outstanding Units, as the case may be, immediately prior to such sale or disposition in substantially the same proportion as their

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ownership of AmeriGas’ voting securities or of the Outstanding Units immediately prior to such sale or disposition; or
(C)      UGI and the UGI Subsidiaries fail to own more than fifty percent (50%) of the then outstanding general partnership interests of the Public Partnership or the Operating Partnership; or
(D)      UGI and the UGI Subsidiaries fail to own more than fifty percent (50%) of the then outstanding shares of common stock of AmeriGas or more than fifty percent (50%) of the combined voting power of the then outstanding voting securities of AmeriGas entitled to vote generally in the election of directors; or
(E)      AmeriGas is removed as the general partner of the Public Partnership by vote of the limited partners of the Public Partnership, or is removed as the general partner of the Public Partnership or the Operating Partnership as a result of judicial or administrative proceedings involving AmeriGas, the Public Partnership or the Operating Partnership.
2.    “Affiliate” and “Associate” shall have the respective meanings ascribed to such terms in Rule 12b-2 of the General Rules and Regulations under the Exchange Act.
3.    A Person shall be deemed the “Beneficial Owner” of any securities: (i) that such Person or any of such Person’s Affiliates or Associates, directly or indirectly, has the right to acquire (whether such right is exercisable immediately or only after the passage of time) pursuant to any agreement, arrangement or understanding (whether or not in writing) or upon the exercise of conversion rights, exchange rights, rights, warrants or options, or otherwise; provided , however , that a person shall not be deemed the “Beneficial Owner” of securities tendered pursuant to a tender or exchange offer made by such Person or any of such person’s Affiliates or Associates until such tendered securities are accepted for payment, purchase or exchange; (ii) that such Person or any of such Person’s Affiliates or Associates, directly or indirectly, has the right to vote or dispose of or has “beneficial ownership” of (as determined pursuant to Rule 13d-3 of the General Rules and Regulations under the Exchange Act), including without limitation pursuant to any agreement, arrangement or understanding, whether or not in writing; provided , however , that a Person shall not be deemed the “Beneficial Owner” of any security under this clause (ii) as a result of an oral or written agreement, arrangement or understanding to vote such security if such agreement, arrangement or understanding (A) arises solely from a revocable proxy given in response to a public proxy or consent solicitation made pursuant to, and in accordance with, the applicable provisions of the General Rules and Regulations under the Exchange Act, and (B) is not then reportable by such Person on Schedule 13D under the Exchange Act (or any comparable or successor report); or (iii) that are beneficially owned, directly or indirectly, by any other Person (or any Affiliate or Associate thereof) with which such Person (or any of such Person’s Affiliates or Associates) has any agreement, arrangement or understanding (whether or not in writing) for the purpose of acquiring, holding, voting (except pursuant to a revocable proxy as described in the proviso to clause (ii) above) or disposing of any securities; provided , however , that nothing in this Section 1(c) shall cause a Person engaged in business as an underwriter of securities to be the “Beneficial Owner” of any securities acquired through such Person’s

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participation in good faith in a firm commitment underwriting until the expiration of forty (40) days after the date of such acquisition.
4.    “Exchange Act” shall mean the Securities Exchange Act of 1934, as amended.
5.    “Operating Partnership” shall mean AmeriGas Propane, L.P.
6.    “Public Partnership” shall mean AmeriGas Partners, L.P.
7.    “Person” shall mean an individual or a corporation, partnership, trust, unincorporated organization, association, or other entity.
8.    “UGI Subsidiary” shall mean any corporation in which UGI directly or indirectly, owns at least a fifty percent (50%) interest or an unincorporated entity of which UGI, as applicable, directly or indirectly, owns at least fifty percent (50%) of the profits or capital interests.

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Exhibit B 

Change of Control with Respect to Utilities
For Participants who are employees of Utilities, or a subsidiary of Utilities, the term “Change of Control” shall include the events set forth in this Exhibit B with respect to Utilities, and the defined terms set forth used in this Exhibit B, if not defined in the Plan, shall have the following meanings:
1.    “Change of Control” shall include any of the following events:
(A)      UGI and the UGI Subsidiaries fail to own more than fifty percent (50%) of the then outstanding shares of common stock of Utilities or more than fifty percent (50%) of the combined voting power of the then outstanding voting securities of Utilities entitled to vote generally in the election of directors; or
(B)      Completion by Utilities of a reorganization, merger or consolidation (a "Business Combination"), in each case, with respect to which all or substantially all of the individuals and entities who were the respective Beneficial Owners of Utilities’ outstanding common stock and voting securities immediately prior to such Business Combination do not, following such Business Combination, Beneficially Own, directly or indirectly, more than 50% of, respectively, the then outstanding shares of common stock and the combined voting power of the then outstanding voting securities entitled to vote generally in the election of directors, as the case may be, of the corporation resulting from such Business Combination in substantially the same proportion as their ownership immediately prior to such Business Combination of Utilities’ outstanding common stock and voting securities, as the case may be; or
(C)      Completion of a complete liquidation or dissolution of the Utilities or sale or other disposition of all or substantially all of the assets of Utilities other than to a corporation with respect to which, following such sale or disposition, more than 50% of, respectively, the then outstanding shares of common stock and the combined voting power of the then outstanding voting securities entitled to vote generally in the election of directors is then owned beneficially, directly or indirectly, by all or substantially all of the individuals and entities who were the Beneficial Owners, respectively, of Utilities’ outstanding common stock and voting securities immediately prior to such sale or disposition in substantially the same proportion as their ownership of Utilities’ outstanding common stock and voting securities, as the case may be, immediately prior to such sale or disposition.
2.    “Affiliate” and “Associate” shall have the respective meanings ascribed to such terms in Rule 12b-2 of the General Rules and Regulations under the Exchange Act.
3.    A Person shall be deemed the “Beneficial Owner” of any securities: (i) that such Person or any of such Person’s Affiliates or Associates, directly or indirectly, has the right to acquire

17

(whether such right is exercisable immediately or only after the passage of time) pursuant to any agreement, arrangement or understanding (whether or not in writing) or upon the exercise of conversion rights, exchange rights, rights, warrants or options, or otherwise; provided , however , that a person shall not be deemed the “Beneficial Owner” of securities tendered pursuant to a tender or exchange offer made by such Person or any of such person’s Affiliates or Associates until such tendered securities are accepted for payment, purchase or exchange; (ii) that such Person or any of such Person’s Affiliates or Associates, directly or indirectly, has the right to vote or dispose of or has “beneficial ownership” of (as determined pursuant to Rule 13d-3 of the General Rules and Regulations under the Exchange Act), including without limitation pursuant to any agreement, arrangement or understanding, whether or not in writing; provided , however , that a Person shall not be deemed the “Beneficial Owner” of any security under this clause (ii) as a result of an oral or written agreement, arrangement or understanding to vote such security if such agreement, arrangement or understanding (A) arises solely from a revocable proxy given in response to a public proxy or consent solicitation made pursuant to, and in accordance with, the applicable provisions of the General Rules and Regulations under the Exchange Act, and (B) is not then reportable by such Person on Schedule 13D under the Exchange Act (or any comparable or successor report); or (iii) that are beneficially owned, directly or indirectly, by any other Person (or any Affiliate or Associate thereof) with which such Person (or any of such Person’s Affiliates or Associates) has any agreement, arrangement or understanding (whether or not in writing) for the purpose of acquiring, holding, voting (except pursuant to a revocable proxy as described in the proviso to clause (ii) above) or disposing of any securities; provided , however , that nothing in this Section 1(c) shall cause a Person engaged in business as an underwriter of securities to be the “Beneficial Owner” of any securities acquired through such Person’s participation in good faith in a firm commitment underwriting until the expiration of forty (40) days after the date of such acquisition.
4.    “Exchange Act” shall mean the Securities Exchange Act of 1934, as amended.
5.    “Person” shall mean an individual or a corporation, partnership, trust, unincorporated organization, association, or other entity.
6.    “UGI Subsidiary” shall mean any corporation in which UGI directly or indirectly, owns at least a fifty percent (50%) interest or an unincorporated entity of which UGI, as applicable, directly or indirectly, owns at least fifty percent (50%) of the profits or capital interests.

18

Exhibit C 

Non-Employee Director Grants
Options :
8,500 shares
Grant Date: 5th business day of January
Stock Units :
2,800 units
Grant Date: 5th business day of January

19

EXHIBIT 10.16
UGI CORPORATION
2004 OMNIBUS EQUITY COMPENSATION PLAN 
 NONQUALIFIED STOCK OPTION GRANT LETTER
This STOCK OPTION GRANT, dated October 1, 2012 (the “Date of Grant”), is delivered by UGI Corporation (“UGI”) to Kirk R. Oliver (the “Participant”).
RECITALS
The UGI Corporation 2004 Omnibus Equity Compensation Plan, as amended (the “Plan”), provides for the grant of options to purchase shares of common stock of UGI. The Compensation and Management Development Committee of the Board of Directors of UGI (the “Committee”) has decided to make a stock option grant to the Participant.
NOW, THEREFORE, the parties to this Grant Letter, intending to be legally bound hereby, agree as follows:
1. Grant of Option . Subject to the terms and conditions set forth in this Grant Letter and in the Plan, the Committee hereby grants to the Participant a nonqualified stock option (the “Option”) to purchase 18,750 shares of common stock of UGI (“Shares”) at an exercise price of $31.10 per Share. The Option shall become exercisable according to Paragraph 2 below.
2.      Exercisability of Option . The Option shall become exercisable on the following dates, if the Participant is employed by, or providing service to, the Company (as defined below) on the applicable date:

		

Date	Shares for Which the
Option is Exercisable	
October 1, 2013	33⅓%	
October 1, 2014	33⅓%	
October 1, 2015	33⅓%	

The exercisability of the Option is cumulative, but shall not exceed 100% of the Shares subject to the Option. If the foregoing schedule would produce fractional Shares, the number of Shares for which the Option becomes exercisable shall be rounded down to the nearest whole Share.
3.      Term of Option .
(a)      The Option shall have a term of ten years from the Date of Grant and shall terminate at the expiration of that period (5:00 p.m. EST on September 30, 2022), unless it is terminated at an earlier date pursuant to the provisions of this Grant Letter or the Plan.

(b)      If the Participant ceases to be employed by, or provide service to, the Company, the Option will terminate on the date the Participant ceases such employment or service. However, if the Participant ceases to be employed by, or provide service to, the Company by reason of (i) Termination Without Cause (as defined below), (ii) Retirement (as defined below), (iii) Disability (as defined below), or (iv) death, the Option held by the Participant will thereafter be exercisable pursuant to the following terms:
(i)      Termination Without Cause . If the Participant terminates employment or service on account of a Termination without Cause, the Option will thereafter be exercisable only with respect to that number of Shares with respect to which the Option is already exercisable on the date the Participant’s employment or service terminates. Such portion of the Option will terminate upon the earlier of the expiration date of the Option or the expiration of the 13-month period commencing on the date the Participant ceases to be employed by, or provide service to, the Company.
(ii)      Retirement . If the Participant ceases to be employed by, or provide service to, the Company on account of Retirement, the Option will thereafter become exercisable as if the Participant had continued to be employed by, or provide service to, the Company after the date of such Retirement. The Option will terminate upon the expiration date of the Option.
(iii)      Disability . If the Participant ceases to be employed by, or provide service to, the Company on account of Disability, the Option will thereafter become exercisable as if the Participant had continued to provide service to the Company for 36 months after the date of such termination of employment or service. The Option will terminate upon the earlier of the expiration date of the Option or the expiration of such 36-month period.
(iv)      Death . In the event of the death of the Participant while employed by, or providing service to, the Company, the Option will be fully and immediately exercisable and may be exercised at any time prior to the earlier of the expiration date of the Option or the expiration of the 12-month period following the Participant’s death. Death of the Participant after the Participant has ceased to be employed by, or provide service to, the Company will not affect the otherwise applicable period for exercise of the Option determined pursuant to subsections (i), (ii) or (iii) above. After the Participant’s death, the Participant’s Option may be exercised by the Participant’s estate.
4.      Exercise Procedures .
(a)      Subject to the provisions of Paragraphs 2 and 3 above, the Participant may exercise part or all of the exercisable Option by giving UGI irrevocable written notice of intent to exercise on a form provided by UGI and delivered in the manner provided in Section 13 below. Payment of the exercise price and any applicable withholding taxes must be made prior to issuance of the Shares. The Participant shall pay the exercise price (i) in cash, (ii) by delivering Shares (or by attestation to ownership of Shares), which shall be valued at their fair market value on the date of delivery, and which shall have a fair market value on the date of exercise equal to the exercise price, (iii) by payment through a broker in accordance with procedures acceptable to

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the Committee and permitted by Regulation T of the Federal Reserve Board, (iv) by a “net exercise” in accordance with procedures established by the Committee, or (v) by such other method as the Committee may approve. The Committee may impose such limitations as it deems appropriate on the use of Shares to exercise the Option.
(b)      The obligation of UGI to deliver Shares upon exercise of the Option shall be subject to all applicable laws, rules, and regulations and such approvals by governmental agencies as may be deemed appropriate by the Committee, including such actions as UGI’s counsel shall deem necessary or appropriate to comply with relevant securities laws and regulations. UGI may require that the Participant (or other person exercising the Option after the Participant’s death) represent that the Participant is purchasing Shares for the Participant’s own account and not with a view to or for sale in connection with any distribution of the Shares, or such other representation as UGI deems appropriate.
(c)      All obligations of UGI under this Grant Letter shall be subject to the rights of the Company as set forth in the Plan to withhold amounts required to be withheld for any taxes, if applicable.
5.      Definitions . Whenever used in this Grant Letter, the following terms shall have the meanings set forth below:
(a)      “Company” means UGI and its Subsidiaries (as defined in the Plan).
(b)      “ Disability ” means a long-term disability as defined in the Company’s long-term disability plan applicable to the Participant.
(c)      “Employed by, or provide service to, the Company” shall mean employment or service as an employee or director of the Company.
(d)      “ Retirement ” means the Participant’s retirement under the Retirement Income Plan for Employees of UGI Utilities, Inc., if the Participant is covered by that Retirement Income Plan. “Retirement” for other Company employees means termination of employment after attaining age 55 with ten or more years of service with the Company.
(e)      “ Termination without Cause ” means termination of employment for the convenience of the Company for any reason other than (i) misappropriation of funds, (ii) habitual insobriety or substance abuse, (iii) conviction of a crime involving moral turpitude, or (iv) gross negligence in the performance of duties, which gross negligence has had a material adverse effect on the business, operations, assets, properties or financial condition of the Company. The Committee may determine in its sole discretion whether, and under what circumstances, the Participant’s voluntary termination upon a significant reduction in the Participant’s duties and responsibilities will constitute a Termination without Cause for purposes of the Grant Letter.
6.      Change of Control . If a Change of Control (as defined in the Plan) occurs, the outstanding Option will become fully exercisable as of the date of the Change of Control, and the Committee may take such actions as it deems appropriate pursuant to the Plan.

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7.      Restrictions on Exercise . Except as the Committee may otherwise permit pursuant to the Plan, only the Participant may exercise the Option during the Participant’s lifetime and, after the Participant’s death, the Option shall be exercisable by the Participant’s estate, to the extent that the Option is exercisable pursuant to this Grant Letter.
8.      Grant Subject to Plan Provisions and Company Policies .
(a)      This grant is made pursuant to the Plan and the Terms and Conditions established by the Committee with respect to the Plan, both of which are incorporated herein by reference, and in all respects shall be interpreted in accordance with the Plan and the Terms and Conditions. The grant and exercise of the Option are subject to interpretations, regulations and determinations concerning the Plan established from time to time by the Committee in accordance with the provisions of the Plan, including, but not limited to, provisions pertaining to (i) the registration, qualification or listing of the Shares, (ii) changes in capitalization of the Company and (iii) other requirements of applicable law. The Committee shall have the authority to interpret and construe the Option pursuant to the terms of the Plan, and its decisions shall be conclusive as to any questions arising hereunder.
(b)      All Shares issued pursuant to this Option grant shall be subject to the UGI Corporation Stock Ownership Policy. This Option grant and all Shares issued pursuant to this Option grant shall be subject to any applicable clawback and other policies implemented by the Board of Directors of UGI, as in effect from time to time.
9.      No Employment or Other Rights . The grant of the Option shall not confer upon the Participant any right to be retained by or in the employ or service of the Company and shall not interfere in any way with the right of the Company to terminate the Participant’s employment or service at any time. The right of the Company to terminate at will the Participant’s employment or service at any time for any reason is specifically reserved.
10.      No Shareholder Rights . Neither the Participant, nor any person entitled to exercise the Participant’s rights in the event of the Participant’s death, shall have any of the rights and privileges of a shareholder with respect to the Shares subject to the Option, until certificates for Shares have been issued upon the exercise of the Option.
11.      Assignment and Transfers . The rights and interests of the Participant under this Grant Letter may not be sold, assigned, encumbered or otherwise transferred except, in the event of the death of the Participant, by will or by the laws of descent and distribution. The rights and protections of the Company hereunder shall extend to any successors or assigns of the Company and to the Company’s parents, subsidiaries, and affiliates.
12.      Applicable Law . The validity, construction, interpretation and effect of this instrument shall be governed by and construed in accordance with the laws of the Commonwealth of Pennsylvania, without giving effect to the conflicts of laws provisions thereof.
13.      Notice . Any notice to UGI provided for in this instrument shall be addressed to UGI in care of the Corporate Secretary at UGI’s headquarters, and any notice to the Participant shall be

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addressed to such Participant at the current address shown on the payroll of the Company, or to such other address as the Participant may designate to the Company in writing. Any notice shall be delivered by hand, sent by telecopy or enclosed in a properly sealed envelope addressed as stated above, registered and deposited, postage prepaid, in a post office regularly maintained by the United States Postal Service.
IN WITNESS WHEREOF, UGI has caused its duly authorized officers to execute and attest this Grant Letter, and the Participant has executed this Grant Letter, effective as of the Date of Grant.
UGI Corporation
Attest
By:                         
Jessica A. Milner                  Monica Gaudiosi
Assistant Secretary                 Vice President and General Counsel, Secretary

I hereby acknowledge receipt of the Plan and the Terms and Conditions incorporated herein. I accept the Option described in this Grant Letter, and I agree to be bound by the terms of the Plan, including the Terms and Conditions, and this Grant Letter. I hereby further agree that all the decisions and determinations of the Committee shall be final and binding on me and any other person having or claiming a right under this grant.

Kirk R. Oliver

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EXHIBIT 10.17
UGI CORPORATION
2004 OMNIBUS EQUITY COMPENSATION PLAN 
 PERFORMANCE UNIT GRANT LETTER
This PERFORMANCE UNIT GRANT, dated October 1, 2012 (the “Date of Grant”), is delivered by UGI Corporation (“UGI”) to Kirk R. Oliver (the “Participant”).
RECITALS
The UGI Corporation 2004 Omnibus Equity Compensation Plan (the “Plan”) provides for the grant of performance units (“Performance Units”) with respect to shares of common stock of UGI (“Shares”). The Compensation and Management Development Committee of the Board of Directors of UGI (the “Committee”) has decided to grant Performance Units to the Participant.
NOW, THEREFORE, the parties to this Grant Letter, intending to be legally bound hereby, agree as follows:
1. Grant of Performance Units . Subject to the terms and conditions set forth in this Grant Letter and in the Plan, the Committee hereby grants to the Participant a target award of 5,000 Performance Units (the “Target Award”). The Performance Units are contingently awarded and will be earned and payable if and to the extent that the performance goals and other conditions of the Grant Letter are met. The Performance Units are granted with Dividend Equivalents (as defined in Section 9).
2.      Performance Goals .
(a)      The Participant shall earn the right to payment of the Performance Units if the performance goals described in subsection (b) below are met for the measurement period, and if the Participant continues to be employed by, or provide service to, the Company (as defined in Section 9) through December 31, 2013. The measurement period is the period beginning January 1, 2011 and ending December 31, 2013.
(b)      The Target Award level of Performance Units and Dividend Equivalents will be payable if UGI’s Total Shareholder Return (TSR) equals the median TSR of a peer group for the measurement period. The peer group is the group of companies that comprises the Russell Midcap Utilities Index, excluding telecommunications companies, as of the beginning of the measurement period, as set forth on the attached Exhibit A . If a company is added to the Russell Midcap Utilities Index during the measurement period, that company is not included in the TSR calculation. A company that is included in the Russell Midcap Utilities Index at the beginning of the measurement period will be removed from the TSR calculation only if the company ceases to exist as a publicly traded company during the measurement period (including by way of a merger or similar transaction in which the company is not the surviving company). Companies that are designated at the beginning of the measurement period as telecommunications companies in the

Russell Midcap Utilities Index shall be excluded from the TSR calculation. The actual amount of the award of Performance Units may be higher or lower than the Target Award, or it may be zero, based on UGI’s TSR percentile rank relative to the companies in the Russell Midcap Utilities Index, excluding telecommunications companies, as follows:
UGI’s TSR Rank          Percentage of Target Award Earned
(Percentile)

Highest    200%
90th        175%
75th        150%
60th        125%
50th        100%
40th         50%
less than 40th     0%
The award percentage earned will be interpolated between each of the measuring points.
(c)      TSR shall be calculated by UGI using the comparative returns methodology used by Bloomberg L.P. or its successor at the time of the calculation. The share price used for determining TSR at the beginning and the end of the measurement period will be the average price for the 90-day period preceding the beginning of the measurement period (i.e., the 90-day period ending on December 31, 2010) and the 90-day period ending on the last day of the measurement period (i.e., the 90-day period ending on December 31, 2013), respectively. The TSR calculation gives effect to all dividends throughout the three-year measurement period as if they had been reinvested.
(d)      The Target Award is the amount designated for 100% (50th TSR rank) performance. The Participant can earn up to 200% of the Target Award if UGI’s TSR rank exceeds the 50th TSR rank, according to the foregoing schedule.
(e)      At the end of the measurement period, the Committee will determine whether and to what extent the performance goals have been met and the amount to be paid with respect to the Performance Units. Except as described in Section 3 below, the Participant must be employed by, or providing service to, the Company on December 31, 2013 in order for the Participant to receive payment with respect to the Performance Units.
3.      Termination of Employment or Service .
(a)      Except as described below, if the Participant’s employment or service with the Company terminates before December 31, 2013, the Performance Units and all Dividend Equivalents credited under this Grant Letter will be forfeited.
(b)      If the Participant terminates employment or service on account of Retirement (as defined in Section 9), Disability (as defined in Section 9) or death, the Participant will earn a pro-rata portion of the Participant’s outstanding Performance Units and Dividend Equivalents, if

2

the performance goals and the requirements of this Grant Letter are met. The prorated portion will be determined as the amount that would otherwise be paid after the end of the measurement period, based on achievement of the performance goals, multiplied by a fraction, the numerator of which is the number of calendar years during the measurement period in which the Participant has been employed by, or provided service to, the Company and the denominator of which is three. For purposes of the proration calculation, the calendar year in which the Participant’s termination of employment or service on account of Retirement, Disability, or death occurs will be counted as a full year.
(c)      In the event of termination of employment or service on account of Retirement, Disability or death, the prorated amount shall be paid after the end of the measurement period, pursuant to Section 5 below.
4.      Coordination with Severance Plan . Notwithstanding anything in this Grant Letter to the contrary, if the Participant receives severance benefits under a Severance Plan (as defined in Section 9) and the terms of such benefits require that severance compensation payable under the Severance Plan be reduced by benefits payable under this Plan, any amount payable to the Participant with respect to Performance Units and Dividend Equivalents after the Participant’s termination of employment or service shall be reduced by the amount of severance compensation paid to the Participant under the Severance Plan, as required by, and according to the terms of, the Severance Plan.
5.      Payment with Respect to Performance Units . If the Committee determines that the conditions to payment of the Performance Units have been met, the Company shall pay to the Participant, between January 1, 2014 and March 15, 2014, (i) Shares equal to the number of Performance Units to be paid according to achievement of the performance goals, up to the Target Award, provided that the Company may withhold Shares to cover required tax withholding in an amount equal to the minimum statutory tax withholding requirement in respect of the Performance Units earned up to the Target Award, and (ii) cash in an amount equal to the Fair Market Value (as defined in the Plan) of the number of Shares equal to the Performance Units to be paid in excess of the Target Award.
6.      Dividend Equivalents with Respect to Performance Units .
(a)      Dividend Equivalents shall accrue with respect to Performance Units and shall be payable subject to the same performance goals and terms as the Performance Units to which they relate. Dividend Equivalents shall be credited with respect to the Target Award of Performance Units from the Date of Grant until the payment date. If and to the extent that the underlying Performance Units are forfeited, all related Dividend Equivalents shall also be forfeited.
(b)      While the Performance Units are outstanding, the Company will keep records in a bookkeeping account for the Participant. On each payment date for a dividend paid by UGI on its common stock, the Company shall credit to the Participant’s account an amount equal to the Dividend Equivalents associated with the Target Award of Performance Units held by the Participant on the record date for the dividend. No interest will be credited to any such account.

3

(c)      The target amount of Dividend Equivalents (100% of the Dividend Equivalents credited to the Participant’s account) will be earned if UGI’s TSR rank is at the 50th TSR rank for the measurement period. The Participant can earn up to 200% of the target amount of Dividend Equivalents if UGI’s TSR rank exceeds the 50th TSR rank, according to the schedule in Section 2 above. Except as described in Section 3(b) above, if the Participant’s employment or service with the Company terminates before December 31, 2013, all Dividend Equivalents will be forfeited.
(d)      Dividend Equivalents will be paid in cash at the same time as the underlying Performance Units are paid, after the Committee determines that the conditions to payment have been met. Notwithstanding anything in this Grant Letter to the contrary, the Participant may not accrue Dividend Equivalents in excess of $750,000 during any calendar year under all grants under the Plan.
7.      Withholding . The Participant shall be required to pay to the Company, or make other arrangements satisfactory to the Company to provide for the payment of, any federal, state, local or other taxes that the Company is required to withhold with respect to the payments under this Grant Letter.
8.      Change of Control . If a Change of Control (as defined in the Plan) occurs during the measurement period, the outstanding Performance Units and Dividend Equivalents shall be paid in cash in an amount equal to the greater of (i) the Target Award amount or (ii) the award amount that would be paid as if the measurement period ended on the date of the Change of Control, based on the Company’s achievement of the performance goals as of the date of the Change of Control, as determined by the Committee. If a former Participant is entitled to receive a prorated award for the measurement period pursuant to Section 3(b) above, the award will be the prorated portion of the amount described in the preceding sentence. The Performance Units and Dividend Equivalents shall be paid on the closing date of the Change of Control.
9.      Definitions . For purposes of this Grant Letter, the following terms will have the meanings set forth below:
(a)      “Company” means UGI and its Subsidiaries (as defined in the Plan).
(b)      “ Disability ” means a long-term disability as defined in the Company’s long-term disability plan applicable to the Participant.
(c)      “Dividend Equivalent” means an amount determined by multiplying the number of shares of UGI common stock subject to the target award of Performance Units by the per-share cash dividend, or the per-share fair market value of any dividend in consideration other than cash, paid by UGI on its common stock.
(d)      “Employed by, or provide service to, the Company” shall mean employment or service as an employee or director of the Company.

4

(e)      “Performance Unit” means a hypothetical unit that represents the value of one share of UGI common stock.
(f)      “ Retirement ” means the Participant’s retirement under the Retirement Income Plan for Employees of UGI Utilities, Inc., if the Participant is covered by that Retirement Income Plan. “Retirement” for other Company employees means termination of employment after attaining age 55 with ten or more years of service with the Company.
(g)      “Severance Plan” means any severance plan maintained by the Company that is applicable to the Participant.
10.      Grant Subject to Plan Provisions and Company Policies .
(a)      This grant is made pursuant to the Plan and the Terms and Conditions established by the Committee with respect to the Plan, both of which are incorporated herein by reference, and in all respects shall be interpreted in accordance with the Plan. The grant and payment of Performance Units and Dividend Equivalents are subject to interpretations, regulations and determinations concerning the Plan established from time to time by the Committee in accordance with the provisions of the Plan, including, but not limited to, provisions pertaining to (i) the registration, qualification or listing of the Shares, (ii) changes in capitalization of the Company and (iii) other requirements of applicable law. The Committee shall have the authority to interpret and construe the grant pursuant to the terms of the Plan, and its decisions shall be conclusive as to any questions arising hereunder.
(b)      All Shares issued pursuant to this Performance Unit grant shall be subject to the UGI Corporation Stock Ownership Policy. This Performance Unit grant and all Shares issued pursuant to this Performance Unit grant shall be subject to any applicable clawback and other policies implemented by the Board of Directors of UGI, as in effect from time to time.
11.      No Employment or Other Rights . The grant of Performance Units shall not confer upon the Participant any right to be retained by or in the employ or service of the Company and shall not interfere in any way with the right of the Company to terminate the Participant’s employment or service at any time. The right of the Company to terminate at will the Participant’s employment or service at any time for any reason is specifically reserved.
12.      No Shareholder Rights . Neither the Participant, nor any person entitled to exercise the Participant’s rights in the event of the Participant’s death, shall have any of the rights and privileges of a shareholder with respect to the Shares related to the Performance Units, unless and until certificates for Shares have been issued to the Participant or successor.
13.      Assignment and Transfers . The rights and interests of the Participant under this Grant Letter may not be sold, assigned, encumbered or otherwise transferred except, in the event of the death of the Participant, by will or by the laws of descent and distribution. If the Participant dies, any payments to be made under this Grant Letter after the Participant’s death shall be paid to the Participant’s estate. The rights and protections of the Company hereunder shall extend to any successors or assigns of the Company and to the Company’s parents, subsidiaries, and affiliates.

5

14.      Applicable Law . The validity, construction, interpretation and effect of this instrument shall be governed by and construed in accordance with the laws of the Commonwealth of Pennsylvania, without giving effect to the conflicts of laws provisions thereof.
15.      Notice . Any notice to UGI provided for in this instrument shall be addressed to UGI in care of the Corporate Secretary at UGI’s headquarters, and any notice to the Participant shall be addressed to such Participant at the current address shown on the payroll of the Company, or to such other address as the Participant may designate to the Company in writing. Any notice shall be delivered by hand, sent by telecopy or enclosed in a properly sealed envelope addressed as stated above, registered and deposited, postage prepaid, in a post office regularly maintained by the United States Postal Service.
IN WITNESS WHEREOF, UGI has caused its duly authorized officers to execute and attest this Grant Letter, and the Participant has executed this Grant Letter, effective as of the Date of Grant.

UGI Corporation
Attest
By:                         
Jessica A. Milner                  Monica Gaudiosi
Assistant Secretary                 Vice President and General Counsel, Secretary
    
I hereby acknowledge receipt of the Plan and the Terms and Conditions incorporated herein. I accept the Performance Units described in this Grant Letter, and I agree to be bound by the terms of the Plan, including the Terms and Conditions, and this Grant Letter. I hereby further agree that all the decisions and determinations of the Committee shall be final and binding on me and any other person

Kirk R. Oliver

6

EXHIBIT A

UGI CORPORATION
PERFORMANCE UNIT PEER GROUP

RUSSELL MIDCAP UTILITIES
(EXCLUDING TELECOMS)
as of 1/1/2011

A-1

AES Corp. (AES)
AGL Resources (AGL)
Allegheny Energy (AYE)
Alliant Energy (LNT)
Ameren Corporation (AEE)
American Water Works (AWK)
Aqua America Inc. (WTR)
Atmos Energy (ATO)
Calpine Corp. (CPN)
Centerpoint Energy (CNP)
CMS Energy Corp. (CMS)
Consolidated Edison Inc. (ED)
Constellation Energy (CEG)
DPL Inc. (DPL)
DTE Energy Co. (DTE)
Edison International (EIX)
Energen Corp. (EGN)
FirstEnergy Corp. (FE)
Genon Energy Inc. (GEN)
Great Plains Energy (GXP)
Hawaiian Electric (HE)
Integrys Energy (TEG)
ITC Holdings Corp. (ITC)
MDU Resource Group (MDU)
National Fuel Gas Co. (NFG)
NiSource Inc. (NI)
Northeast Utilities (NU)
NRG Energy (NRG)
NStar (NST)
NV Energy Inc. (NVE)
OGE Energy Corp. (OGE)
ONEOK Inc. (OKE)
Ormat Technologies (ORA)
Pepco Holdings (POM)
Pinnacle West Capital Corp. (PNW)
PPL Corporation (PPL)
Progress Energy (PGN)
Questar Corp. (STR)
Scana Corp. (SCG)
Sempra Energy (SRE)
Teco Energy Inc. (TE)
UGI Corporation (UGI)
Vectren Corp. (VVC)
Westar Energy, Inc. (WR)
Wisconsin Energy (WEC)

A-1

XCEL Energy Inc. (XEL)

9

EXHIBIT 10.34

UGI CORPORATION
2013 OMNIBUS INCENTIVE COMPENSATION PLAN 
 NONQUALIFIED STOCK OPTION GRANT LETTER
This STOCK OPTION GRANT, dated April 1, 2013 (the “Date of Grant”), is delivered by UGI Corporation (“UGI”) to John L. Walsh (the “Participant”).
RECITALS
The UGI Corporation 2013 Omnibus Incentive Compensation Plan, as amended (the “Plan”), provides for the grant of options to purchase shares of common stock of UGI. The Compensation and Management Development Committee of the Board of Directors of UGI (the “Committee”) has decided to make a stock option grant to the Participant.
NOW, THEREFORE, the parties to this Grant Letter, intending to be legally bound hereby, agree as follows:
1. Grant of Option . Subject to the terms and conditions set forth in this Grant Letter and in the Plan, the Committee hereby grants to the Participant a nonqualified stock option (the “Option”) to purchase 86,000 shares of common stock of UGI (“Shares”) at an exercise price of $ 38.24 per Share. The Option shall become exercisable according to Paragraph 2 below.
2.      Exercisability of Option . The Option shall become exercisable on the following dates, if the Participant is employed by, or providing service to, the Company (as defined below) on the applicable date:

		

Date	Shares for Which the
Option is Exercisable	
April 1, 2014	33⅓%	
April 1, 2015	33⅓%	
April 1, 2016	33⅓%	

The exercisability of the Option is cumulative, but shall not exceed 100% of the Shares subject to the Option. If the foregoing schedule would produce fractional Shares, the number of Shares for which the Option becomes exercisable shall be rounded down to the nearest whole Share.
3.      Term of Option .
(a)      The Option shall have a term of ten years from the Date of Grant and shall terminate at the expiration of that period (5:00 p.m. EST on March 31, 2023), unless it is terminated at an earlier date pursuant to the provisions of this Grant Letter or the Plan.

(b)      If the Participant ceases to be employed by, or provide service to, the Company, the Option will terminate on the date the Participant ceases such employment or service. However, if the Participant ceases to be employed by, or provide service to, the Company by reason of one of the following events, the Option held by the Participant will thereafter be exercisable pursuant to the following terms:
(i)      Termination Without Cause . If the Participant terminates employment or service on account of a Termination without Cause, the Option will thereafter be exercisable only with respect to that number of Shares with respect to which the Option is already exercisable on the date the Participant’s employment or service terminates, except as provided in subsection (v) below. Such portion of the Option will terminate upon the earlier of the expiration date of the Option or the expiration of the 13-month period commencing on the date the Participant ceases to be employed by, or provide service to, the Company.
(ii)      Retirement . If the Participant ceases to be employed by, or provide service to, the Company on account of Retirement, the Option will thereafter become exercisable as if the Participant had continued to be employed by, or provide service to, the Company after the date of such Retirement. The Option will terminate upon the expiration date of the Option.
(iii)      Disability . If the Participant ceases to be employed by, or provide service to, the Company on account of Disability, the Option will thereafter become exercisable as if the Participant had continued to provide service to the Company for 36 months after the date of such termination of employment or service. The Option will terminate upon the earlier of the expiration date of the Option or the expiration of such 36-month period.
(iv)      Death . In the event of the death of the Participant while employed by, or providing service to, the Company, the Option will be fully and immediately exercisable and may be exercised at any time prior to the earlier of the expiration date of the Option or the expiration of the 12-month period following the Participant’s death. Death of the Participant after the Participant has ceased to be employed by, or provide service to, the Company will not affect the otherwise applicable period for exercise of the Option determined pursuant to subsections (i), (ii), (iii) or (v). After the Participant’s death, the Participant’s Option may be exercised by the Participant’s estate.
(v)      Termination Without Cause or Good Reason Termination upon or within two years after a Change of Control. Notwithstanding the foregoing, if the Participant’s employment or service terminates on account of a Termination Without Cause or a Good Reason Termination upon or within two years after a Change of Control, the Option will be fully and immediately exercisable. The Option will terminate upon the earlier of the expiration date of the Option or the expiration of the 13-month period commencing on the date the Participant ceases to be employed by, or provide service to, the Company; provided that if the Participant is eligible for Retirement at the date of such termination of employment, the Option will terminate on the expiration date of the Option.
4.      Exercise Procedures .
(a)      Subject to the provisions of Paragraphs 2 and 3 above, the Participant may exercise part or all of the exercisable Option by giving UGI irrevocable written notice of intent to exercise on a form provided by UGI and delivered in the manner provided in Section 13 below. Payment of the exercise price and any applicable withholding taxes must be made prior to issuance of the Shares. The Participant shall pay the exercise price (i) in cash, (ii) by “net exercise,” which is the surrender of shares for which the Option is exercisable to the Company in exchange for a distribution of Shares equal to the amount by which the then fair market value of the Shares subject to the exercised Option exceeds the applicable Option Price, (iii) by payment through a broker in accordance with procedures acceptable to the Committee and permitted by Regulation T of the Federal Reserve Board or (iv) by such other method as the Committee may approve. The Committee may impose such limitations as it deems appropriate on the use of Shares to exercise the Option.
(b)      The obligation of UGI to deliver Shares upon exercise of the Option shall be subject to all applicable laws, rules, and regulations and such approvals by governmental agencies as may be deemed appropriate by the Committee, including such actions as UGI’s counsel shall deem necessary or appropriate to comply with relevant securities laws and regulations. UGI may require that the Participant (or other person exercising the Option after the Participant’s death) represent that the Participant is purchasing Shares for the Participant’s own account and not with a view to or for sale in connection with any distribution of the Shares, or such other representation as UGI deems appropriate.
(c)      All obligations of UGI under this Grant Letter shall be subject to the rights of the Company as set forth in the Plan to withhold amounts required to be withheld for any taxes, if applicable.
5.      Definitions . Whenever used in this Grant Letter, the following terms shall have the meanings set forth below:
(a)      “Change of Control” shall have the meaning given that term in the Plan.
(b)      “Company” means UGI and its Subsidiaries (as defined in the Plan).
(c)      “ Disability ” means a long-term disability as defined in the Company’s long-term disability plan applicable to the Participant.
(d)      “Employed by, or provide service to, the Company” shall mean employment or service as an employee or director of the Company.
(e)      “ Good Reason Termination ” shall mean a termination of employment or service initiated by the Participant upon or within two years after a Change of Control upon one or more of the following occurences:

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(i)      a material diminution in the authority, duties or responsibilities held by the Participant immediately prior to the Change of Control;
(ii)      a material diminution in the Participant’s base salary as in effect immediately prior to the Change of Control; or
(iii)      a material change in the geographic location at which the Participant must perform services (which, for purposes of this Agreement, means the Participant is required to report, other than on a temporary basis (less than 12 months), to a location which is more than 50 miles from the Participant’s principal place of business immediately preceding the Change of Control, without the Participant’s express written consent).
Notwithstanding the foregoing, the Participant shall be considered to have a Good Reason Termination only if the Participant provides written notice to the Company, pursuant to Section 13, specifying in reasonable detail the events or conditions upon which the Participant is basing such Good Reason Termination and the Participant provides such notice within 90 days after the event that gives rise to the Good Reason Termination. Within 30 days after notice has been provided, the Company shall have the opportunity, but shall have no obligation, to cure such events or conditions that give rise to the Good Reason Termination. If the Company does not cure such events or conditions within the 30-day period, the Participant may terminate employment or service with the Company based on Good Reason Termination within 30 days after the expiration of the cure period.
Notwithstanding the foregoing, if the Participant has in effect a Change in Control Agreement with the Company or an Affiliate, the term “Good Reason Termination” shall have the meaning given that term in the Change in Control Agreement.
(f)      “ Retirement ” means the Participant’s retirement under the Retirement Income Plan for Employees of UGI Utilities, Inc., if the Participant is covered by that Retirement Income Plan. “Retirement” for other Company employees means termination of employment or service after attaining (i) age 55 with ten or more years of service with the Company or (ii) age 65 with five or more years of service with the Company.
(g)      “ Termination without Cause ” means termination of employment or service by the Company for the convenience of the Company for any reason other than (i) misappropriation of funds, (ii) habitual insobriety or substance abuse adversely affecting the performance of duties, (iii) conviction of a crime involving moral turpitude, or (iv) gross negligence in the performance of duties, which gross negligence has had a material adverse effect on the business, operations, assets, properties or financial condition of the Company.
6.      Change of Control . If a Change of Control occurs, the Committee may take such actions with respect to the Option as it deems appropriate pursuant to the Plan.
7.      Restrictions on Exercise . Except as the Committee may otherwise permit pursuant to the Plan, only the Participant may exercise the Option during the Participant’s lifetime and, after the

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Participant’s death, the Option shall be exercisable by the Participant’s estate, to the extent that the Option is exercisable pursuant to this Grant Letter.
8.      Grant Subject to Plan Provisions and Company Policies .
(a)      This grant is made pursuant to the Plan, which is incorporated herein by reference, and in all respects shall be interpreted in accordance with the Plan. The grant and exercise of the Option are subject to interpretations, regulations and determinations concerning the Plan established from time to time by the Committee in accordance with the provisions of the Plan, including, but not limited to, provisions pertaining to (i) the registration, qualification or listing of the Shares, (ii) changes in capitalization of the Company and (iii) other requirements of applicable law. The Committee shall have the authority to interpret and construe the Option pursuant to the terms of the Plan, and its decisions shall be conclusive as to any questions arising hereunder.
(b)      All Shares issued pursuant to this Option grant shall be subject to the UGI Corporation Stock Ownership Policy. This Option grant and all Shares issued pursuant to this Option grant shall be subject to any applicable clawback and other policies implemented by the Board of Directors of UGI, as in effect from time to time.
9.      No Employment or Other Rights . The grant of the Option shall not confer upon the Participant any right to be retained by or in the employ or service of the Company and shall not interfere in any way with the right of the Company to terminate the Participant’s employment or service at any time. The right of the Company to terminate at will the Participant’s employment or service at any time for any reason is specifically reserved.
10.      No Shareholder Rights . Neither the Participant, nor any person entitled to exercise the Participant’s rights in the event of the Participant’s death, shall have any of the rights and privileges of a shareholder with respect to the Shares subject to the Option, until certificates for Shares have been issued upon the exercise of the Option.
11.      Assignment and Transfers . The rights and interests of the Participant under this Grant Letter may not be sold, assigned, encumbered or otherwise transferred except, in the event of the death of the Participant, by will or by the laws of descent and distribution. The rights and protections of the Company hereunder shall extend to any successors or assigns of the Company and to the Company’s parents, subsidiaries, and affiliates.
12.      Applicable Law . The validity, construction, interpretation and effect of this instrument shall be governed by and construed in accordance with the laws of the Commonwealth of Pennsylvania, without giving effect to the conflicts of laws provisions thereof.
13.      Notice . Any notice to UGI provided for in this instrument shall be addressed to UGI in care of the Corporate Secretary at UGI’s headquarters, and any notice to the Participant shall be addressed to such Participant at the current address shown on the payroll of the Company, or to such other address as the Participant may designate to the Company in writing. Any notice shall be delivered by hand, sent by telecopy or enclosed in a properly sealed envelope addressed as

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stated above, registered and deposited, postage prepaid, in a post office regularly maintained by the United States Postal Service.
IN WITNESS WHEREOF, UGI has caused its duly authorized officers to execute and attest this Grant Letter, and the Participant has executed this Grant Letter, effective as of the Date of Grant.
UGI Corporation
Attest
By:                         
Jessica A. Milner                 Monica M. Gaudiosi
Assistant Secretary              Vice President and General Counsel, Secretary                            

I hereby acknowledge receipt of the Plan. I accept the Option described in this Grant Letter, and I agree to be bound by the terms of the Plan and this Grant Letter. I hereby further agree that all the decisions and determinations of the Committee shall be final and binding on me and any other person having or claiming a right under this grant.

John L. Walsh

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EXHIBIT 10.35 
UGI CORPORATION
2013 OMNIBUS INCENTIVE COMPENSATION PLAN 
 PERFORMANCE UNIT GRANT LETTER
This PERFORMANCE UNIT GRANT, dated April 1, 2013 (the “Date of Grant”), is delivered by UGI Corporation (“UGI”) to John L. Walsh (the “Participant”).
RECITALS
The UGI Corporation 2013 Omnibus Incentive Compensation Plan (the “Plan”) provides for the grant of performance units (“Performance Units”) with respect to shares of common stock of UGI (“Shares”). The Compensation and Management Development Committee of the Board of Directors of UGI (the “Committee”) has decided to grant Performance Units to the Participant.
NOW, THEREFORE, the parties to this Grant Letter, intending to be legally bound hereby, agree as follows:
1. Grant of Performance Units . Subject to the terms and conditions set forth in this Grant Letter and in the Plan, the Committee hereby grants to the Participant a target award of 21,000 Performance Units (the “Target Award”). The Performance Units are contingently awarded and will be earned and payable if and to the extent that the Performance Goals (defined below) and other conditions of the Grant Letter are met. The Performance Units are granted with Dividend Equivalents (as defined in Section 7).
2.      Performance Goals .
(a)      The Participant shall earn the right to payment of the Performance Units if the Performance Goals are met for the Performance Period, and if the Participant continues to be employed by, or provide service to, the Company (as defined in Section 7) through December 31, 2015. The Performance Period is the period beginning January 1, 2013 and ending December 31, 2015. The Total Shareholder Return (“TSR”) goals and other requirements of this Section 2 are referred to as the “Performance Goals.”
(b)      The Target Award level of Performance Units and Dividend Equivalents will be payable if UGI’s TSR equals the median TSR of the comparison group designated by the Committee (the “Peer Group”) for the Performance Period. The Peer Group is the group of companies that comprises the Russell Midcap Utilities Index, excluding telecommunications companies, as of the beginning of the Performance Period, as set forth on the attached Exhibit A , and as described herein. If a company is added to the Russell Midcap Utilities Index during the Performance Period, that company is not included in the TSR calculation. A company that is included in the Russell Midcap Utilities Index at the beginning of the Performance Period will be removed from the TSR calculation only if the company ceases to exist as a publicly traded

company during the Performance Period (including by way of a merger or similar transaction in which the company is not the surviving company), consistent with the methodology described in subsection (c) below. Companies that are designated at the beginning of the Performance Period as telecommunications companies in the Russell Midcap Utilities Index shall be excluded from the TSR calculation. The actual amount of the award of Performance Units may be higher or lower than the Target Award, or it may be zero, based on UGI’s TSR percentile rank relative to the companies in the Peer Group, as follows:
UGI’s TSR Rank          Percentage of Target Award Earned 
                                   (Percentile)
90th                        200%
75th                        162.5%
60th                        125%
50th                        100%
40th                         70%
25th                         25%
Less than 25th                     0%

The award percentage earned will be interpolated between each of the measuring points.
(c)      TSR shall be calculated by UGI using the comparative returns methodology used by Bloomberg L.P. or its successor at the time of the calculation. The share price used for determining TSR at the beginning and the end of the Performance Period will be the average price for the calendar quarter preceding the beginning of the Performance Period (i.e., the calendar quarter ending on December 31, 2012) and the calendar quarter ending on the last day of the Performance Period (i.e., the calendar quarter ending on December 31, 2015), respectively. The TSR calculation gives effect to all dividends throughout the three-year Performance Period as if they had been reinvested.
(d)      The Target Award is the amount designated for 100% (50th TSR rank) performance. The Participant can earn up to 200% of the Target Award if UGI’s TSR percentile rank exceeds the 50th TSR percentile rank, according to the foregoing schedule.
(e)      At the end of the Performance Period, the Committee will determine whether and to what extent the Performance Goals have been met and the amount to be paid with respect to the Performance Units. Except as described in Sections 3 and 6 below, the Participant must be employed by, or providing service to, the Company on December 31, 2015 in order for the Participant to receive payment with respect to the Performance Units.
3.      Termination of Employment or Service .
(a)      Except as described below, if the Participant ceases to be employed by, or provide services to, the Company before December 31, 2015, the Performance Units and all Dividend Equivalents credited under this Grant Letter will be forfeited.

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(b)      If the Participant terminates employment or service on account of Retirement (as defined in Section 7), Disability (as defined in Section 7) or death, the Participant will earn a pro-rata portion of the Participant’s outstanding Performance Units and Dividend Equivalents, if the Performance Goals and the requirements of this Grant Letter are met. The prorated portion will be determined as the amount that would otherwise be paid after the end of the Performance Period, based on achievement of the Performance Goals, multiplied by a fraction, the numerator of which is the number of calendar years during the Performance Period in which the Participant has been employed by, or provided service to, the Company and the denominator of which is three. For purposes of the proration calculation, the calendar year in which the Participant’s termination of employment or service on account of Retirement, Disability, or death occurs will be counted as a full year.
(c)      In the event of termination of employment or service on account of Retirement, Disability or death, the prorated amount shall be paid after the end of the Performance Period, pursuant to Section 4 below, except as provided in Section 6.
4.      Payment with Respect to Performance Units . If the Committee determines that the conditions to payment of the Performance Units have been met, the Company shall pay to the Participant (i) Shares equal to the number of Performance Units to be paid according to achievement of the Performance Goals, up to the Target Award, provided that the Company may withhold Shares to cover required tax withholding in an amount equal to the minimum statutory tax withholding requirement in respect of the Performance Units earned up to the Target Award, and (ii) cash in an amount equal to the Fair Market Value (as defined in the Plan) of the number of Shares equal to the Performance Units to be paid in excess of the Target Award, subject to applicable tax withholding. Payment shall be made between January 1, 2016 and March 15, 2016, except as provided in Section 6 below.
5.      Dividend Equivalents with Respect to Performance Units .
(a)      Dividend Equivalents shall accrue with respect to Performance Units and shall be payable subject to the same Performance Goals and terms as the Performance Units to which they relate. Dividend Equivalents shall be credited with respect to the Target Award of Performance Units from the Date of Grant until the payment date. If and to the extent that the underlying Performance Units are forfeited, all related Dividend Equivalents shall also be forfeited.
(b)      While the Performance Units are outstanding, the Company will keep records of Dividend Equivalents in a bookkeeping account for the Participant. On each payment date for a dividend paid by UGI on its common stock, the Company shall credit to the Participant’s account an amount equal to the Dividend Equivalents associated with the Target Award of Performance Units held by the Participant on the record date for the dividend. No interest will be credited to any such account.
(c)      The target amount of Dividend Equivalents (100% of the Dividend Equivalents credited to the Participant’s account) will be earned if UGI’s TSR rank is at the 50th TSR percentile rank for the Performance Period. The Participant can earn up to 200% of the target

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amount of Dividend Equivalents if UGI’s TSR percentile rank exceeds the 50th TSR rank, according to the schedule in Section 2 above. Except as described in Section 3(b) above, or Section 6, if the Participant’s employment or service with the Company terminates before December 31, 2015, all Dividend Equivalents will be forfeited.
(d)      Dividend Equivalents will be paid in cash at the same time as the underlying Performance Units are paid, after the Committee determines that the conditions to payment have been met. Notwithstanding anything in this Grant Letter to the contrary, the Participant may not accrue Dividend Equivalents in excess of $1,000,000 during any calendar year under all grants under the Plan.
6.      Change of Control .
(a)      If a Change of Control (as defined in the Plan) occurs, the Performance Units and Dividend Equivalents shall not automatically become payable upon the Change of Control, but, instead, shall become payable as described in this Section 6. The Committee may take such other actions with respect to the Performance Units and Dividend Equivalents as it deems appropriate pursuant to the Plan.
(b)      If a Change of Control occurs during the Performance Period, the Committee shall calculate a Change of Control Amount as follows:
(i)      The Performance Period shall end as of the closing date of the Change of Control (the “Change of Control Date”) and the TSR ending date calculation for the Performance Period shall be based on the 90 calendar day period ending on the Change of Control Date.
(ii)      The Committee shall calculate a “Change of Control Amount” equal to the greater of (i) the Target Award amount or (ii) the amount of Performance Units that would be payable based on the Company’s achievement of the Performance Goals as of the Change of Control Date, as determined by the Committee. The Change of Control Amount shall include related Dividend Equivalents and, if applicable, interest as described below.
(iii)      The Committee shall determine whether the Change of Control Amount attributable to Performance Units shall be (A) converted to units with respect to shares or other equity interests of the acquiring company or its parent (“Successor Units”), in which case Dividend Equivalents shall continue to be credited on the Successor Units, or (B) valued based on the Fair Market Value of the Performance Units as of the Change of Control Date and credited to a bookkeeping account for the Participant, in which case interest shall be credited on the amount so determined at a market rate for the period between the Change of Control Date and the applicable payment date.  Notwithstanding the provisions of Section 4, all payments on and after a Change of Control shall be made in cash.  If alternative (A) above is used, the cash payment shall equal the Fair Market Value on the date of payment of the number of shares or other equity interests underlying

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the Successor Units, plus accrued Dividend Equivalents.  All payments shall be subject to applicable tax withholding. 
(c)      If a Change of Control occurs during the Performance Period and the Participant continues in employment or service through December 31, 2015, the Change of Control Amount shall be paid in cash between January 1, 2016 and March 15, 2016.
(d)      If a Change of Control occurs during the Performance Period, and the Participant has a Termination without Cause or a Good Reason Termination upon or within two years after the Change of Control Date and before December 31, 2015, the Change of Control Amount shall be paid in cash within 30 days after the Participant’s separation from service, subject to Section 13 below.
(e)      If a Change of Control occurs during the Performance Period, and the Participant terminates employment or service on account of Retirement, Disability or death upon or after the Change of Control Date and before December 31, 2015, the Change of Control Amount shall be paid in cash within 30 days after the Participant’s separation from service, subject to Section 13 below; provided that, if required by section 409A, if the Participant’s Retirement, Disability or death occurs more than two years after the Change of Control Date, payment will be made between January 1, 2016 and March 15, 2016, and not upon the earlier separation from service.
(f)      If a Participant’s employment or service terminates on account of Retirement, death or Disability before a Change of Control, and a Change of Control subsequently occurs before the end of the Performance Period, the prorated amount in Section 3(b) shall be calculated by multiplying the fraction described in Section 3(b) by the Change of Control Amount. The prorated Change of Control Amount shall be paid in cash within 30 days after the Change of Control Date, subject to Section 13 below.
7.      Definitions . For purposes of this Grant Letter, the following terms will have the meanings set forth below:
(a)      “Company” means UGI and its Subsidiaries (as defined in the Plan).
(b)      “ Disability ” means a long-term disability as defined in the Company’s long-term disability plan applicable to the Participant.
(c)      “Dividend Equivalent” means an amount determined by multiplying the number of shares of UGI common stock subject to the target award of Performance Units by the per-share cash dividend, or the per-share fair market value of any dividend in consideration other than cash, paid by UGI on its common stock.
(d)      “Employed by, or provide service to, the Company” shall mean employment or service as an employee or director of the Company. The Participant shall not be considered to have a termination of employment or service under this Grant Letter until the Participant is no longer employed by, or performing services for, the Company.

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(e)      “ Good Reason Termination ” shall mean a termination of employment or service initiated by the Participant upon or after a Change of Control upon one or more of the following events:
(i)      a material diminution in the authority, duties or responsibilities held by the Participant immediately prior to the Change of Control;
(ii)      a material diminution in the Participant’s base salary as in effect immediately prior to the Change of Control; or
(iii)      a material change in the geographic location at which the Participant must perform services (which, for purposes of this Agreement, means the Participant is required to report, other than on a temporary basis (less than 12 months), to a location which is more than 50 miles from the Participant’s principal place of business immediately before the Change of Control, without the Participant’s express written consent).
Notwithstanding the foregoing, the Participant shall be considered to have a Good Reason Termination only if the Participant provides written notice to the Company, pursuant to Section 15, specifying in reasonable detail the events or conditions upon which the Participant is basing such Good Reason Termination and the Participant provides such notice within 90 days after the event that gives rise to the Good Reason Termination. Within 30 days after notice has been provided, the Company shall have the opportunity, but shall have no obligation, to cure such events or conditions that give rise to the Good Reason Termination. If the Company does not cure such events or conditions within the 30-day period, the Participant may terminate employment or service with the Company based on Good Reason Termination within 30 days after the expiration of the cure period.
Notwithstanding the foregoing, if the Participant has in effect a Change in Control Agreement with the Company or an Affiliate, the term “Good Reason Termination” shall have the meaning given that term in the Change in Control Agreement.
(f)      “Performance Unit” means a hypothetical unit that represents the value of one share of UGI common stock.
(g)      Retirement ” means the Participant’s retirement under the Retirement Income Plan for Employees of UGI Utilities, Inc., if the Participant is covered by that Retirement Income Plan. “Retirement” for other Company employees means termination of employment or service after attaining (i) age 55 with ten or more years of service with the Company or (ii) age 65 with five or more years of service with the Company.
(h)      “ Termination without Cause ” means termination of employment or service by the Company for the convenience of the Company for any reason other than (i) misappropriation of funds, (ii) habitual insobriety or substance abuse adversely affecting the performance of duties, (iii) conviction of a crime involving moral turpitude, or (iv) gross negligence in the performance

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of duties, which gross negligence has had a material adverse effect on the business, operations, assets, properties or financial condition of the Company.
8.      Withholding . All payments under this Grant Letter are subject to applicable tax withholding. The Participant shall be required to pay to the Company, or make other arrangements satisfactory to the Company to provide for the payment of, any federal (including FICA), state, local or other taxes that the Company is required to withhold with respect to the payments under this Grant Letter. The Company may withhold from cash distributions to cover required tax withholding, or may withhold Shares to cover required tax withholding in an amount equal to the minimum applicable tax withholding amount.
9.      Grant Subject to Plan Provisions and Company Policies .
(a)      This grant is made pursuant to the Plan, which is incorporated herein by reference, and in all respects shall be interpreted in accordance with the Plan. The grant and payment of Performance Units and Dividend Equivalents are subject to interpretations, regulations and determinations concerning the Plan established from time to time by the Committee in accordance with the provisions of the Plan, including, but not limited to, provisions pertaining to (i) the registration, qualification or listing of the Shares, (ii) adjustments pursuant to Section 5(d) of the Plan, and (iii) other requirements of applicable law. The Committee shall have the authority to interpret and construe the grant pursuant to the terms of the Plan, and its decisions shall be conclusive as to any questions arising hereunder.
(b)      This Performance Unit grant and Shares issued pursuant to this Performance Unit grant shall be subject to the UGI Corporation Stock Ownership Policy as adopted by the Board of Directors of UGI and any applicable clawback and other policies implemented by the Board of Directors of UGI, as in effect from time to time.
10.      No Employment or Other Rights . The grant of Performance Units shall not confer upon the Participant any right to be retained by or in the employ or service of the Company and shall not interfere in any way with the right of the Company to terminate the Participant’s employment or service at any time. The right of the Company to terminate at will the Participant’s employment or service at any time for any reason is specifically reserved.
11.      No Shareholder Rights . Neither the Participant, nor any person entitled to receive payment in the event of the Participant’s death, shall have any of the rights and privileges of a shareholder with respect to the Shares related to the Performance Units, unless and until certificates for Shares have been distributed to the Participant or successor.
12.      Assignment and Transfers . The rights and interests of the Participant under this Grant Letter may not be sold, assigned, encumbered or otherwise transferred except, in the event of the death of the Participant, by will or by the laws of descent and distribution. If the Participant dies, any payments to be made under this Grant Letter after the Participant’s death shall be paid to the Participant’s estate. The rights and protections of the Company hereunder shall extend to any successors or assigns of the Company and to the Company’s parents, subsidiaries, and affiliates.

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13.      Compliance with Code Section 409A . Notwithstanding the other provisions hereof, this Grant Letter is intended to comply with the requirements of section 409A of the Internal Revenue Code of 1986, as amended, or an exception, and shall be administered accordingly. Any reference to a Participant’s termination of employment shall mean a Participant’s “separation from service,” as such term is defined under section 409A. For purposes of section 409A, each payment of compensation under this Grant Letter shall be treated as a separate payment. Notwithstanding anything in this Grant Letter to the contrary, if the Participant is a “key employee” under section 409A and if payment of any amount under this Grant Letter is required to be delayed for a period of six months after separation from service pursuant to section 409A, payment of such amount shall be delayed as required by section 409A and shall be paid within 10 days after the end of the six-month period. If the Participant dies during such six-month period, the amounts withheld on account of section 409A shall be paid to the personal representative of the Participant’s estate within 60 days after the date of the Participant’s death. Notwithstanding anything in this Grant Letter to the contrary, if a Change of Control is not a “change in control event” under section 409A, any Performance Units and Dividend Equivalents that are payable pursuant to Section 6 shall be paid to the Participant between January 1, 2016 and March 15, 2016, and not upon the earlier separation from service, if required by section 409A.
14.      Applicable Law . The validity, construction, interpretation and effect of this Grant Letter shall be governed by and construed in accordance with the laws of the Commonwealth of Pennsylvania, without giving effect to the conflicts of laws provisions thereof.
15.      Notice . Any notice to UGI provided for in this Grant Letter shall be addressed to UGI in care of the Corporate Secretary at UGI’s headquarters, and any notice to the Participant shall be addressed to such Participant at the current address shown on the payroll of the Company, or to such other address as the Participant may designate to the Company in writing. Any notice shall be delivered by hand, sent by telecopy or enclosed in a properly sealed envelope addressed as stated above, registered and deposited, postage prepaid, in a post office regularly maintained by the United States Postal Service.
IN WITNESS WHEREOF, UGI has caused its duly authorized officers to execute and attest this Grant Letter, and the Participant has executed this Grant Letter, effective as of the Date of Grant.

UGI Corporation
Attest

By:                          
 Jessica A. Milner                 Monica M. Gaudiosi
Assistant Secretary              Vice President and General Counsel, Secretary    

8

I hereby acknowledge receipt of the Plan incorporated herein. I accept the Performance Units described in this Grant Letter, and I agree to be bound by the terms of the Plan, and this Grant Letter. I hereby further agree that all the decisions and determinations of the Committee shall be final and binding on me and any other person having or claiming a right under this grant.

John L. Walsh

9

EXHIBIT A

UGI CORPORATION
PERFORMANCE UNIT PEER GROUP

RUSSELL MIDCAP UTILITIES
(EXCLUDING TELECOMS)
as of 1/1/2013

A-1

AES Corp. (AES)
AGL Resources (AGL)
Alliant Energy (LNT)
Ameren Corporation (AEE)
American Water Works (AWK)
Aqua America Inc. (WTR)
Atmos Energy (ATO)
Calpine Corp. (CPN)
Centerpoint Energy (CNP)
CMS Energy Corp. (CMS)
DTE Energy Co. (DTE)
Edison International (EIX)
Energen Corp. (EGN)
Entergy Corp (ETR)
Great Plains Energy (GXP)
Hawaiian Electric (HE)
Integrys Energy (TEG)
ITC Holdings Corp. (ITC)
MDU Resource Group (MDU)
National Fuel Gas Co. (NFG)
NiSource Inc. (NI)
Northeast Utilities (NU)
NRG Energy (NRG)
NV Energy Inc. (NVE)
OGE Energy Corp. (OGE)
ONEOK Inc. (OKE)
Pepco Holdings (POM)
Pinnacle West Capital Corp. (PNW)
PPL Corporation (PPL)
Questar Corp. (STR)
Scana Corp. (SCG)
Sempra Energy (SRE)
Teco Energy Inc. (TE)
UGI Corporation (UGI)
Vectren Corp. (VVC)
Westar Energy, Inc. (WR)
Wisconsin Energy (WEC)
XCEL Energy Inc. (XEL)

A-1

EXHIBIT 10.37
UGI CORPORATION 
 DESCRIPTION OF COMPENSATION ARRANGEMENT
FOR
JOHN L. WALSH
John L. Walsh is President and Chief Executive Officer of UGI Corporation. Mr. Walsh has an oral compensation arrangement with UGI Corporation which includes the following:
Mr. Walsh:

1.	is entitled to an annual base salary, which for fiscal year 2013 was $861,710, reflecting the portion of Fiscal 2013 that he served as President and Chief Operating Officer (until April 1, 2013), as well as his promotion to President and Chief Executive Officer (effective April 1, 2013);	

2.	participates in UGI Corporation’s annual bonus plan, with bonus payable based on the achievement of pre-approved financial and/or business performance objectives that support business plans and strategic goals;	

3.	participates in UGI Corporation’s long-term compensation plans, UGI Corporation’s 2004 Omnibus Equity Compensation Plan, as amended, and UGI Corporation’s 2013 Omnibus Incentive Compensation Plan, with annual awards as determined by the UGI Corporation Compensation and Management Development Committee;	

4.	will receive cash benefits upon termination of his employment without cause following a change in control of UGI Corporation; and	

5.	participates in UGI Corporation’s benefit plans, including the UGI Pension Plan, Senior Executive Employee Severance Plan, Supplemental Executive Retirement Plan, UGI Savings Plan, and Supplemental Savings Plan.	

                 

UGI CORPORATION 
 DESCRIPTION OF COMPENSATION ARRANGEMENT
FOR 
 KIRK R. OLIVER
Kirk R. Oliver is Chief Financial Officer of UGI Corporation. Mr. Oliver has an oral compensation arrangement with UGI Corporation which includes the following:
Mr. Oliver:

1.	is entitled to an annual base salary, which for fiscal year 2013 was $515,000;	

2.	participates in UGI Corporation’s annual bonus plan, with bonus payable based on the achievement of pre-approved financial and/or business performance objectives that support business plans and strategic goals;	

3.	participates in UGI Corporation’s long-term compensation plans, UGI Corporation’s 2004 Omnibus Equity Compensation Plan, as amended, and UGI Corporation’s 2013 Omnibus Incentive Compensation Plan, with annual awards as determined by the UGI Corporation Compensation and Management Development Committee;	

4.	will receive cash benefits upon termination of his employment without cause following a change in control of UGI Corporation; and	

5.	participates in UGI Corporation’s benefit plans, including the Senior Executive Employee Severance Plan, 2009 Supplemental Executive Retirement Plan for New Employees, and UGI Savings Plan.	

                 

UGI CORPORATION 
 DESCRIPTION OF COMPENSATION ARRANGEMENT
FOR 
 MONICA M. GAUDIOSI
Monica M. Gaudiosi is Vice President, General Counsel and Secretary of UGI Corporation. Ms. Gaudiosi has an oral compensation arrangement with UGI Corporation which includes the following:
Ms. Gaudiosi:

1.	is entitled to an annual base salary, which for fiscal year 2013 was $408,044;	

2.	participates in UGI Corporation’s annual bonus plan, with bonus payable based on the achievement of pre-approved financial and/or business performance objectives that support business plans and strategic goals;	

3.	participates in UGI Corporation’s long-term compensation plans, UGI Corporation’s 2004 Omnibus Equity Compensation Plan, as amended, and UGI Corporation’s 2013 Omnibus Incentive Compensation Plan, with annual awards as determined by the UGI Corporation Compensation and Management Development Committee;	

4.	will receive cash benefits upon termination of her employment without cause following a change in control of UGI Corporation; and	

5.	participates in UGI Corporation’s benefit plans, including the Senior Executive Employee Severance Plan, 2009 Supplemental Executive Retirement Plan for New Employees, and UGI Savings Plan.	

                 

UGI CORPORATION 
 DESCRIPTION OF COMPENSATION ARRANGEMENT
FOR 
 BRADLEY C. HALL
Bradley C. Hall is Vice President – New Business Development of UGI Corporation. Mr. Hall has an oral compensation arrangement with UGI Corporation which includes the following:
Mr. Hall:

1.	is entitled to an annual base salary, which for fiscal year 2013 was $358,254;	

2.	participates in UGI Corporation’s annual bonus plan, with bonus payable based on the achievement of pre-approved financial and/or business performance objectives that support business plans and strategic goals;	

3.	participates in UGI Corporation’s long-term compensation plans, UGI Corporation’s 2004 Omnibus Equity Compensation Plan, as amended, and UGI Corporation’s 2013 Omnibus Incentive Compensation Plan, with annual awards as determined by the Compensation and Management Development Committee;	

4.	will receive cash benefits upon termination of his employment without cause following a change in control of UGI Corporation; and	

5.	participates in UGI Corporation’s benefit plans, including the UGI Pension Plan, Senior Executive Employee Severance Plan, Supplemental Executive Retirement Plan, UGI Savings Plan, and Supplemental Savings Plan.	

EXHIBIT 10.39

UGI CORPORATION
SUMMARY OF DIRECTOR COMPENSATION

The table below shows the components of director compensation effective October 1, 2013. A director who is an officer or employee of the Registrant or its subsidiaries is not compensated for service on the Board of Directors or on any Committee of the Board.

DIRECTORS' COMPENSATION

CASH        EQUITY
COMPONENT          COMPONENT (1) (2)  

Annual Retainer for Non-Employee        $77,000         2,800 Stock Units
Directors (except Mr. Greenberg)
8,500 Options for the purchase of shares of common stock of the Registrant.

Annual Retainer for Non-Executive        $200,000
Chairman (pro-rated for the number
of months served in Fiscal 2013) (3)         

Additional Annual Retainer for         $5,000
Audit Committee Members
(other than the Chairperson)            

Additional Annual Retainer for         $15,000
Audit Committee Chairperson        

Additional Annual Retainer for         $15,000
Compensation and Management
Development Committee Chairperson        

Additional Annual Retainer for         $10,000
Corporate Governance Committee
Chairperson                

Additional Annual Retainer for         $7,500
Safety, Environmental and Regulatory
Compliance Committee Chairperson        

Additional Annual Retainer for        $20,000
Presiding Director                 

		
(1)	Stock Units and Options are granted under the UGI Corporation 2004 Omnibus Equity Compensation Plan Amended and Restated as of December 5, 2006 and the UGI Corporation 2013 Omnibus Incentive Compensation Plan.	

(2)	Stock Units and Stock Options to be awarded January 2014.	

(3)	Mr. Greenberg will not receive any equity compensation for his services as Non-Executive Chairman.	

EXHIBIT 10.72

AMENDMENT NO. 13
Dated as of October 1, 2013
to
RECEIVABLES PURCHASE AGREEMENT
Dated as of November 30, 2001
This AMENDMENT NO. 13 (this “ Amendment ”) dated as of October 1, 2013 is entered into among ENERGY SERVICES FUNDING CORPORATION, a Delaware corporation, as the seller (the “ Seller ”), UGI ENERGY SERVICES, LLC (as successor to UGI Energy Services, Inc.), a Pennsylvania limited liability company (“ UGI ”), as initial servicer (in such capacity, together with its successors and permitted assigns in such capacity, the “ Servicer ”), MARKET STREET FUNDING LLC, a Delaware limited liability company (“ Market Street ”), as issuer (together with its successors and permitted assigns, the “ Issuer ”) , as Assignor (as defined below), and PNC BANK, NATIONAL ASSOCIATION, a national banking association (“ PNC ”), as administrator (in such capacity, together with its successors and assigns in such capacity, the “ Administrator ”) and as Assignee (as defined below).
RECITALS
WHEREAS, the parties hereto have entered into that certain Receivables Purchase Agreement, dated as of November 30, 2001 (as amended, supplemented or otherwise modified from time to time, the “ Agreement ”);
WHEREAS, Market Street, as the assignor (in such capacity, the “ Assignor ”), desires to sell, assign and delegate to PNC, as the assignee (in such capacity, the “ Assignee ”), all of the Assignor’s rights under, interest in, title to and obligations under the Agreement and the other Transaction Documents (collectively, the “ Assigned Documents ”), and the Assignee desires to purchase and assume from the Assignor all of the Assignor’s rights under, interest in, title to and obligations under the Assigned Documents;
WHEREAS, after giving effect to the assignment and assumption contemplated in Section 2 of this Amendment, each of the parties hereto desires that Market Street cease to be a party to the Agreement and each of the other Assigned Documents to which it is a party and to be discharged from its duties and obligations as the Issuer or otherwise under the Agreement and each of the other Assigned Documents;
WHEREAS, effective as of the date hereof, (i) UGI Energy Services, Inc. will merge with and into UGI Newco, LLC, a Pennsylvania limited liability company (“ Newco ”), with Newco being the surviving entity and (ii) Newco will amend its name from “UGI Newco, LLC” to “UGI Energy Services, LLC” (such transaction, collectively, the “ Subject Event ”); and
WHEREAS, the parties hereto wish to amend the Agreement as set forth herein;
NOW, THEREFORE, in consideration of the promises and the mutual agreements contained herein and in the Agreement, the parties hereto agree as follows:

SECTION 1. Definitions . All capitalized terms used but not otherwise defined herein are used herein as defined in the Agreement.
SECTION 2.      Assignment and Assumption .
(a) Sale and Assignment by Assignor to Assignee . At or before 2:00 pm (New York time) on the date hereof, the Assignee shall pay to the Assignor, in immediately available funds, (i) the amount set forth on Schedule I hereto (such amount, the “ Capital Payment ”) representing 100.00% of the aggregate Capital of the Assignor under the Agreement on the date hereof and (ii) the amount set forth on Schedule I hereto representing all accrued but unpaid (whether or not then due) Discount, fees and other costs and expenses payable in respect of such Capital to but excluding the date hereof (such amount, the “ CP Costs and Other Costs ”; together with the Capital Payment, collectively, the “ Payoff Amount ”). Upon the Assignor’s receipt of the Payoff Amount in its entirety, the Assignor hereby sells, transfers, assigns and delegates to the Assignee, without recourse, representation or warranty except as otherwise provided herein, and the Assignee hereby irrevocably purchases, receives, accepts and assumes from the Assignor, all of the Assignor’s rights under, interest in, title to and all its obligations under the Agreement and the other Assigned Documents. Without limiting the generality of the foregoing, the Assignor hereby assigns to the Assignee all of its right, title and interest in the Purchased Interest.
Payment of each portion of the Payoff Amount shall be made by wire transfer of immediately available funds in accordance with the payment instructions set forth on Schedule II hereto.
(a)      Removal of Assignor . From and after the Effective Date (as defined below), the Assignor shall cease to be a party to the Agreement and each of the other Assigned Documents to which it was a party and shall no longer have any rights or obligations under the Agreement or any other Assigned Document (other than such rights which by their express terms survive termination thereof).
(b)      Limitation on Liability . Notwithstanding anything to the contrary set forth in this Amendment, the Assignee does not accept or assume any liability or responsibility for any breach, failure or other act or omission on the part of the Assignor, or any indemnification or other cost, fee or expense related thereto, in each case which occurred or directly or indirectly arose out of an event which occurred prior to the Effective Date.
(c)      Assumption . From and after the Effective Date, UGI hereby (i) unconditionally assumes all of UGI Energy Services, Inc.’s rights, duties and obligations under the Agreement and each of the other Transaction Documents and (ii) agrees to be bound by all of the terms and conditions of the Agreement and the Transaction Documents applicable to UGI Energy Services, Inc.

	

(d)      Acknowledgement and Agreement .    Each of the parties and signatories hereto (i) hereby acknowledges and agrees to the sale, assignment and assumptions set forth in clauses (a) and (d) above and (ii) expressly waives any notice or other applicable requirements set forth in any Transaction Document as a prerequisite or condition precedent to such sale, assignment and assumptions (other than as set forth herein).
SECTION 3.      Joinder .
(a)      PNC as Issuer . From and after the date hereof, PNC shall be the Issuer under the Agreement for all purposes thereof and of the other Transaction Documents as if PNC were an original party to the Agreement in such capacity, and PNC assumes all related rights and agrees to be bound by all of the terms and provisions applicable to the Issuer contained in the Agreement and the other Transaction Documents.
(b)      Consent to Joinder . Each of the parties hereto consents to the foregoing joinder of PNC as a party to the Agreement in the capacity of the Issuer, and any otherwise applicable conditions precedent thereto under the Agreement and the other Transactions Documents (other than as set forth herein) are hereby waived.
SECTION 4.      Notice; Consent .
(a)      Notice . UGI hereby provides notice of UGI Energy Services, Inc.’s intent to perform and consummate the Subject Event on the date hereof and requests that each of the parties hereto acknowledge and consent to such merger and name change effective as of the date hereof.
(b)      Consent . Subject to terms and conditions set forth in this Amendment, each of the parties hereto hereby: (i) acknowledges such notice set forth in clause (a) above, (ii) consents to the Subject Event on the date hereof and (iii) waives any notice requirement with respect to the Subject Event set forth in the Agreement or any other Transaction Document.
SECTION 5.      Amendments to the Agreement . The Agreement is hereby amended to incorporate the changes shown on the marked pages to the Agreement attached hereto as Exhibit A .
SECTION 6.      Certain Representations, Warranties and Covenants . Each of the Seller, UGI and the Servicer, as to itself, hereby represents and warrants that:
(c)      the representations and warranties of such Person contained in Exhibit III to the Agreement (as amended hereby) are true and correct as of the date hereof (unless stated to relate solely to an earlier date, in which case such representations and warranties were true and correct as of such earlier date);
(d)      the execution and delivery by such Person of this Amendment, and the performance of its obligations under this Amendment and the Agreement (as amended hereby) are within its organizational powers and have been duly authorized by all necessary

	

organizational action on its part, and this Amendment and the Agreement (as amended hereby) are its valid and legally binding obligations, enforceable in accordance with its terms, subject to the effect of bankruptcy, insolvency, reorganization or other similar laws affecting the enforcement of creditors’ rights generally; and
(e)      no Termination Event or Unmatured Termination Event has occurred, is continuing, or would occur as a result of this Amendment.
SECTION 7.      Effectiveness . This Amendment shall become effective as of the date (such date, the “ Effective Date ”) when (a) the Administrator shall have received counterparts of (i) this Amendment (whether by facsimile or otherwise), (ii) that certain Amendment No. 4 to Purchase and Sale Agreement, dated as of the date hereof, between UGI and the Seller and (iii) that certain Ninth Amended and Restated Fee Letter, dated as of the date hereof, among certain of the parties hereto (whether by facsimile or otherwise), in each case, executed and delivered by each of the parties hereto or thereto, as applicable, (b) the Administrator shall have received (i) a certificate of the Secretary or Assistant Secretary of UGI certifying the names and true signatures of its officers who are authorized to sign this Amendment and the other Transaction Documents, (ii) certified copies of: (A) the resolutions of the Board of Managers of UGI authorizing the execution, delivery and performance by UGI, of this Amendment, the Agreement and the other Transaction Documents to which it is a party and (B) the certificate of organization and the limited liability company operating agreement of UGI, (iii) a present subsistence certificate with respect to UGI issued by the Secretary of the Commonwealth of Pennsylvania and (iv) completed UCC search reports, dated on or shortly before the date hereof, with respect to UGI and Newco and (c) the Assignor shall have received the Payoff Amount in its entirety in accordance with Section 2 of this Amendment.
SECTION 8.      References to Agreement . Upon the effectiveness of this Amendment, each reference in the Agreement to “this Agreement”, “hereunder”, “hereof”, “herein”, or words of like import shall mean and be a reference to the Agreement as amended hereby, and each reference to the Agreement in any other document, instrument or agreement executed and/or delivered in connection with the Agreement shall mean and be a reference to the Agreement as amended hereby.
SECTION 9.      Effect on the Agreement . Except as specifically amended above, the Agreement and all other documents, instruments and agreements executed and/or delivered in connection therewith shall remain in full force and effect and are hereby ratified and confirmed.
SECTION 10.      Further Assurances . Each of the Seller and the Servicer hereby agrees to do all such things and execute all such documents and instruments, at the Seller’s sole expense, as the Assignee may reasonably consider necessary or desirable to give effect to the assignment and assumption set forth in Section 2 of this Amendment.
SECTION 11.      No Proceedings . Each of the parties hereto hereby covenants and agrees that it will not institute against, or join any other Person in instituting against, Market Street any bankruptcy, reorganization, arrangement, insolvency or liquidation proceeding, or other proceeding under any federal or state bankruptcy or similar law, for one year and one day after the latest maturing Note issued by Market Street is paid in full. The provisions of this Section 11 shall survive any termination of the Agreement.

	

SECTION 12.      No Waiver . The execution, delivery and effectiveness of this Amendment shall not operate as a waiver of any right, power or remedy of any party under the Agreement or any other document, instrument or agreement executed in connection therewith, nor constitute a waiver of any provision contained therein, except as specifically set forth herein.
SECTION 13.      Governing Law . THIS AMENDMENT, INCLUDING THE RIGHTS AND DUTIES OF THE PARTIES HERETO, SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE INTERNAL LAWS OF THE STATE OF NEW YORK (INCLUDING FOR SUCH PURPOSE SECTION 5-1401 AND 5-1402 OF THE GENERAL OBLIGATIONS LAW OF THE STATE OF NEW YORK).
SECTION 14.      Successors and Assigns . This Amendment shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors and assigns.
SECTION 15.      Headings . The Section headings in this Amendment are inserted for convenience of reference only and shall not affect the meaning or interpretation of this Amendment or any provision hereof.
SECTION 16.      Counterparts . This Amendment may be executed by the parties hereto in several counterparts, each of which shall be deemed to be an original and all of which shall constitute together but one and the same agreement. Delivery of an executed counterpart of a signature page to this Amendment by facsimile or electronic transmission shall be effective as delivery of a manually executed counterpart hereof.
SECTION 17.      Severability . Each provision of this Amendment shall be severable from every other provision of this Amendment for the purpose of determining the legal enforceability of any provision hereof, and the unenforceability of one or more provisions of this Amendment in one jurisdiction shall not have the effect of rendering such provision or provisions unenforceable in any other jurisdiction.
SECTION 18.      Consent . Each of the parties hereto hereby consents to the filing, by or on behalf of UGI and at the sole expense of the Seller, of the UCC-1 Financing Statement in substantially the form attached hereto as Exhibit B , upon consummation of the Subject Event.
[Signature Pages Follow]

IN WITNESS WHEREOF, the parties have caused this Amendment to be executed by their respective officers thereunto duly authorized as of the date first above written.
ENERGY SERVICES FUNDING CORPORATION

By:       /s/ Angela K. Rodriguez    
Name:    Angela K. Rodriguez

	

Title:    Assistant Treasurer

UGI ENERGY SERVICES, LLC

By:       /s/ Angela K. Rodriguez    
Name:    Angela K. Rodriguez
		
Title:	Vice President and
Chief Financial Officer	

MARKET STREET FUNDING LLC ,
as Assignor

By :       /s/ Doris J. Hearn    
Name:    Doris J. Hearn
Title:    Vice President

PNC BANK, NATIONAL ASSOCIATION ,
as Administrator and Assignee

By:       /s/ Mark Falcione _________________
Name:    Mark Falcione
Title:    Executive Vice President

SCHEDULE I

ASSIGNMENTS AND PAYMENT AMOUNTS

	
			
 	Schedule I	 	

SCHEDULE II

WIRING INSTRUCTIONS

Wiring instructions with respect to amounts payable to the Assignor:

	
		
Bank Name:	 	
ABA #:	 	
Account #:	 	
Account Name:	 	
Reference:	 	

	
			
 	Schedule II	 	

EXHIBIT A
(attached)

Conformed to Amendment #1 dated August 29, 2003
Conformed to Amendment #2 dated January 29, 2004
Conformed to Amendment #3 dated August 30, 2004
Conformed to Amendment #4 dated November 1, 2005
Conformed to Amendment #5 dated April 24, 2006
Conformed to Amendment #6 dated September 5, 2006
Conformed to Amendment #7 dated April 23, 2009
Conformed to Amendment #8 dated April 22, 2010
Conformed to Amendment #9 dated August 26, 2010
Conformed to Amendment #10 dated April 21, 2011
Conformed to Amendment #11 dated April 19, 2012
Conformed to Amendment #12 dated April 18, 2013

EXECUTION COPY EXHIBIT A to Amendment #13 dated October 1, 2013

RECEIVABLES PURCHASE AGREEMENT

dated as of November 30, 2001 among
ENERGY SERVICES FUNDING CORPORATION

UGI ENERGY SERVICES, INC. LLC

MARKET STREET FUNDING CORPORATION

and

PNC BANK, NATIONAL ASSOCIATION

This RECEIVABLES PURCHASE AGREEMENT (as amended, supplemented or otherwise modified from time to time, this “ Agreement ”) is entered into as of November 30,
2001, among ENERGY SERVICES FUNDING CORPORATION, a Delaware corporation, as seller (the “ Seller ”), UGI ENERGY SERVICES, INC. LLC (as successor to UGI Energy Services, Inc.) , a Pennsylvania corporation limited liability company (“ UGI ”), as initial servicer (in such capacity, together with its successors and permitted assigns in such capacity, the “ Servicer ”) , MARKET STREET FUNDING CORPORATION, a Delaware corporation (together with its successors and permitted assigns, the “ Issuer ”) , and PNC BANK, NATIONAL ASSOCIATION, a national banking association (“ PNC ”), as issuer (together with its successors and permitted assigns, the “Issuer”) and as administrator (in such capacity, together with its successors and assigns in such capacity, the “ Administrator ”).

PRELIMINARY STATEMENTS. Certain terms that are capitalized and used throughout this Agreement are defined in Exhibit I . References in the Exhibits hereto to the “Agreement” refer to this Agreement.

The Seller desires to sell, transfer and assign an undivided variable percentage interest in a pool of receivables, and the Issuer desires to acquire such undivided variable percentage interest, as such percentage interest shall be adjusted from time to time based upon, in part, reinvestment payments that are made by the Issuer.

In consideration of the mutual agreements, provisions and covenants contained herein, the parties hereto agree as follows:

ARTICLE I.
AMOUNTS AND TERMS OF THE PURCHASES

Section 1.1 Purchase Facility . (a) On the terms and conditions hereinafter set forth, the Issuer hereby agrees to purchase, and make reinvestments of, undivided percentage ownership interests with regard to the Purchased Interest from the Seller from time to time from December
4, 2001 to the Facility Termination Date. Under no circumstances shall the Issuer make any such purchase or reinvestment if, after giving effect to such purchase or reinvestment, the aggregate outstanding Capital of the Purchased Interest would exceed the Purchase Limit.

(b) The Seller may, upon at least 60 days’ written notice to the Administrator, terminate the Purchase Facility provided in this Section in whole or, upon at least 30 days’ written notice to the Administrator, from time to time, irrevocably reduce in part the unused portion of the Purchase Limit; provided , that, so long as the Credit Agreement is in effect, the Seller’s right to terminate the Purchase Facility in whole pursuant to this Section 1.1(b) is conditioned upon the Seller exercising its option to repurchase in full (but not in part) the Purchased Interest in accordance with the terms of Section 5.14 ; provided , further , that each partial reduction shall be in the amount of at least $5,000,000, or an integral multiple of $1,000,000 in excess thereof, and that, unless terminated in whole, the Purchase Limit shall in no event be reduced below
$20,000,000.

Section 1.2 Making Purchases . (a) Each purchase (but not reinvestment) of undivided percentage ownership interests with regard to the Purchased Interest hereunder shall be made

(iii) the Servicer shall hold such Collections in trust for the Issuer, for payment to the Administrator on (1) solely with respect to any reduction described in subsections (f)(i)(B) or (f)(i)(C) the next Weekly Settlement Date, or (2) with respect to any reduction described in subsection (f)(i)(A) , such other date with at least one (1) Business Day prior written notice to the Administrator of such payment, and the Capital shall be deemed reduced in the amount to be paid to the Administrator only when in fact finally so paid;

provided , that the amount of any such reduction shall be not less than $1,000,000 and shall be an integral multiple of $100,000.

Section 1.5 Fees . The Seller shall pay to the Administrator certain fees in the amounts and on the dates set forth in a fee letter, dated the date hereof, among UGI, the Seller and the Administrator (as such letter agreement may be amended, supplemented or otherwise modified from time to time, the “ Fee Letter ”).

Section 1.6 Payments and Computations, Etc . (a) All amounts to be paid or deposited by the Seller or the Servicer hereunder shall be made without reduction for offset or counterclaim and shall be paid or deposited no later than noon (New York City time) on the day when due in same day funds to the Administration Account. All amounts received after noon (New York City time) will be deemed to have been received on the next Business Day.

(b) The Seller or the Servicer, as the case may be, shall, to the extent permitted by applicable law, pay interest on any amount not paid or deposited by the Seller or the Servicer, as the case may be, when due hereunder, at an interest rate equal to 3.00% per annum above the Base Rate, payable on demand.

(c) All computations of interest under clause (b) and all computations of Discount, fees and other amounts hereunder shall be made on the basis of a year of 360 (or 365 or 366, as applicable, with respect to Discount or other amounts calculated by reference to the Base Rate) days for the actual number of days elapsed. Whenever any payment or deposit to be made hereunder shall be due on a day other than a Business Day, such payment or deposit shall be made on the next Business Day and such extension of time shall be included in the computation of such payment or deposit.

Section 1.7 Increased Costs . (a) If the Administrator, the Issuer , any Purchaser, any other Program Support Provider or any of their respective Affiliates (each an “ Affected Person ”) reasonably determines that the existence of or compliance with: (i) any law or regulation or any change therein or in the interpretation or application thereof by a Governmental Authority, in each case adopted, issued or occurring after the date hereof, or (ii) any request, guideline or directive from any central bank or other Governmental Authority (whether or not having the force of law) issued or occurring after the date of this Agreement, affects or would affect the amount of capital required or expected to be maintained by such Affected Person, and such Affected Person reasonably determines that the amount of such capital is increased by or based upon the existence of any commitment to make purchases of (or otherwise to maintain the investment in) Pool Receivables related to this Agreement or any related liquidity facility, credit enhancement facility and other commitments of the same type related to this Agreement, then, upon demand by such Affected Person (with a copy to the Administrator), the Seller shall

promptly pay to the Administrator, for the account of such Affected Person, from time to time as specified by such Affected Person, additional amounts sufficient to compensate such Affected Person in the light of such circumstances, to the extent that such Affected Person reasonably determines such increase in capital to be allocable to the existence of any of such commitments. A certificate as to such amounts submitted to the Seller and the Administrator by such Affected Person shall be conclusive and binding for all purposes, absent manifest error.

(b) If, due to either: (i) the introduction of or any change in or in the interpretation of any law or regulation by any Governmental Authority occurring after the date hereof or (ii) compliance with any guideline or request from any central bank or other Governmental Authority (whether or not having the force of law), there shall be any increase in the cost to any Affected Person of agreeing to purchase or purchasing, or maintaining the ownership of, the Purchased Interest in respect of which Discount is computed by reference to the Euro-Rate LMIR , then, upon demand by such Affected Person, the Seller shall promptly pay to such Affected Person, from time to time as specified by such Affected Person, additional amounts sufficient to compensate such Affected Person for such increased costs. A certificate as to such amounts submitted to the Seller and the Administrator by such Affected Person shall be conclusive and binding for all purposes, absent manifest error.

(c) If such increased costs affect the related Affected Person’s portfolio of financing transactions, such Affected Person shall use reasonable averaging and attribution methods to allocate such increased costs to the transactions contemplated by this Agreement.

(d) The Administrator will make reasonable efforts to cause the interest of any Affected Party (other than the Issuer or its domestic Affiliates) that makes a claim under this Section 1.7 to be transferred to a party that is not subject to increased costs under this Section 1.7 ; provided that neither the Administrator nor any of its Affiliates shall be required hereunder to itself accept such transferred interest.

(e) Notwithstanding any language in this Section 1.7 to the contrary, nothing in this Section 1.7 shall be construed as requiring the Seller to make any payments attributable to or in respect of any tax of any kind whatsoever imposed upon or required to be withheld or deducted from payments to any Affected Person.

Section 1.8 Requirements of Law . If any Affected Person reasonably determines that the existence of or compliance with: (a) any law or regulation or any change therein or in the interpretation or application thereof, in each case adopted, issued or occurring after the date hereof, or (b) any request, guideline or directive from any central bank or other Governmental Authority (whether or not having the force of law) issued or occurring after the date of this Agreement:

(i) does or shall subject such Affected Person to any tax of any kind whatsoever with respect to this Agreement, any increase in the Purchased Interest or in the amount of Capital relating thereto, or does or shall change the basis of taxation of payments to such Affected Person on account of Collections, Discount or any other amounts payable hereunder (excluding taxes imposed on the overall or branch pre-tax net income of such Affected Person, and franchise taxes imposed on such Affected Person by the jurisdiction

under the laws of which such Affected Person is organized or otherwise is considered doing business (unless the Affected Person would not be considered doing business in such jurisdiction, but for having entered into, or engaged in the transactions in connection with, this Agreement or any other Transaction Document) or a political subdivision thereof,

(ii) does or shall impose, modify or hold applicable any reserve, special deposit, compulsory loan or similar requirement against assets held by, or deposits or other liabilities in or for the account of, purchases, advances or loans by, or other credit extended by, or any other acquisition of funds by, any office of such Affected Person that are not otherwise included in the determination of the Euro-Rate LMIR or the Base Rate hereunder, or

(iii) does or shall impose on such Affected Person any other condition, and the result of any of the foregoing is: (A) to increase the cost to such Affected Person of acting as Administrator, or of agreeing to purchase or purchasing or maintaining the ownership of undivided percentage ownership interests with regard to the Purchased Interest (or interests therein) or any Portion of Capital, or (B) to reduce any amount receivable hereunder (whether directly or indirectly), then, in any such case, without duplication to any amounts paid or payable pursuant to Section 1.7 or Section 3.1 upon demand by such Affected Person, the Seller shall promptly pay to such Affected Person additional amounts necessary to compensate such Affected Person for such additional cost or reduced amount receivable. All such amounts shall be payable as incurred. A certificate from such Affected Person to the Seller and the Administrator certifying, in reasonably specific detail, the basis for, calculation of, and amount of such additional costs or reduced amount receivable shall be conclusive and binding for all purposes, absent manifest error; provided, however, that no Affected Person shall be required to disclose any confidential or tax planning information in any such certificate.

Section 1.9 Inability to Determine Euro-Rate LMIR . (a) If the Administrator determines before the first day of on any Settlement Period day (which determination shall be final and conclusive) that, by reason of circumstances affecting the interbank eurodollar market generally, deposits in dollars (in the relevant amounts for such Settlement Period day ) are not being offered to banks in the interbank eurodollar market for such Settlement Period day , or adequate means do not exist for ascertaining the Euro-Rate LMIR for such Settlement Period day , then the Administrator shall give notice thereof to the Seller. Thereafter, until the Administrator notifies the Seller that the circumstances giving rise to such suspension no longer exist, (i) no Portion of Capital shall be funded at the Alternate Rate determined by reference to the Euro-Rate LMIR and (ii) the Discount for any outstanding Portions of Capital then funded at the Alternate Rate determined by reference to the Euro-Rate shall, on the last day of the then current Settlement Period, LMIR shall immediately be converted to the Alternate Rate determined by reference to the Base Rate.

(b) If, on or before the first day of any Settlement Period any day , the Administrator shall have been notified by any Purchaser the Issuer that such Purchaser the Issuer has determined (which determination shall be final and conclusive) that any enactment, promulgation or adoption of or any change in any applicable law, rule or regulation, or any change in the interpretation or

administration thereof by a Governmental Authority, central bank or comparable agency charged with the interpretation or administration thereof, or compliance by such Purchaser the Issuer with any guideline, request or directive (whether or not having the force of law) of any such authority, central bank or comparable agency shall make it unlawful or impossible for such Purchaser the Issuer to fund or maintain any Portion of Capital at the Alternate Rate and based upon the Euro-Rate LMIR , the Administrator shall notify the Seller thereof. Upon receipt of such notice, until the Administrator notifies the Seller that the circumstances giving rise to such determination no longer apply, (i) no Portion of Capital shall be funded at the Alternate Rate determined by reference to the Euro-Rate LMIR and (ii) the Discount for any outstanding Portions of Capital then funded at the Alternate Rate determined by reference to the Euro-Rate LMIR shall immediately be converted to the Alternate Rate determined by reference to the Base Rate either (A) on the last day of the then current Settlement Period if such Purchaser may lawfully continue to maintain such Portion of Capital at the Alternate Rate determined by reference to the Euro-Rate to such day, or (B) immediately, if such Purchaser may not lawfully continue to maintain such Portion of Capital at the Alternate Rate determined by reference to the Euro-Rate to such day .

ARTICLE II.
REPRESENTATIONS AND WARRANTIES; COVENANTS; TERMINATION EVENTS

Section 2.1 Representations and Warranties; Covenants . Each of the Seller, UGI and the Servicer hereby makes the representations and warranties, and hereby agrees to perform and observe the covenants, applicable to it set forth in Exhibits III , IV and VI , respectively.

Section 2.2 Termination Events . If any of the Termination Events set forth in Exhibit V shall occur, the Administrator may, by notice to the Seller, declare the Facility Termination Date to have occurred (in which case the Facility Termination Date shall be deemed to have occurred); provided, that automatically upon the occurrence of any event (without any requirement for the passage of time or the giving of notice) described in paragraph (f) of Exhibit V , the Facility Termination Date shall occur. Upon any such declaration, occurrence or deemed occurrence of the Facility Termination Date, the Issuer and the Administrator shall have, in addition to the rights and remedies that they may have under this Agreement, all other rights and remedies provided after default under the New York UCC and under other applicable law, which rights and remedies shall be cumulative.

ARTICLE III. INDEMNIFICATION

Section 3.1 Indemnities by the Seller . Without limiting any other rights that the Administrator, the Issuer , any Program Support Provider or any of their respective Affiliates, employees, officers, directors, agents, counsel, successors, transferees or assigns (each, an “ Indemnified Party ”) may have hereunder or under applicable law, the Seller hereby agrees to indemnify each Indemnified Party from and against any and all claims, damages, expenses, costs, losses and liabilities (including Attorney Costs) (all of the foregoing being collectively referred to as “ Indemnified Amounts ”) incurred by any Indemnified Party arising out of or resulting from this Agreement (whether directly or indirectly), the use of proceeds of purchases or

expenses incurred by such successor Servicer in connection with the performance of its obligations as Servicer.

ARTICLE V. MISCELLANEOUS

Section 5.1 Amendments, Etc . No amendment or waiver of any provision of this Agreement or any other Transaction Document, or consent to any departure by the Seller or the Servicer therefrom, shall be effective unless in a writing signed by the Administrator, and, in the case of any amendment, by the other parties thereto; and then such amendment, waiver or consent shall be effective only in the specific instance and for the specific purpose for which given. No failure on the part of the Issuer or the Administrator to exercise, and no delay in exercising any right hereunder shall operate as a waiver thereof, nor shall any single or partial exercise of any right hereunder preclude any other or further exercise thereof or the exercise of any other right.

Section 5.2 Notices, Etc . (a) All notices and other communications provided for
hereunder shall, unless otherwise stated herein, be in writing (including facsimile communication) and shall be personally delivered or sent by certified mail, postage prepaid, via nationally recognized courier or by facsimile, to the intended party at the mailing address or facsimile number of such party set forth under its name on the signature pages hereof or at such other address or facsimile number as shall be designated by such party in a written notice to the other parties hereto. All such notices and communications shall be effective (i) if personally delivered, when received, (ii) if sent by certified mail three (3) Business Days after having been deposited in the mail, postage prepaid, (iii) if via nationally recognized courier for delivery the next Business Day, and (iv) if transmitted by facsimile, when sent, receipt confirmed by telephone or electronic means (and shall be followed by a hard copy sent by first class mail).

Section 5.3 Assignability . (a) This Agreement and the Issuer’s rights and obligations herein (including ownership of the Purchased Interest or an interest therein) shall be assignable, in whole or in part, by the Issuer and its successors and assigns with the prior written consent of the Seller; provided , however , that such consent shall not be unreasonably withheld; and provided further , that no such consent shall be required if the assignment is made to PNC, any Affiliate of PNC (other than a director or officer of PNC) , any Purchaser or other Program Support Provider, or any Person that is (i) in the business of issuing Notes and (ii) administered by PNC or any Affiliate of PNC. Each assignor may, in connection with the assignment, disclose to the applicable assignee (that shall have agreed to be bound by Section 5.6 ) any information relating to the Servicer, the Seller or the Pool Receivables furnished to such assignor by or on behalf of the Servicer, the Seller, the Issuer or the Administrator. The Administrator shall give prior written notice of any assignment of the Issuer’s rights and obligations (including ownership of the Purchased Interest to any Person other than a Program Support Provider ).

(b) The Issuer may at any time grant to one or more banks or other institutions (each a “Purchaser”) party to the Liquidity Agreement, or to any other Program Support Provider, participating interests in the Purchased Interest; provided , however , that in the case of any such grant to PNC or any Affiliate of PNC, the Seller shall have approved such Purchaser at the time such Purchaser became a party to the Liquidity Agreement (such approval to not be unreasonably

withheld). In the event of any such grant by the Issuer of a participating interest to a Purchaser or other Program Support Provider, the Issuer shall remain responsible for the performance of its obligations hereunder. The Seller agrees that each Purchaser or other Program Support Provider shall be entitled to the benefits of Sections 1.7 and 1.8 . [Reserved].

(c) This Agreement and the rights and obligations of the Administrator hereunder shall be assignable, in whole or in part, by the Administrator and its successors and assigns; provided , that unless: (i) such assignment is to an Affiliate of PNC, (ii) it becomes unlawful for PNC to serve as the Administrator or (iii) a Termination Event exists, the Seller has consented to such assignment, which consent shall not be unreasonably withheld.

(d) Except as provided in Section 4.1(d) , none of the Seller, UGI or the Servicer may assign its rights or delegate its obligations hereunder or any interest herein without the prior written consent of the Administrator.

(e) Without limiting any other rights that may be available under applicable law, the rights of the Issuer may be enforced through it or by its agents.

(f) Each of (A) the Issuer, (B) its successors and assigns , (C) any Program Support Provider, (D and (C ) any assignee under Section 5.3(a) and (E) any recipient of a participating interest under Section 5.3(b) that, in each case, is not a United States Person (as such term is defined in Section 7701(a)(30) of the United States Internal Revenue Code of 1986, as amended) for United States federal tax purposes shall deliver to the Seller, with a copy to the Servicer, a United States Internal Revenue Service Form W-8BEN or W-8ECI (or successor form) properly completed and certifying in each case that the party delivering such form is entitled to a complete exemption from withholding or deduction for or on account of any United States federal income taxes with respect to amounts derived, directly or indirectly, in connection with this Agreement. The Issuer, if required to deliver such form, shall deliver such form on the Closing Date. A party described in any of the foregoing clauses (B) through or ( E C ) shall deliver such form concurrently with such party becoming described in any of such clauses. Each party obligated to deliver a form under the first sentence of this Section 5.3(f) shall, to the extent permitted by law, further deliver to the Seller, with a copy to the Servicer, a United States Internal Revenue Service Form W-8BEN or W-8ECI (or successor form) on or before the date that any such form expires or becomes obsolete or after the occurrence of any event requiring a change in the most recent form previously delivered by such party to the Seller, properly completed and certifying in each case that the party delivering such form is entitled to a complete exemption from withholding or deduction for or on account of any United States federal income taxes with respect to amounts derived, directly or indirectly, in connection with this Agreement.    The Seller shall not be required to pay to or on behalf of any party described in the foregoing clauses (A) through ( E C ) any additional amount under Section 1.8 or Section 3.1 attributable to any tax, duty, levy or other charge of any kind whatsoever imposed upon or required to be withheld or deducted from payments to any such party if such party shall have failed to satisfy the requirements of this Section 5.3(f) ; provided that  nothing in this Section 5.3(f)  shall relieve the Seller of any obligation to pay additional amounts under Section 1.8 or Section 3.1 if, as a result of a change in treaty, law or regulation or the interpretation or application thereof, adopted, issued or occurring after the satisfaction by such party of such requirements, such party is no longer properly entitled to deliver Form W-8BEN or Form W-8ECI (or successor forms) certifying that such party is

entitled to a complete exemption from withholding or deduction for or on account of any United States federal income taxes with respect to amounts derived, directly or indirectly, in connection with this Agreement.

Section 5.4 Costs, Expenses and Taxes . (a) In addition to the rights of indemnification granted under Section 3.1 , the Seller agrees to pay on demand (which demand shall be accompanied by documentation thereof in reasonable detail) all reasonable costs and expenses in connection with the preparation, execution, delivery and administration (including periodic internal audits by the Administrator of Pool Receivables, provided that the Seller shall not pay for more than one audit per year unless a Termination Event has occurred and is continuing) of this Agreement, the other Transaction Documents and the other documents and agreements to be delivered hereunder (and all reasonable costs and expenses in connection with any amendment, waiver or modification of any thereof), including: (i) Attorney Costs for the Administrator, the Issuer and their respective Affiliates and agents with respect thereto and with respect to advising the Administrator, the Issuer and their respective Affiliates and agents as to their rights and remedies under this Agreement and the other Transaction Documents, and (ii) all reasonable costs and expenses (including Attorney Costs), if any, of the Administrator, the Issuer and their respective Affiliates and agents in connection with the enforcement of this Agreement and the other Transaction Documents.

(b) In addition, the Seller shall pay on demand any and all stamp and other similar taxes and fees payable in connection with the execution, delivery, filing and recording of this Agreement or the other documents or agreements to be delivered hereunder, and agrees to save each Indemnified Party harmless from and against any liabilities with respect to or resulting from any delay in paying or omission to pay such taxes and fees.

Section 5.5 No Proceedings; Limitation on Payments . Each of the Seller, UGI, the Servicer, the Administrator, each assignee of the Purchased Interest or any interest therein, and each Person that enters into a commitment to purchase the Purchased Interest or interests therein, hereby covenants and agrees that it will not institute against, or join any other Person in instituting against, the Issuer any bankruptcy, reorganization, similar arrangement, insolvency or liquidation proceeding, or other proceeding under any federal or state bankruptcy or similar law, for one year and one day after the latest maturing Note issued by the Issuer is paid in full. The provision of this Section 5.5 shall survive any termination of this Agreement [Reserved] .

Section 5.6 Confidentiality . Unless otherwise required by applicable law, each of the Seller and the Servicer agrees to maintain the confidentiality of the terms of this Agreement and the other Transaction Documents (and all drafts thereof) in communications with third parties and otherwise; provided , that this Agreement may be disclosed to: (a) third parties to the extent such disclosure is made pursuant to a written agreement of confidentiality in form and substance reasonably satisfactory to the Administrator, and (b) the Seller’s legal counsel and auditors if they agree to hold it confidential. Unless otherwise required by applicable law, each of the Administrator and the Issuer agrees to maintain the confidentiality of non-public information regarding UGI and its Subsidiaries and Affiliates; provided , that such information may be disclosed to: (i) third parties to the extent such disclosure is made pursuant to a written agreement of confidentiality in form and substance reasonably satisfactory to UGI, (ii) legal counsel and auditors of the Issuer or the Administrator if they agree to hold it confidential, (iii)

any nationally recognized statistical rating organization and the rating agencies rating the Notes, (iv) any Program Support Provider or potential Program Support Provider (if they agree to hold it confidential), (v) any placement agent placing the Notes and (vi (iv ) any regulatory authorities having jurisdiction over PNC , or the Issuer , any Program Support Provider or any Purchaser .

Section 5.7 GOVERNING LAW AND JURISDICTION . (a) THIS AGREEMENT SHALL BE DEEMED TO BE A CONTRACT MADE UNDER AND GOVERNED BY THE INTERNAL LAWS OF THE STATE OF NEW YORK (INCLUDING FOR SUCH PURPOSE SECTION 5-1401 AND 5-1402 OF THE GENERAL OBLIGATIONS LAW OF THE STATE OF NEW YORK) EXCEPT TO THE EXTENT THAT THE VALIDITY OR PERFECTION OF A SECURITY INTEREST OR REMEDIES HEREUNDER, IN RESPECT OF ANY PARTICULAR COLLATERAL ARE GOVERNED BY THE LAWS OF A JURISDICTION OTHER THAN THE STATE OF NEW YORK.

(b) ANY LEGAL ACTION OR PROCEEDING WITH RESPECT TO THIS AGREEMENT MAY BE BROUGHT IN THE COURTS OF THE STATE OF NEW YORK OR OF THE UNITED STATES FEDERAL COURT FOR THE SOUTHERN DISTRICT OF NEW YORK; AND, BY EXECUTION AND DELIVERY OF THIS AGREEMENT, EACH OF THE PARTIES HERETO CONSENTS, FOR ITSELF AND IN RESPECT OF ITS PROPERTY, TO THE NON-EXCLUSIVE JURISDICTION OF THOSE COURTS. EACH OF THE PARTIES HERETO IRREVOCABLY WAIVES, TO THE MAXIMUM EXTENT PERMITTED BY LAW, ANY OBJECTION, INCLUDING ANY OBJECTION TO THE LAYING OF VENUE OR BASED ON THE GROUNDS OF FORUM NON CONVENIENS, THAT IT MAY NOW OR HEREAFTER HAVE TO THE BRINGING OF ANY ACTION OR PROCEEDING IN SUCH JURISDICTION IN RESPECT OF THIS AGREEMENT OR ANY DOCUMENT RELATED HERETO. EACH OF THE PARTIES HERETO WAIVES PERSONAL SERVICE OF ANY SUMMONS, COMPLAINT OR OTHER PROCESS, WHICH SERVICE MAY BE MADE BY ANY OTHER MEANS PERMITTED BY NEW YORK LAW.

Section 5.8 Execution in Counterparts . This Agreement may be executed in any number
of counterparts, each of which, when so executed, shall be deemed to be an original, and all of which, when taken together, shall constitute one and the same agreement.

Section 5.9 Survival of Termination . The provisions of Sections 1.7 , 1.8 , 3.1 , 3.2 , 5.4 ,
5.5 , 5.6 , 5.7 , 5.10 and 5.13 shall survive any termination of this Agreement.

Section 5.10 WAIVER OF JURY TRIAL . EACH OF THE PARTIES HERETO
WAIVES THEIR RESPECTIVE RIGHTS TO A TRIAL BY JURY OF ANY CLAIM OR CAUSE OF ACTION BASED UPON OR ARISING OUT OF OR RELATED TO THIS AGREEMENT OR THE TRANSACTIONS CONTEMPLATED HEREBY IN ANY ACTION, PROCEEDING OR OTHER LITIGATION OF ANY TYPE BROUGHT BY ANY OF THE PARTIES AGAINST ANY OTHER PARTY OR PARTIES, WHETHER WITH RESPECT TO CONTRACT CLAIMS, TORT CLAIMS OR OTHERWISE. EACH OF THE PARTIES HERETO AGREES THAT ANY SUCH CLAIM OR CAUSE OF ACTION SHALL BE TRIED BY A COURT TRIAL WITHOUT A JURY. WITHOUT LIMITING THE FOREGOING, EACH OF THE PARTIES HERETO FURTHER AGREES THAT ITS RESPECTIVE RIGHT TO A TRIAL BY JURY IS WAIVED BY OPERATION OF THIS SECTION AS TO ANY

ACTION, COUNTERCLAIM OR OTHER PROCEEDING THAT SEEKS, IN WHOLE OR IN PART, TO CHALLENGE THE VALIDITY OR ENFORCEABILITY OF THIS AGREEMENT OR ANY PROVISION HEREOF. THIS WAIVER SHALL APPLY TO ANY SUBSEQUENT AMENDMENTS, RENEWALS, SUPPLEMENTS OR MODIFICATIONS TO THIS AGREEMENT.

Section 5.11 Entire Agreement . This Agreement and the other Transaction Documents embody the entire agreement and understanding between the parties hereto, and supersede all prior or contemporaneous agreements and understandings of such Persons, verbal or written, relating to the subject matter hereof and thereof, except for any prior arrangements made with respect to the payment by the Issuer of (or any indemnification for) any fees, costs or expenses payable to or incurred (or to be incurred) by or on behalf of the Seller, the Servicer and the Administrator.

Section 5.12 Headings . The captions and headings of this Agreement and any Exhibit, Schedule or Annex hereto are for convenience of reference only and shall not affect the interpretation hereof or thereof.

Section 5.13 Issuer’s,Administrator’s,Seller’sandServicer’sLiabilities . The obligations of the Issuer, the Administrator, the Seller and the Servicer under the Transaction Documents are solely the corporate or organizational obligations of the Issuer, the Administrator, the Seller and the Servicer, respectively. No recourse shall be had for any obligation or claim arising out of or based upon any Transaction Document against any stockholder, employee, officer, director or , incorporator or organizer of the Issuer, the Administrator, the Seller or the Servicer; provided , however , that this Section shall not relieve any such Person of any liability it might otherwise have for its own gross negligence or willful misconduct.

Section 5.14 Purchase Option . So long as the Credit Agreement is in effect, the Seller shall have the right to repurchase in full (but not in part) the Purchased Interest from the Issuer and the Purchasers, if any, on any Settlement Date on the terms hereinafter set forth in this Section 5.14 (such date, the “ Repurchase Date ”). The Seller shall give the Administrator at least sixty (60) days’ prior written notice of such repurchase. The Repurchase Date shall occur not later than the Settlement Date immediately after the sixty-day period following Seller’s written notice of such repurchase to the Administrator. Upon payment of the full Repurchase Price for the Purchased Interest on the Repurchase Date, as herein provided, the Issuer and the Purchasers, as applicable, shall be deemed to have reconveyed the Purchased Interest to the Seller without recourse, representation or warranty.    The Seller shall pay such repurchase price (the “ Repurchase Price ”) for the Purchased Interest on the Repurchase Date in immediately available funds to the Administrator in an amount equal to the sum of (i) the aggregate of the Discount accrued for each Portion of Capital for the Issuer and each Purchaser accrued to and including the Repurchase Date, (ii) the Capital for the Issuer and each Purchaser , (iii) all amounts payable pursuant to Sections 1.5 , 1.7 , 1.8 or 5.4 or Article III accrued to and including the Repurchase Date, (iv) all other fees, costs, expenses and other obligations of the Seller and the Servicer pursuant to the Transaction Documents that are payable as of the Repurchase Date, and (v) if UGI is not the Servicer, the Issuer’s Share of the Servicing Fee allocated to the Purchased Interest that has accrued to and including the Repurchase Date.

20

IN WITNESS WHEREOF , the parties have caused this Agreement to be executed by their respective officers thereunto duly authorized, as of the date first above written.

ENERGY SERVICES FUNDING CORPORATION

By:  Name:  Title:  

Address:    Energy Services Funding Corporation
460 North Gulph Road, Suite 200
King of Prussia, PA 19406-2815

Attention:    
Telephone:    
Facsimile:    

UGI ENERGY SERVICES, INC. LLC

By:  Name:  Title:  

Address:    UGI Energy Services, Inc. LLC
1100 Berkshire Boulevard, Suite 305
Wyomissing, PA 19610

Attention:    
Telephone:    
Facsimile:    

MARKET STREET FUNDING CORPORATION

By:  Name:  Title:  

PNC BANK, NATIONAL ASSOCIATION, as Administrator

By:  Name:  Title:  

Address:    PNC Bank, National Association
One Three PNC Plaza
249 225 Fifth Avenue
Pittsburgh, PA 15222-2707

Attention:    
Telephone:    
Facsimile:    

PNC BANK, NATIONAL ASSOCIATION, as Issuer

By: __________________
Name:
Title:

Address:      PNC Bank, National Association
Three PNC Plaza
225 Fifth Avenue
Pittsburgh, PA 15222-2707

Attention:     
Telephone:     
Facsimile:     

EXHIBIT I DEFINITIONS

As used in the Agreement (including its Exhibits, Schedules and Annexes), the following terms shall have the following meanings (such meanings to be equally applicable to both the singular and plural forms of the terms defined). Unless otherwise indicated, all Section, Annex, Exhibit and Schedule references in this Exhibit are to Sections of and Annexes, Exhibits and Schedules to the Agreement.

“Administration Account” means the account (account number ________ ABA number _______) of the Issuer maintained at the office of PNC at One PNC Plaza, 249 Fifth Avenue, Pittsburgh, Pennsylvania 15222-2707, or such other account as may be so designated in writing by the Administrator to the Servicer.

“Administrator” has the meaning set forth in the preamble to the Agreement.

“Adverse Claim” means a lien, security interest or other charge or encumbrance, or any other type of preferential arrangement; it being understood that any thereof in favor of, or assigned to, the Issuer or the Administrator (for the benefit of the Issuer) shall not constitute an Adverse Claim.

“Affected Person” has the meaning set forth in Section 1.7 of the Agreement.

“Affiliate” means, as to any Person: (a) any Person that, directly or indirectly, is in control of, is controlled by or is under common control with such Person, or (b) who is a director or officer: (i) of such Person or (ii) of any Person described in clause (a) , except that, with respect to the Issuer, Affiliate shall mean the holder(s) of its capital stock. For purposes of this definition, control of a Person shall mean the power, direct or indirect: (x) to vote 51% or more of the securities having ordinary voting power for the election of directors or managers of such Person, or (y) to direct or cause the direction of the management and policies of such Person, in either case whether by ownership of securities, contract, proxy or otherwise.

“Agreement” has the meaning set forth in the preamble to the Agreement.

“Alternate Rate” for any Settlement Period for any Portion of Capital of the Purchased Interest means an interest rate per annum equal to: (a) 2.00% per annum above the Euro-Rate daily average LMIR for such Settlement Period, or , in the sole discretion of the Administrator, (b) if LMIR is unavailable as described in Section 1.9, the Base Rate for such Settlement Period; provided , however , that the “Alternate Rate” for any day while a Termination Event exists shall be an interest rate equal to 3.00% per annum above the Base Rate in effect on such day.

“Approved Billing Program” means any consolidated billing or similar agreement between a Purchasing Utility and the Originator pursuant to which the Originator may from time to time sell and/or assign receivables, which agreement has been approved in writing by the Administrator; provided , that if (i) the Originator delivers to the Administrator in writing and in accordance with Section 5.2 a copy of such an agreement (or a substantially final draft thereof)

with a request that it be approved as an “Approved Billing Program” and (ii) the Administrator does not, on or prior to the date that is ten (10) Business Days following such delivery, notify the Originator or the Servicer that the Administrator is withholding such approval, the Administrator shall be deemed to have approved such agreement as an “Approved Billing Program” in accordance with this definition. Without limiting the generality of the foregoing, each of the following agreements shall be an Approved Billing Program: (x) that certain Consolidated Utility Billing Service and Assignment Agreement, contemplated to be entered into between Consolidated Edison Company of New York, Inc. and the Originator, containing terms and conditions in form and substance substantially similar to those set forth in the draft of such agreement previously delivered by the Originator to the Administrator on April 7, 2009 and (y) that certain Third Party Supplier Customer Account Services Master Service Agreement, dated November 6, 2008, by and between Public Service Electric and Gas Company and the Originator, a copy of which was delivered by the Originator to the Administrator on April 20, 2009.

“Attorney Costs” means and includes all reasonable fees and disbursements of any law firm or other external counsel, the reasonable allocated cost of internal legal services and all reasonable disbursements of internal counsel.

“Bankruptcy Code” means the United States Bankruptcy Reform Act of 1978 (11 U.S.C.
§ 101, et seq.), as amended from time to time.

“Base Rate” means, for any day, a fluctuating interest rate per annum as shall be in effect from time to time, which rate shall be at all times equal to the higher of:

(a) the rate of interest in effect for such day as publicly announced from time to time by PNC in Pittsburgh, Pennsylvania as its “prime rate.” Such “prime rate” is set by PNC based upon various factors, including PNC’s costs and desired return, general economic conditions and other factors, and is used as a reference point for pricing some loans, which may be priced at, above or below such announced rate, and

(b) 0.50% per annum above the latest Federal Funds Rate.

“BBA” means the British Bankers’ Association.

“Benefit Plan” means any employee benefit pension plan as defined in Section 3(2) of ERISA in respect of which the Seller, the Originator, UGI or any ERISA Affiliate is an “employer” as defined in Section 3(5) of ERISA.

“Billing Program Receivable” means a Receivable described in clause (i) of the definition of the term “Receivable”, which is sold and/or assigned by the Originator to a Purchasing Utility from time to time pursuant to an Approved Billing Program.

“Business Day” means any day (other than a Saturday or Sunday) on which: (a) banks are not authorized or required to close in New York City, New York or Pittsburgh, Pennsylvania, and (b) if this definition of “Business Day” is utilized in connection with the Euro-Rate LMIR , dealings are carried out in the London interbank market.

“Capital” means the amount paid to the Seller in respect of the Purchased Interest by the Issuer pursuant to the Agreement, or such amount divided or combined in order to determine the Discount applicable to any Portion of Capital, in each case reduced from time to time by Collections distributed and applied on account of such Capital pursuant to Section 1.4(d) of the Agreement; provided , that if such Capital shall have been reduced by any distribution, and thereafter all or a portion of such distribution is rescinded or must otherwise be returned for any reason, such Capital shall be increased by the amount of such rescinded or returned distribution as though it had not been made.

“Change in Control” means that (a) with respect to the Seller, UGI ceases to own, directly or indirectly, 100% of the capital stock of the Seller free and clear of all Adverse Claims, (b) with respect to UGI, UGI Enterprises, Inc. shall cease to own 51% or more of the shares of outstanding voting stock of UGI on a fully diluted basis.

“Closing Date” means November 30, 2001.

“Collections” means, with respect to any Pool Receivable: (a) all funds that are received by the Originator, UGI, the Seller or the Servicer in payment of any amounts owed in respect of such Receivable (including purchase price, finance charges, interest and all other charges), or applied to amounts owed in respect of such Receivable (including insurance payments and net proceeds of the sale or other disposition of repossessed goods or other collateral or property of the related Obligor or any other Person directly or indirectly liable for the payment of such Pool Receivable and available to be applied thereon), (b) all amounts deemed to have been received pursuant to Section 1.4(e) of the Agreement and (c) all other proceeds of such Pool Receivable.

“Concentration Percentage” means for any: (a) Group A Obligor, 16.00%, (b) Group B Obligor, 12.00%, (c) Group C Obligor, 8.00% and (d) Group D Obligor, 4.00%.

“Concentration Reserve Percentage” means, at any time, the largest of: (a) the sum of five largest Group D Obligor Percentages, (b) the sum of the three largest Group C Obligor Percentages, (c) the sum of two largest Group B Obligor Percentages and (d) the largest Group A Obligor Percentage.

“Contract” means, with respect to any Receivable, any and all contracts, instruments, agreements, leases, invoices, notes or other writings pursuant to which such Receivable arises or that evidence such Receivable or under which an Obligor becomes or is obligated to make payment in respect of such Receivable.

“Contributed Receivables” has the meaning set forth in Section 2.2 of the Purchase and
Sale Agreement.

“CP Rate” for any Settlement Period for any Portion of Capital means a rate calculated by the Administrator equal to: (a) the rate (or if more than one rate, the weighted average of the rates) at which Notes of the Issuer on each day during such period have been outstanding; provided , that if such rate(s) is a discount rate(s), then the CP Rate shall be the rate (or if more than one rate, the

weighted average of the rates) resulting from converting such discount rate(s) to an interest-bearing equivalent rate plus (b) the commissions and charges charged by such placement agent or commercial paper dealer with respect to such Notes, expressed as a
percentage of the face amount of such Notes and converted to an interest-bearing equivalent rate per annum. Notwithstanding the foregoing, the “CP Rate” for any day while a Termination Event exists shall be an interest rate equal to 3.00% above the Base Rate in effect on such day.

“Credit Agreement” means that certain Credit Agreement, dated on or about August 26,
2010, among UGI, as borrower, the lenders party thereto, JPMorgan Chase Bank, N.A., as administrative agent, PNC Bank, National Association, Wells Fargo Bank, National Association, and certain other parties, as such agreement may be amended, amended and restated, supplemented or otherwise modified from time to time.

“Credit and Collection Policy” means, as the context may require, those receivables credit and collection policies and practices of the Originator in effect on the date of the Agreement and described in Schedule I to the Agreement, as modified in compliance with the Agreement.

“Cut-off Date” has the meaning set forth in the Purchase and Sale Agreement.

“Days’ Sales Outstanding” means, for any calendar month, an amount (expressed as a number of days) computed as of the last day of such calendar month equal to: (a) the average of the Outstanding Balance of all Pool Receivables as of the last day of each of the three most recent calendar months ended on the last day of such calendar month divided by (b) (i) the aggregate credit sales made by the Originator during the three calendar months ended on the last day of such calendar month divided by (ii) 90.

“Debt” means: (a) indebtedness for borrowed money, (b) obligations evidenced by bonds, debentures, notes or other similar instruments, (c) obligations to pay the deferred purchase price of property or services, (d) obligations as lessee under leases that shall have been or should be, in accordance with GAAP, recorded as capital leases, and (e) obligations under direct or indirect guaranties in respect of, and obligations (contingent or otherwise) to purchase or otherwise acquire, or otherwise to assure a creditor against loss in respect of, indebtedness or obligations of others of the kinds referred to in clauses (a) through (d) .

“Default Ratio” means the ratio (expressed as a percentage and rounded to the nearest
1/100 of 1%, with 5/1000th of 1% rounded upward) computed as of the last day of each calendar month by dividing: (a) the aggregate Outstanding Balance of all Pool Receivables that became Defaulted Receivables during such month, by (b) the aggregate credit sales made by the Originator during the month that is three calendar months before such month. The Outstanding Balance of any Defaulted Receivable shall be determined without regard to any credit memos or credit balances.

“Defaulted Receivable” means a Receivable:

(a) as to which any payment, or part thereof, remains unpaid for more than 60 days from the original due date for such payment, or

(b) without duplication (i) as to which an Insolvency Proceeding shall have occurred with respect to the Obligor thereof or any other Person obligated thereon with respect thereto, or (ii) that has been written off the Seller’s books as uncollectible.
“Delinquency Ratio” means the ratio (expressed as a percentage and rounded to the nearest 1/100 of 1%, with 5/1000th of 1% rounded upward) computed as of the last day of each calendar month by dividing: (a) the aggregate Outstanding Balance of all Pool Receivables that were Delinquent Receivables on such day by, (b) the aggregate Outstanding Balance of all Pool Receivables (excluding Delinquent Receivables that have a stated maturity which is more than 60 days after the original invoice date of such Receivable) on such day.

“Delinquent Receivable” means any portion of a Receivable as to which any payment, or part thereof, remains unpaid for more than 60 days from the original due date for such payment. The Outstanding Balance of any Delinquent Receivable shall be determined without regard to any credit memos or credit balances and shall exclude Delinquent Receivables that have a stated maturity which is more than 60 days after the original invoice date of such Receivable.

“Dilution Horizon” means, for any calendar month, the ratio (expressed as a percentage and rounded to the nearest 1/100th of 1%, with 5/1000th of 1% rounded upward) computed as of the last day of such calendar month of: (a) the aggregate credit sales made by the Originator during the most recent calendar month and 50% of the next most recent calendar month’s credit sales to (b) the Net Receivables Pool Balance at the last day of the most recent calendar month.

“Dilution Ratio” means the ratio (expressed as a percentage and rounded to the nearest
1/100th of 1%, with 5/1000th of 1% rounded upward) computed as of the last day of each calendar month by dividing: (a) the aggregate amount of payments required to be made by the Seller pursuant to Section 1.4(e)(i) of the Agreement during such calendar month, by (b) the aggregate credit sales made by the Originator during the month that is one calendar month before such month.

“Dilution Reserve” means, on any date, an amount equal to: (a) the Capital at the close of business of the Servicer on such date multiplied by (b) (i) the Dilution Reserve Percentage on such date, divided by (ii) 100% minus the Dilution Reserve Percentage on such date.

“Dilution Reserve Percentage” means on any date, the product of (i) the Dilution Horizon multiplied by (ii) the sum of (x) 2.25 times the average of the Dilution Ratios for the twelve most recent calendar months and (y) the Spike Factor.

“Discount” means:

(a)  for the Portion of Capital for any Settlement Period to the extent the Issuer will be funding such Portion of Capital during such Settlement Period through the issuance of Notes:

CPR x C x ED/360

(b)  for the Portion of Capital for any Settlement Period to the extent the Issuer will not be funding such Portion of Capital during such Settlement Period through the issuance of Notes :

AR x C x ED/Year + TF

	
				
where:	

AR	

=	

the Alternate Rate for the Portion of Capital for such Settlement	
 	 	 	Period,	
 	
C	
=	
the Portion of Capital during such Settlement Period,	
 	
CPR	
=	
the CP Rate for the Portion of Capital for such Settlement Period,	
 	
ED	
=	
the actual number of days during such Settlement Period,	
 	
TF	
=	
the Termination Fee, if any, for the Portion of Capital for such
Settlement Period, and	
 	
Year	
=	
if such Portion of Capital is funded based upon: (i)   the   Euro-Rate LMIR , 360 days, and (ii) the Base Rate, 365 or 366 days, as applicable;	

provided , that no provision of the Agreement shall require the payment or permit the collection of Discount in excess of the maximum permitted by applicable law; and provided further , that Discount for the Portion of Capital shall not be considered paid by any distribution to the extent that at any time all or a portion of such distribution is rescinded or must otherwise be returned for any reason.

“Eligible Receivable” means, at any time, a Pool Receivable:

(a) the Obligor of which is (i) a United States resident, (ii) not a government or a governmental subdivision, affiliate or agency, provided , however , if the Obligor of such Receivable is a government or a governmental subdivision, affiliate or agency, such Receivable shall satisfy the requirements of this clause (a)(ii)  if the sum of the Outstanding Balance of such Receivable and the aggregate Outstanding Balance of all other Eligible Receivables of Obligors who are governments or governmental subdivisions, affiliates or agencies does not exceed $200,000, (iii) not subject to any action of the type described in paragraph (f) of Exhibit V to the Agreement, (iv) not an Affiliate of UGI; provided , however , if the Obligor of such Receivable is either UGI Utilities, Inc. or UGI Penn Natural Gas, Inc. (provided that UGI Penn Natural Gas, Inc. is a wholly-owned subsidiary of UGI Utilities, Inc.), such Receivable shall satisfy the requirements of this clause (a)(iv)  if the sum of the Outstanding Balance of such Receivable and the aggregate Outstanding Balance of all other Eligible Receivables of the Obligors of which are either UGI Utilities, Inc. or UGI Penn Natural Gas, Inc. does not exceed $10,000,000, and (v) not a Reseller, provided , however , if the Obligor of such Receivable is a Reseller, such Receivable shall satisfy the requirements of this clause (a)(v)  if the sum of the Outstanding Balance of such Receivable and the aggregate Outstanding Balance of all other Eligible Receivables of Obligors who are Resellers does not exceed $2,000,000,

(b) that is denominated and payable only in U.S. dollars in the United States,
(n) for which neither the Originator thereof, the Seller nor the Servicer has established any offset arrangements with the related Obligor,

(o) of an Obligor as to which Defaulted Receivables of such Obligor do not
exceed 25% of the Outstanding Balance of all such Obligor’s Receivables; provided , however , that amounts owing from Cooperative Industries Inc. that are more than 90 days from the original invoice date as of the Closing Date and that are being paid in accordance with a negotiated payment schedule shall not be considered Defaulted Receivables for purposes of this clause (o) , and

(p) that represents amounts earned and payable by the Obligor that are not subject to the performance of additional services by the Originator thereof.

“ERISA” means the Employee Retirement Income Security Act of 1974, as amended from time to time, and any successor statute of similar import, together with the regulations thereunder, in each case as in effect from time to time. References to sections of ERISA also refer to any successor sections.

“ERISA Affiliate” means: (a) any corporation that is a member of the same controlled group of corporations (within the meaning of Section 414(b) of the Internal Revenue Code) as the Seller, the Originator or UGI, (b) a trade or business (whether or not incorporated) under common control (within the meaning of Section 414(c) of the Internal Revenue Code) with the Seller, the Originator or UGI, or (c) a member of the same affiliated service group (within the meaning of Section 414(m) of the Internal Revenue Code) as the Seller, the Originator, any corporation described in clause (a) or any trade or business described in clause (b) .

“Euro-Rate” means with respect to any Settlement Period the interest rate per annum determined by the Administrator by dividing (the resulting quotient rounded upwards, if necessary, to the nearest 1/100th of 1% per annum) (i) the rate of interest determined by the Administrator in accordance with its usual procedures (which determination shall be conclusive absent manifest error) to be the average of the London interbank market offered rates for U.S. dollars quoted by the BBA as set forth on Dow Jones Markets Service (formerly known as Telerate) (or appropriate successor or, if the BBA or its successor ceases to provide display page
3750 (or such other display page on the Dow Jones Markets Service system as may replace display page 3750) at or about 11:00 a.m. (London time) on the Business Day which is two (2) Business Days prior to the first day of such Settlement Period for an amount comparable to the Portion of Capital to be funded at the Alternate Rate and based upon the Euro-Rate during such Settlement Period by (ii) a number equal to 1.00 minus the Euro-Rate Reserve Percentage. The Euro-Rate may also be expressed by the following formula:

Euro-Rate =  Average of London interbank offered rates quoted by BBA as shown on Dow Jones Markets Service display page 3750 or appropriate successor

1.00 - Euro-Rate Reserve Percentage

where “Euro-Rate Reserve Percentage” means, the maximum effective percentage in effect on such day as prescribed by the Board of Governors of the Federal Reserve System (or any successor) for determining the reserve requirements (including without limitation, supplemental, marginal, and emergency reserve requirements) with respect to eurocurrency funding (currently referred to as “Eurocurrency Liabilities”). The Euro-Rate shall be adjusted with respect to any Portion of Capital funded at the Alternate Rate and based upon the Euro-Rate that is outstanding on the effective date of any change in the Euro-Rate Reserve Percentage as of such effective date. The Administrator shall give prompt notice to the Seller of the Euro-Rate as determined or adjusted in accordance herewith (which determination shall be conclusive absent manifest error).

“Excess Concentration” means the sum of the amounts by which the Outstanding Balance of Eligible Receivables of each Obligor then in the Receivables Pool exceeds an amount equal to: (a) the applicable Concentration Percentage for such Obligor multiplied by  (b) the Outstanding Balance of all Eligible Receivables then in the Receivables Pool.

“Facility Termination Date” means the earliest to occur of: (a) November 1, 2013, (b) the date determined pursuant to Section 2.2 of the Agreement , and (c) the date the Purchase Limit reduces to zero pursuant to Section 1.1(b) of the Agreement , (d) the date, after written notice from the Purchasers, that the commitments of the Purchasers terminate under the Liquidity Agreement, but the failure to give or delay in giving such notice shall not prevent or delay such termination, and (e) the Issuer shall fail to cause the amendment or modification of any Transaction Document or related opinion as required by Moody’s or Standard and Poor’s, and such failure shall continue for 30 days after such amendment is initially requested .

“Federal Funds Rate” means, for any day, the per annum rate set forth in the weekly statistical release designated as H.15(519), or any successor publication, published by the Federal Reserve Board (including any such successor, “H.15(519)”) for such day opposite the caption “Federal Funds (Effective).” If on any relevant day such rate is not yet published in H.15(519), the rate for such day will be the rate set forth in the daily statistical release designated as the Composite 3:30 p.m. Quotations for U.S. Government Securities, or any successor publication, published by the Federal Reserve Bank of New York (including any such successor, the “Composite 3:30 p.m. Quotations”) for such day under the caption “Federal Funds Effective Rate.” If on any relevant day the appropriate rate is not yet published in either H.15(519) or the Composite 3:30 p.m. Quotations, the rate for such day will be the arithmetic mean as determined by the Administrator of the rates for the last transaction in overnight Federal funds arranged before 9:00 a.m. (New York time) on that day by each of three leading brokers of Federal funds transactions in New York City selected by the Administrator.

“Federal Reserve Board” means the Board of Governors of the Federal Reserve System, or any entity succeeding to any of its principal functions.

“Fee Letter” has the meaning set forth in Section 1.5 of the Agreement.

“GAAP” means the generally accepted accounting principles and practices in the United
States, consistently applied.
Excess Concentrations of such Obligor, divided by (b) the aggregate Outstanding Balance of all
Eligible Receivables at such time.

“Indemnified Amounts” has the meaning set forth in Section 3.1 of the Agreement. “Indemnified Party” has the meaning set forth in Section 3.1 of the Agreement. “Indemnifying Party” has the meaning set forth in Section 3.3 of the Agreement. “Independent Director” has the meaning set forth in paragraph 3(c) of Exhibit IV to the
Agreement.

“Information Package” means a report, in substantially the form of either Annex A-1 (in the case of an Information Package delivered in connection with a Settlement Date) or Annex A-2 (in the case of an Information Package delivered at any other time) to the Agreement, furnished to the Administrator pursuant to the Agreement.

“Insolvency Proceeding” means: (a) any case, action or proceeding before any court or other Governmental Authority relating to bankruptcy, reorganization, insolvency, liquidation, receivership, dissolution, winding-up or relief of debtors, or (b) any general assignment for the benefit of creditors of a Person, or composition, marshaling of assets for creditors of a Person, or other, similar arrangement in respect of its creditors generally or any substantial portion of its creditors, in each of cases (a) and (b) undertaken under U.S. Federal, state or foreign law, including the Bankruptcy Code.

“Internal Revenue Code” means the Internal Revenue Code of 1986, as amended from time to time, and any successor statute of similar import, together with the regulations thereunder, in each case as in effect from time to time. References to sections of the Internal Revenue Code also refer to any successor sections.

“Issuer” has the meaning set forth in the preamble to the Agreement.

“Issuer’s Share” of any amount means such amount multiplied by the Purchased Interest at the time of determination.

“ Liquidity Agent” means PNC in its capacity as the Liquidity Agent pursuant to the Liquidity Agreement. LMIR” means for any day during any Settlement Period, the one-month Eurodollar rate for U.S. dollar deposits as reported on the Reuters Screen LIBOR01 Page or any other page that may replace such page from time to time for the purpose of displaying offered rates of leading banks for London interbank deposits in United States dollars, as of 11:00 a.m. (London time) on such day, or if such day is not a Business Day, then the immediately preceding Business Day (or if not so reported, then as determined by the Administrator from another recognized source for interbank quotation), in each case, changing when and as such rate changes.

“Liquidity Agreement” means the Liquidity Asset Purchase Agreement, dated as of even date herewith, between the Purchasers from time to time party thereto, the Issuer and PNC, as
Administrator and Liquidity Agent, as the same may be further amended, supplemented or otherwise modified from time to time.

“Lock-Box Account” means an account in the name of the Seller and maintained by the
Seller at a bank or other financial institution for the purpose of receiving Collections.

“Lock-Box Agreement” means an agreement, in form and substance satisfactory to the Administrator, among the Seller, the Originator, the Servicer, the Administrator, the Issuer and a Lock-Box Bank.

“Lock-Box Bank” means any of the banks or other financial institutions holding one or more Lock-Box Accounts.

“Loss Reserve” means, on any date, an amount equal to: (a) the Capital at the close of business of the Servicer on such date multiplied by (b)(i) the Loss Reserve Percentage on such date divided by (ii) 100% minus the Loss Reserve Percentage on such date.

“Loss Reserve Percentage” means, on any date, the product of (i) 2.25 times (ii) the highest average of the Default Ratios for any three consecutive calendar months during the twelve most recent calendar months times (iii) (A) the aggregate credit sales made by the Originator during the four most recent calendar months, divided by (B) the Net Receivables Pool Balance as of such date.

“Material Adverse Effect” means, relative to any Person with respect to any event or circumstance, a material adverse effect on:

(a) the assets, operations, business or financial condition of such Person,

(b) the ability of any of such Person to perform its obligations under the
Agreement or any other Transaction Document to which it is a party,

(c) the validity or enforceability of any other Transaction Document, or the validity, enforceability or collectibility of a material portion of the Pool Receivables, or

(d) the status, perfection, enforceability or priority of the Issuer’s or the Seller’s interest in the Pool Assets.

“Moody’s” means Moody’s Investors Service, Inc.

“Net Receivables Pool Balance” means, at any time: (a) the Outstanding Balance of
Eligible Receivables then in the Receivables Pool minus (b) the Excess Concentration.

“Notes” means short-term promissory notes issued, or to be issued, by the Issuer to fund its investments in accounts receivable or other financial assets.

“Obligor” means, with respect to any Receivable, the Person obligated to make payments pursuant to the Contract relating to such Receivable.
“Originator” has the meaning set forth in the Purchase and Sale Agreement.

“Originator Assignment Certificate” means the assignment, in substantially the form of Exhibit C to the Purchase and Sale Agreement, evidencing Seller’s ownership of the Receivables generated by the Originator, as the same may be amended, supplemented, amended and restated, or otherwise modified from time to time in accordance with the Purchase and Sale Agreement.

“Outstanding Balance” of any Receivable at any time means the then outstanding principal balance thereof.

“Payment Date” has the meaning set forth in Section 2.2 of the Purchase and Sale
Agreement.

“Person” means an individual, partnership, corporation (including a business trust), joint stock company, trust, unincorporated association, joint venture, limited liability company or other entity, or a government or any political subdivision or agency thereof.

“PNC” has the meaning set forth in the preamble to the Agreement.

“Pool Assets” has the meaning set forth in Section 1.2(d) of the Agreement. “Pool Receivable” means a Receivable in the Receivables Pool.
“Portion of Capital” means any separate portion of Capital being funded or maintained by the Issuer (or its successors or permitted assigns) by reference to a particular interest rate basis. In addition, at any time when the Capital of the Purchased Interest is not divided into two or more such portions, “Portion of Capital” means 100% of the Capital.

“Program Support Agreement” means and includes the Liquidity Agreement and any other agreement entered into by any Program Support Provider providing for: (a) the issuance of one or more letters of credit for the account of the Issuer in connection with the Issuer’s Receivables securitization program, (b) the issuance of one or more surety bonds in connection with the Issuer’s Receivables securitization program for which the Issuer is obligated to reimburse the applicable Program Support Provider for any drawings thereunder, (c) the sale by the Issuer to any Program Support Provider of the Purchased Interest (or portions thereof) and/or (d) the making of loans and/or other extensions of credit to the Issuer in connection with the Issuer’s Receivables-securitization program contemplated in the Agreement, together with any letter of credit, surety bond or other instrument issued thereunder (but excluding any discretionary advance facility provided by the Administrator).

“Program Support Provider” means and includes any Purchaser and any other Person (other than any customer of the Issuer) now or hereafter extending credit or having a commitment to extend credit to or for the account of, or to make purchases from, the Issuer pursuant to any Program Support Agreement.

“Purchase and Sale Agreement” means the Purchase and Sale Agreement, dated as of even date herewith, between the Seller and UGI, as such agreement may be amended, amended and restated, supplemented or otherwise modified from time to time.
“Purchase and Sale Indemnified Amounts” has the meaning set forth in Section 9.1 of the

Purchase and Sale Agreement.

“Purchase and Sale Indemnified Party” has the meaning set forth in Section 9.1 of the
Purchase and Sale Agreement.

“Purchase and Sale Termination Date” has the meaning set forth in Section 1.4 of the
Purchase and Sale Agreement.

“Purchase and Sale Termination Event” has the meaning set forth in Section 8.1 of the
Purchase and Sale Agreement.

“Purchase Facility” has the meaning set forth in Section 1.1 of the Purchase and Sale
Agreement.

“Purchase Limit” means $100,000,000, as such amount may be subsequently reduced pursuant to Section 1.1(b) of the Agreement. References to the unused portion of the Purchase Limit shall mean, at any time, the Purchase Limit minus the then outstanding Capital.

References to the unused portion of the Purchase Limit shall mean, at any time, the
Purchase Limit minus the then outstanding Capital.

“Purchase Notice” has the meaning set forth in Section 1.2(a) of the Agreement.

“Purchase Price” has the meaning set forth in Section 2.1 of the Purchase and Sale
Agreement.

“Purchase Report” has the meaning set forth in Section 2.1 of the Purchase and Sale
Agreement.

“Purchased Interest” means, at any time, the undivided percentage ownership interest in: (a) each and every Pool Receivable now existing or hereafter arising, (b) all Related Security with respect to such Pool Receivables and (c) all Collections with respect to, and other proceeds of, such Pool Receivables and Related Security. Such undivided percentage interest shall be computed as:

    Capital + Total Reserves      Net Receivables Pool Balance

The Purchased Interest shall be determined from time to time pursuant to Section 1.3 of the
Agreement.

“Purchaser” has the meaning set forth in Section 5.3(b) of the Agreement.

“Purchasing Utility” means a jurisdictional natural gas or electricity distribution company.

EXHIBIT II CONDITIONS OF PURCHASES
1. Conditions Precedent to Initial Purchase . The Initial Purchase initial purchase under this Agreement is subject to the following conditions precedent that the Administrator shall have received on or before the date of such purchase, November 30, 2001, each in form and substance (including the date thereof) satisfactory to the Administrator:

(a) A counterpart of the Agreement and the other Transaction Documents executed by the parties thereto.

(b) Certified copies of: (i) the resolutions of the Board of Directors of each of the Seller, the Originator and UGI authorizing the execution, delivery and performance by the Seller, the Originator and UGI, as the case may be, of the Agreement and the other Transaction Documents to which it is a party; (ii) all documents evidencing other necessary corporate action and governmental approvals, if any, with respect to the Agreement and the other Transaction Documents and (iii) the certificate of incorporation and by-laws of the Seller and UGI.

(c) A certificate of the Secretary or Assistant Secretary of the Seller, the Originator and UGI certifying the names and true signatures of its officers who are authorized to sign the Agreement and the other Transaction Documents. Until the Administrator receives a subsequent incumbency certificate from the Seller, the Originator or UGI, as the case may be, the Administrator shall be entitled to rely on the last such certificate delivered to it by the Seller, the Originator or UGI, as the case may be.

(d) Proper financing statements or other instrument similar in effect, suitable for filing, under the UCC of all jurisdictions that the Administrator may deem necessary or desirable in order to perfect the interests of the Seller, UGI and the Issuer contemplated by the Agreement and the Purchase and Sale Agreement.

(e) Proper financing statements or other instrument similar in effect, suitable for filing, if any, necessary to release all security interests and other rights of any Person in the Receivables, Contracts or Related Security previously granted by the Originator, UGI or the Seller.

(f) Completed UCC search reports, dated on or shortly before the date of the initial purchase hereunder, listing the financing statements filed in all applicable jurisdictions referred to in subsection (e) above that name the Originator or the Seller as debtor, together with copies of such other financing statements, and similar search reports with respect to judgment liens, federal tax liens and liens of the Pension Benefit Guaranty Corporation in such jurisdictions, as the Administrator may request, showing no Adverse Claims on any Pool Assets.

(g) Copies of executed Lock-Box Agreements with each Lock-Box Bank (to be delivered within 30 days of the Closing Date).

(h) Favorable opinions, in form and substance reasonably satisfactory to the
Administrator, of Morgan, Lewis & Bockius LLP, counsel for the Seller, the Originator and the
Servicer.

(i) Satisfactory results of a review and audit (performed by representatives of the Administrator) of the Servicer’s collection, operating and reporting systems, the Credit and Collection Policy of the Originator, historical receivables data and accounts, including satisfactory results of a review of the Servicer’s operating location(s) and satisfactory review and approval of the Eligible Receivables in existence on the date of the initial purchase under the Agreement.

(j) A pro forma Information Package representing the performance of the Receivables
Pool for the calendar month before closing.

(k) Evidence of payment by the Seller of all accrued and unpaid fees (including those contemplated by the Fee Letter), costs and expenses to the extent then due and payable on the date thereof, including any such costs, fees and expenses arising under or referenced in Section
5.4 of the Agreement and the Fee Letter.

(l) The Fee Letter duly executed by the Seller and the Servicer.

(m) Good standing certificates with respect to each of the Seller, the Originator and the Servicer issued by the Secretary of State (or similar official) of the state of each such Person’s organization or formation and principal place of business.

(n) The Liquidity Agreement and all other All Transaction Documents duly executed by the parties thereto.

(o) A computer file containing all information with respect to the Receivables as the
Administrator or the Issuer may reasonably request.

(p) Such other approvals, opinions or documents as the Administrator or the Issuer may reasonably request.

2. ConditionsPrecedenttoAllPurchasesandReinvestments . Each purchase (except as to clause (a) , including the initial purchase) and each reinvestment shall be subject to the further conditions precedent that:

(a) in the case of each purchase, the Servicer shall have delivered to the Administrator on or before such purchase, in form and substance satisfactory to the Administrator, a completed pro forma Information Package to reflect the level of Capital and related reserves and the calculation of the Purchased Interest after such subsequent purchase and a completed Purchase Notice in the form of Annex B; and

(b) on the date of such purchase or reinvestment the following statements shall be true (and acceptance of the proceeds of such purchase or reinvestment shall be deemed a representation and warranty by the Seller that such statements are then true):

(i) the representations and warranties contained in Exhibit III or VI to the Agreement are true and correct in all material respects on and as of the date of such

purchase or reinvestment as though made on and as of such date (except to the extent that such representations and warranties relate expressly to an earlier date, and in which case
EXHIBIT III REPRESENTATIONS AND WARRANTIES

1. Representations and Warranties of the Seller . The Seller represents and warrants as follows:

(a) The Seller is a corporation duly incorporated, validly existing and in good standing under the laws of the State of Delaware, and is duly qualified to do business and is in good standing as a foreign corporation in every jurisdiction where the nature of its business requires it to be so qualified, except where the failure to be so qualified would not have a Material Adverse Effect.

(b) The execution, delivery and performance by the Seller of the Agreement and the other Transaction Documents to which it is a party, including its use of the proceeds of purchases and reinvestments: (i) are within its corporate powers; (ii) have been duly authorized by all necessary corporate action; (iii) do not contravene or result in a default under or conflict with: (A) its charter or by-laws, (B) any law, rule or regulation applicable to it, (C) any indenture, loan agreement, mortgage, deed of trust or other material agreement or instrument to which it is a party or by which it is bound, or (D) any order, writ, judgment, award, injunction or decree binding on or affecting it or any of its property; and (iv) do not result in or require the creation of any Adverse Claim upon or with respect to any of its properties. The Agreement and the other Transaction Documents to which it is a party have been duly executed and delivered by the Seller.

(c) No authorization, approval or other action by, and no notice to or filing with, any Governmental Authority or other Person is required for its due execution, delivery and performance by the Seller of its obligations under the Agreement or any other Transaction Document to which it is a party, other than the Uniform Commercial Code filings referred to in Exhibit II to the Agreement, all of which shall be suitable for filing on or before the date of the first purchase hereunder.

(d) Each of the Agreement and the other Transaction Documents to which the Seller is a party constitutes a legal, valid and binding obligation enforceable against the Seller in accordance with its terms, except as enforceability may be limited by bankruptcy, insolvency, reorganization or other similar laws from time to time in effect affecting the enforcement of creditors’ rights generally and by general principles of equity, regardless of whether such enforceability is considered in a proceeding in equity or at law.

(e) There is no pending or, to Seller’s knowledge, threatened action or proceeding affecting Seller or any of its properties before any Governmental Authority or arbitrator.

(f) No proceeds of any purchase or reinvestment will be used to acquire any equity
security of a class that is registered pursuant to Section 12 of the Securities Exchange Act of
1934.

(g) The Seller is the legal and beneficial owner of the Pool Receivables and Related

Security, free and clear of any Adverse Claim. Upon each purchase or reinvestment, the Issuer
(o) The Seller has accounted for each sale of undivided percentage ownership interests in
Receivables in its books and financial statements as sales, consistent with GAAP.

(p) The Seller has complied in all material respects with the Credit and Collection
Policies of the Originator with regard to each Receivable originated by the Originator.

(q) The Seller has complied in all material respects with all of the terms, covenants and agreements contained in the Agreement and the other Transaction Documents that are applicable to it.

(r) The Seller’s complete corporate name is set forth in the preamble to the Agreement, and it does not use and has not during the last six years used any other corporate name, trade name, doing-business name or fictitious name, except as set forth on Schedule III  to the Agreement and except for names first used after the date of the Agreement and set forth in a notice delivered to the Administrator pursuant to Section 1(l)(v) of Exhibit IV to the Agreement.

(s) The Seller is not an “investment company,” or a company “controlled” by an “investment company” within the meaning of the Investment Company Act of 1940, as amended. In addition, the Seller is not a “holding company,” a “subsidiary company” of a “holding company” or an “affiliate” of a “holding company” or of a “subsidiary company” of a “holding company” within the meaning of the Public Utility Holding Company Act of 1935, as amended.

(t) With respect to each Receivable transferred to the Seller under the Purchase and Sale Agreement, Seller has given reasonably equivalent value to the Originator thereof in consideration therefor and such transfer was not made for or on account of an antecedent debt. No transfer by the Originator of any Receivable under the Purchase and Sale Agreement is or may be voidable under any section of the Bankruptcy Code.

(u) Each Contract with respect to each Receivable is effective to create, and has created, a legal, valid and binding obligation of the related Obligor to pay the Outstanding Balance of the Receivable created thereunder and any accrued interest thereon, enforceable against the Obligor in accordance with its terms, except as such enforcement may be limited by applicable bankruptcy, insolvency, reorganization or other similar laws relating to or limiting creditors’ rights generally and by general principles of equity (regardless of whether enforcement is sought in a proceeding in equity or at law).

(v) Since its most recent fiscal year end, there has been no change in the business, operations, financial condition, properties or assets of the Seller which would have a Material Adverse Effect on its ability to perform its obligations under the Agreement or any other Transaction Document to which it is a party or materially and adversely affect the transactions contemplated under the Agreement or such other Transaction Documents.

2. Representations and Warranties of UGI (including in its capacity as the Servicer) . UGI, individually and in its capacity as the Servicer, represents and warrants as follows:

(a) UGI is a corporation limited liability company duly formed and validly subsisting

under the laws of the Commonwealth of Pennsylvania and is duly qualified to do business and is in good standing as a foreign corporation limited liability company in every jurisdiction where the
nature of its business requires it to be so qualified, except (i) for the District of Columbia and the State of New York, in which jurisdictions the Servicer shall be qualified within 90 days after the Closing Date and (ii) where the failure to be so qualified would not have a Material Adverse Effect.

(b) The execution, delivery and performance by UGI of its obligations under the Agreement and the other Transaction Documents to which it is a party, including UGI in its capacity as the Servicer: (i) are within its corporate organizational powers; (ii) have been duly authorized by all necessary corporate organizational action; (iii) do not contravene or result in a default under or conflict with: (A) its charter or bylaws limited liability company operating agreement , (B) any law, rule or regulation applicable to it, (C) any indenture, loan agreement, mortgage, deed of trust or other material agreement or instrument to which it is a party or by which it is bound, or (D) any order, writ, judgment, award, injunction or decree binding on or affecting it or any of its property; and (iv) do not result in or require the creation of any Adverse Claim upon or with respect to any of its properties. The Agreement and the other Transaction Documents to which UGI is a party have been duly executed and delivered by UGI.

(c) No authorization, approval or other action by, and no notice to or filing with any Governmental Authority or other Person, is required for the due execution, delivery and performance by UGI of its obligations under the Agreement or any other Transaction Document to which it is a party.

(d) Each of the Agreement and the other Transaction Documents to which UGI is a party constitutes the legal, valid and binding obligation of UGI enforceable against UGI in accordance with its terms, except as enforceability may be limited by bankruptcy, insolvency, reorganization or other similar laws from time to time in effect affecting the enforcement of creditors’ rights generally and by general principles of equity, regardless of whether such enforceability is considered in a proceeding in equity or at law.

(e) The balance sheets of UGI and its consolidated Subsidiaries as at September 30, 2001, and the related statements of income and retained earnings for the fiscal year then ended, copies of which have been furnished to the Administrator, fairly present the financial condition of UGI and its consolidated Subsidiaries as at such date and the results of the operations of UGI and its Subsidiaries for the period ended on such date, all in accordance with GAAP consistently applied, and since September 30, 2001 there has been no event or circumstances which have had a Material Adverse Effect.

(f) Except as disclosed in the most recent audited financial statements of UGI furnished to the Administrator or as otherwise disclosed in writing to the Administrator, there is no pending or, to its best knowledge, threatened action or proceeding affecting it or any of its Subsidiaries before any Governmental Authority or arbitrator that could reasonably be expected to have a Material Adverse Effect.

(g) No proceeds of any purchase or reinvestment will be used to acquire any equity security of a class that is registered pursuant to Section 12 of the Securities Exchange Act of

1934.
EXHIBIT IV COVENANTS

3. Covenants of the Seller . Until the latest of the Facility Termination Date, the date on which no Capital of or Discount in respect of the Purchased Interest shall be outstanding or the date all other amounts owed by the Seller under the Agreement to the Issuer, the Administrator and any other Indemnified Party or Affected Person shall be paid in full:

(a) Compliance with Laws, Etc. The Seller shall comply in all material respects with all applicable laws, rules, regulations and orders, and preserve and maintain its corporate existence, rights, franchises, qualifications and privileges, except to the extent that the failure so to comply with such laws, rules, regulations or orders or the failure so to preserve and maintain such rights, franchises, qualifications and privileges would not have a Material Adverse Effect.

(b) Offices, Records and Books of Account, Etc. The Seller: (i) shall keep its principal place of business and chief executive office (as such terms or similar terms are used in the UCC) and the office where it keeps its records concerning the Receivables at the address of the Seller set forth under its name on the signature page to the Agreement or, pursuant to clause (l)(v) below, at any other locations in jurisdictions where all actions reasonably requested by the Administrator to protect and perfect the interest of the Issuer in the Receivables and related items (including the Pool Assets) have been taken and completed and (ii) shall provide the Administrator with at least 30 days’ written notice before making any change in the Seller’s name or making any other change in the Seller’s identity or corporate structure (including a Change in Control) that could render any UCC financing statement filed in connection with this Agreement “seriously misleading” as such term (or similar term) is used in the UCC; each notice to the Administrator pursuant to this sentence shall set forth the applicable change and the effective date thereof. The Seller also will maintain and implement (or cause the Servicer to maintain and implement) administrative and operating procedures (including an ability to recreate records evidencing Receivables and related Contracts in the event of the destruction of the originals thereof), and keep and maintain (or cause the Servicer to keep and maintain) all documents, books, records, computer tapes and disks and other information reasonably necessary or advisable for the collection of all Receivables (including records adequate to permit the daily identification of each Receivable and all Collections of and adjustments to each existing Receivable).

(c) Performance and Compliance with Contracts and Credit and Collection Policy . The Seller shall (and shall cause the Servicer to), at its expense, timely and fully perform and comply with all material provisions, covenants and other promises required to be observed by it under the Contracts related to the Receivables, and timely and fully comply in all material respects with the applicable Credit and Collection Policies with regard to each Receivable and the related Contract.

(d) Ownership Interest, Etc . The Seller shall (and shall cause the Servicer to), at its expense, take all action necessary or desirable to establish and maintain a valid and enforceable undivided percentage ownership or security interest, to the extent of the Purchased Interest, in the Pool Receivables, the Related Security and Collections with respect thereto, and a first priority

minimal obligations to the extent necessary for the day-to-day operations of the Seller (such as expenses for stationery, audits, maintenance of legal status, etc.).

(p) Use of Seller’s Share of Collections . The Seller shall apply the Seller’s Share of Collections to make payments in the following order of priority: (i) the payment of its expenses (including all obligations payable to the Issuer and the Administrator under the Agreement and under the Fee Letter); and (ii) other legal and valid corporate purposes.

(q) Tangible Net Worth . The Seller will not permit its Tangible Net Worth, at any time, to be less than $6,000,000.

4. Covenants of the Servicer and UGI . Until the latest of the Facility Termination Date,
the date on which no Capital of or Discount in respect of the Purchased Interest shall be outstanding or the date all other amounts owed by the Seller under the Agreement to the Issuer, the Administrator and any other Indemnified Party or Affected Person shall be paid in full:

(a) Compliance with Laws, Etc. The Servicer and, to the extent that it ceases to be the Servicer, UGI shall comply (and shall cause the Originator to comply) in all material respects with all applicable laws, rules, regulations and orders, and preserve and maintain its corporate organizational existence, rights, franchises, qualifications and privileges, except to the extent that the failure so to comply with such laws, rules, regulations or orders or the failure so to preserve and maintain such existence, rights, franchises, qualifications and privileges would not have a Material Adverse Effect.

(b) Offices, Records and Books of Account, Etc. The Servicer and, to the extent that it ceases to be the Servicer, UGI, shall keep (and shall cause the Originator to keep) its principal place of business and chief executive office (as such terms or similar terms are used in the applicable UCC) and the office where it keeps its records concerning the Receivables at the address of the Servicer set forth under its name on the signature page to the Agreement or, upon at least 30 days’ prior written notice of a proposed change to the Administrator, at any other locations in jurisdictions where all actions reasonably requested by the Administrator to protect and perfect the interest of the Issuer in the Receivables and related items (including the Pool Assets) have been taken and completed. The Servicer and, to the extent that it ceases to be the Servicer, UGI, also will (and will cause the Originator to) maintain and implement administrative and operating procedures (including an ability to recreate records evidencing Receivables and related Contracts in the event of the destruction of the originals thereof), and keep and maintain all documents, books, records, computer tapes and disks and other information reasonably necessary or advisable for the collection of all Receivables (including records adequate to permit the daily identification of each Receivable and all Collections of and adjustments to each existing Receivable).

(c) Performance and Compliance with Contracts and Credit and Collection Policy . The Servicer and, to the extent that it ceases to be the Servicer, UGI, shall (and shall cause the Originator to), at its expense, timely and fully perform and comply with all material provisions, covenants and other promises required to be observed by it under the Contracts related to the Receivables, and timely and fully comply in all material respects with the Credit and Collection Policy with regard to each Receivable and the related Contract.

Exchange Commission that have been granted “confidential” treatment shall be provided promptly after such filings have become publicly available;

(vi) promptly after the filing or receiving thereof, copies of all reports and notices that UGI or any of its Affiliate files under ERISA with the Internal Revenue Service, the Pension Benefit Guaranty Corporation or the U.S. Department of Labor with respect to any Benefit Plan that is subject to Title IV of ERISA or that UGI or any of its Affiliates receives with respect to any Benefit Plan that is subject to Title IV of ERISA from any of the foregoing or from any multiemployer plan (within the meaning of Section 4001(a)(3) of ERISA) to which UGI or any of its Affiliate is or was, within the preceding five years, a contributing employer, in each case in respect of the assessment of withdrawal liability or an event or condition that could, in the aggregate, reasonably result in the imposition of material liability on UGI and/or any such Affiliate;

(vii) at least thirty days before any change in UGI’s or the Originator’s name or
any other change requiring the amendment of UCC financing statements, a notice setting forth such changes and the effective date thereof;

(viii) promptly after UGI obtains knowledge thereof, notice of any: (A) litigation, investigation or proceeding that may exist at any time between UGI or any of its Subsidiaries and any Governmental Authority that, if not cured or if adversely determined, as the case may be, would have a Material Adverse Effect; (B) litigation or proceeding adversely affecting UGI or any of its Subsidiaries in which the amount involved is $1,000,000 or more and not covered by insurance or in which injunctive or similar relief is sought; or (C) litigation or proceeding relating to any Transaction Document;

(ix) promptly after becoming aware thereof, notice of a material adverse change in the business, operations, property or financial or other condition of UGI or any of its Subsidiaries; and

(x) such other information respecting the Receivables or the condition or operations, financial or otherwise, of UGI or any of its Affiliates as the Administrator may from time to time reasonably request.

(k) Net Worth . At any time of determination, the net worth (as adjusted to eliminate the impact of any charges related to SFAS 133) of the Servicer shall not be less than the lesser of (a)
$93,000,000 or (b) $93,000,000 less an amount equal to the sum of all dividends paid by the Servicer from June 30, 2004 through such time; provided , however , that at no time shall the net worth (as adjusted above) of the Servicer (as reduced by all such dividends paid during the period referred to above) be less than $40,000,000.

5. Separate Existence . Each of the Seller and UGI hereby acknowledges that the Purchasers, the Issuer and the Administrator are entering into the transactions contemplated by this Agreement and the other Transaction Documents in reliance upon the Seller’s identity as a legal entity separate from UGI and its Affiliates. Therefore, from and after the date hereof, each of the Seller and UGI shall take all steps specifically required by the Agreement or reasonably

EXHIBIT V TERMINATION EVENTS

Each of the following shall be a “Termination Event”:

(a) (i) the Seller, UGI, the Originator or the Servicer (if UGI or any of its Affiliates) shall fail to perform or observe in any material respect any term, covenant or agreement under the Agreement or any other Transaction Document and, except as otherwise provided herein, such failure shall continue for thirty days after knowledge or notice thereof, (ii) the Seller or the Servicer shall fail to make when due any payment or deposit to be made by it under the Agreement and such failure shall continue unremedied for two (2) Business Days or (iii) UGI shall resign as Servicer, and no successor Servicer reasonably satisfactory to the Administrator shall have been appointed;

(b) UGI (or any Affiliate thereof) shall fail to transfer to any successor Servicer when required any rights pursuant to the Agreement that UGI (or such Affiliate) then has as Servicer;

(c) any representation or warranty made or deemed made by the Seller, UGI or the Originator (or any of their respective officers) under or in connection with the Agreement or any other Transaction Document, or any written information or report delivered by the Seller, UGI or the Originator or the Servicer pursuant to the Agreement or any other Transaction Document, shall prove to have been incorrect or untrue in any respect when made or deemed made (pursuant to paragraph 2(b) of Exhibit II hereof or with respect to any Information Package) or delivered; provided , however , if the violation of this paragraph (c) by the Seller or the Servicer may be cured without any potential or actual detriment to the Purchaser, Issuer or the Administrator, or any Program Support Provider, the Seller or the Servicer , as applicable , shall have 30 days from the earlier of (i) such Person’s knowledge of such failure and (ii) notice to such Person of such failure to cure any such violation, before a Termination Event shall occur so long as such Person is diligently attempting to effect such cure;

(d) the Seller or the Servicer shall fail to deliver the Information Package pursuant to the
Agreement, and such failure shall remain unremedied for two Business Days;

(e) the Agreement or any purchase or reinvestment pursuant to the Agreement shall for
any reason: (i) cease to create, or the Purchased Interest shall for any reason cease to be, a valid and enforceable perfected undivided percentage ownership or security interest to the extent of the Purchased Interest in each Pool Receivable, the Related Security and Collections with respect thereto, free and clear of any Adverse Claim, or (ii) cease to create with respect to the Pool Assets, or the interest of the Issuer with respect to such Pool Assets shall cease to be, a valid and enforceable first priority perfected security interest, free and clear of any Adverse Claim;

(f) (i) the (A) Default Ratio shall exceed 2.25% or (B) Delinquency Ratio shall exceed
10.0% or (ii) the average for three consecutive calendar months of (A) the Default Ratio shall exceed 1.50%, (B) the Delinquency Ratio shall exceed 9.0%, (C) the Dilution Ratio shall exceed
1.75% or (iii) Days’ Sales Outstanding exceeds 45 days;

EXHIBIT VI
SUPPLEMENTAL PERFECTION REPRESENTATIONS, WARRANTIES AND COVENANTS

In addition to the representations, warranties and covenants contained in Exhibit III hereof, the Seller hereby makes the following additional representations, warranties and covenants:

1.    Receivables; Lock-box Accounts.
(a) The Pool Receivables constitute “accounts”, “general intangibles” or

“tangible chattel paper”, each within the meaning of the applicable UCC.
(b)

 Lock-Box Accounts. Each Lock-Box Account constitutes a “deposit

account” within the meaning of the applicable UCC.

2.    Creation of Security Interest. The Seller owns and has good and marketable title
to the Pool Receivables and Lock-Box Accounts (and the related lock-boxes), free and clear of any Adverse Claim. The Agreement creates a valid and continuing security interest (as defined in the applicable UCC) in the Pool Receivables and the Lock-Box Accounts (and the related lock-boxes) in favor of the Issuer, which security interest is prior to all other Adverse Claims and is enforceable as such as against any creditors of and purchasers from the Seller.

3.    Perfection.
(a) General. The Seller has or has caused, or will or will cause within ten

days after the date hereof, the filing of all appropriate financing statements in the proper filing office in the appropriate jurisdictions under applicable law in order to perfect the sale of the Pool Receivables from the Originator to the Seller pursuant to the Purchase and Sale Agreement and the security interest granted by the Seller to the Issuer in the Receivables and Lock-Box Accounts (and the related lock-boxes) hereunder.
(b) Tangible Chattel Paper. With respect to any Pool Receivable that

constitutes “tangible chattel paper”, the Servicer is in possession of the original copies of the tangible chattel paper that constitute or evidence such Pool Receivables, and the Seller has filed or has caused the Originator to file, or will file or will cause the Originator to file within ten days after the date hereof, the financing statements described in paragraph (a) above, each of which will contain a statement that: “A purchase of or a grant of a security interest in any property described in this financing statement will violate the rights of the Issuer.” The Pool Receivables to the extent they are evidenced by “tangible chattel paper” do not have any marks or notations indicating that they have been pledged, assigned or otherwise conveyed to any Person other than the Seller or the Issuer.
(c) Lock-Box Accounts. With respect to all Lock-Box Accounts (and all

related lock-boxes), the Seller has delivered to the Administrator, on behalf of the Issuer, a fully executed Lock-Box Agreement pursuant to which the applicable Lock-Box Bank has agreed, following the occurrence and continuation of a Termination Event, to comply with all instructions given by the Administrator with respect to all funds on deposit in such Lock-Box
Account (and all funds sent to the respective lock-box), without further consent by the Seller or the Servicer.

4.    Priority.
(a) Other than the transfer of the Receivables by the Originator to the Seller

pursuant to the Purchase and Sale Agreement and the grant of security interest by the Seller to the Issuer in the Pool Receivables and Lock-Box Accounts (and the related lock-boxes) hereunder, neither the Seller nor the Originator has pledged, assigned, sold, conveyed, or otherwise granted a security interest in any of the Pool Receivables or Lock-Box Accounts (and the related lock-boxes) to any other Person.
(b) Neither the Seller nor the Originator has authorized, or is aware of, any

filing of any financing statement against the Seller or the Originator that includes a description of collateral covering the Pool Receivables or any other Pool Assets, other than any financing statement filed pursuant to the Purchase and Sale Agreement and the Agreement or financing statements that have been validly terminated prior to the date hereof.
(c) The Seller is not aware of any judgment, ERISA or tax lien filings against

either the Seller or the Originator.
(d) None of the Lock-Box Accounts (and the related lock-boxes) are in the

name of any Person other than the Seller or the Issuer. None of the Seller, the Servicer or the Originator has consented to any Lock-Box Bank’s complying with instructions of any person other than the Administrator.

5.    Survival of Supplemental Representations. Notwithstanding any other provision
of the Agreement or any other Transaction Document, the representations contained in this Exhibit VI shall be continuing, and remain in full force and effect until such time as all the Capital has finally been paid in full and all other obligations of the Seller under the Agreement or any other Transaction Documents have been fully performed.

6.     No Waiver. The parties to the Agreement: (i) shall not, without obtaining a
confirmation of the then-current rating of the Notes, waive any of the representations set forth in this Exhibit VI; (ii) shall provide the ratings agencies rating the Notes with prompt written notice of any breach of any representations set forth in this Exhibit VI, and (iii) shall not, without obtaining a confirmation of the then-current rating of the Notes (as determined after any adjustment or withdrawal of the ratings following notice of such breach) waive a breach of any of the representations set forth in this Exhibit VI. [Reserved].

7.    Seller to Maintain Perfection and Priority. In order to evidence the interests of the
Issuer under this Agreement, the Seller shall, from time to time take such action, or execute and deliver such instruments (other than filing financing statements) as may be necessary or advisable (including, without limitation, such actions as are requested by the Administrator on behalf of the Issuer) to maintain and perfect, as a first-priority interest, the Issuer’s security interest in the Pool Assets. The Seller shall, from time to time and within the time limits established by law, prepare and present to the Administrator for the Administrator’s authorization and approval all financing statements, amendments, continuations or initial financing statements in lieu of a continuation
statement, or other filings necessary to continue, maintain and perfect the Purchaser Issuer ’s security interest in the Pool Assets as a first-priority interest. The Administrator’s approval of such filings shall authorize the Seller to file such financing statements under the UCC without the signature of the Seller, the Originator or the Issuer where allowed by applicable law. Notwithstanding anything else in the Transaction Documents to the contrary, neither the Seller, the Servicer, nor the Originator, shall have any authority to file a termination, partial termination, release, partial release or any

amendment that deletes the name of a debtor or excludes collateral of any such financing statements, without the prior written consent of the Administrator, on behalf of the Issuer.

SCHEDULE I
CREDIT AND COLLECTION POLICY

SCHEDULE II
LOCK-BOX BANKS AND LOCK-BOX ACCOUNTS

Lock-Box Bank      Seller      Lock Box No.      Account No.

PNC Bank, National
Association
 
Energy Services Funding
Corporation

SCHEDULE III TRADE NAMES

Corporate Name

 Trade Names / Fictitious Names

Energy Services Funding Corporation

 None

SCHEDULE IV
LOCATION OF RECORDS OF SELLER

460 North Gulph Road
King of Prussia, Pennsylvania 19406-2815

1 Meridian Boulevard
Reading, Pennsylvania 19610

ANNEX A-1 to Receivables Purchase Agreement

FORM OF INFORMATION PACKAGE (Settlement Date)

ANNEX B
to Receivables Purchase Agreement

FORM OF PURCHASE NOTICE

FORM OF PURCHASE NOTICE

     , [ 2001] 20  ]

PNC Bank, National Association
One Three PNC Plaza , 3rd Floor
249
225 Fifth Avenue
Pittsburgh, PA 15222-2707

Ladies and Gentlemen:

Reference is hereby made to the Receivables Purchase Agreement, dated as of November
30, 2001 (as heretofore amended or supplemented, the “ Receivables Purchase Agreement ”), among Energy Services Funding Corporation (“ Seller ”), UGI Energy Services, Inc. LLC , as Servicer , Market Street Funding Corporation (“ Issuer ”) and PNC Bank , National Association , as issuer (the “Issuer”) and as administrator (the “ Administrator ”). Capitalized terms used in this Purchase Notice and not otherwise defined herein shall have the meanings assigned thereto in the Receivables Purchase Agreement.

This letter constitutes a Purchase Notice pursuant to Section 1.2(a) of the Receivables Purchase Agreement. Seller desires to sell pursuant to the Receivables Purchase Agreement an undivided variable percentage interest in a pool of receivables on [  , 200 20  ] , for a

Purchase Price of $__________. Subsequent to this purchase, the aggregate outstanding Capital will be $__________. The pro forma calculation of the Purchased Interest after giving effect to the increase in Capital is [__________________].

Seller hereby represents and warrants as of the date hereof, and as of the date of purchase, as follows:

(i) the representations and warranties contained in Exhibit III of the Receivables Purchase Agreement are correct in all respects on and as of such dates as though made on and as of such dates and shall be deemed to have been made (pursuant to paragraph 2(b) of Exhibit II of the Receivables Purchase Agreement) on such dates (except to the extent that such representations and warranties relate expressly to an earlier date, and in which case such representations and warranties shall be true and correct in all respects as of such earlier date);
(ii) no Termination Event or Unmatured Termination Event has occurred and is continuing, or would result from such purchase;
(iii) after giving effect to the purchase proposed hereby, the Purchased Interest will not exceed 100% and the Capital will not exceed the Purchase Limit;
(iv) no Default Event shall have occurred and is continuing; and
(v) the Facility Termination Date shall not have occurred.

FORM OF PAYDOWN NOTICE

     ,     

PNC Bank, National Association
249 225 Fifth Avenue
Pittsburgh, New York 15222-2707
Attention: John T. Smathers William Falcon

Ladies and Gentlemen:

Reference is hereby made to the Receivables Purchase Agreement, dated as of November
30, 2001 (as amended, supplemented or otherwise modified, the “ Receivables Purchase Agreement ”), among Energy Services Funding Corporation, as Seller, UGI Energy Services, Inc. LLC , as Servicer , Market Street Funding Corporation, as Issuer, and PNC Bank, National Association, as Issuer and as Administrator. Capitalized terms used in this paydown notice and not otherwise defined herein shall have the meanings assigned thereto in the Receivables Purchase Agreement.

This letter constitutes a paydown notice pursuant to Section 1.4(f)(i) of the Receivables

Purchase Agreement. The Seller desires to reduce the Capital on _______, ________ 1 by the application of $__________ in cash to pay Capital and Discount to accrue (until such cash can

be used to pay commercial paper notes) through such date with respect to such Capital, together with all costs related to such reduction of Capital.

1 Notice must be given (i) at least one Business Day prior to the requested paydown date, in the case of reductions of greater than $1,000,000 and less than or equal to $3,000,000; (ii) at least two Business Days prior the requested paydown date, in the case of reductions of greater than $3,000,000 and less than or equal to $10,000,000; and (ii) at least five Business Days prior to the requested paydown date, in the case of reductions of greater than
$10,000,000.

Annex C- 2

TABLE OF CONTENTS

ARTICLE I.
AMOUNTS AND TERMS OF THE PURCHASES

Section 1.1    Purchase Facility      1
Section 1.2    Making Purchases      1
Section 1.3    Purchased Interest Computation      2
Section 1.4    Settlement Procedures      3
Section 1.5    Fees      6
Section 1.6    Payments and Computations, Etc      6
Section 1.7    Increased Costs      6
Section 1.8    Requirements of Law      7
Section 1.9    Inability to Determine Euro-Rate LMIR      8

ARTICLE II.
REPRESENTATIONS AND WARRANTIES; COVENANTS; TERMINATION EVENTS

Section 2.1    Representations and Warranties; Covenants      9
Section 2.2    Termination Events      9

ARTICLE III. INDEMNIFICATION

Section 3.1    Indemnities by the Seller      9
Section 3.2    Indemnities by the Servicer      11
Section 3.3    Notice of Claims      11

	
			
707436045 01917304	Exhibit A	 	

ARTICLE IV. ADMINISTRATION AND COLLECTIONS

Section 4.1    Appointment of the Servicer      12
Section 4.2    Duties of the Servicer      13
Section 4.3    Lock-Box Arrangements      14
Section 4.4    Enforcement Rights      14
Section 4.5    Responsibilities of the Seller      15
Section 4.6    Servicing Fee      15

ARTICLE V. MISCELLANEOUS

Section 5.1    Amendments, Etc      16
Section 5.2    Notices, Etc      16
Section 5.3    Assignability      16
Section 5.4    Costs, Expenses and Taxes      18
Section 5.5    No Proceedings; Limitation on Payments      18
Section 5.6    Confidentiality      18
Section 5.7    GOVERNING LAW AND JURISDICTION      19
Section 5.8    Execution in Counterparts      19
Section 5.9    Survival of Termination      19

i

	
			
707436045 01917304	Exhibit A	 	

EXHIBIT B
UCC-1 FINANCING STATEMENT

(attached)

	
			
707436045 01917304	Exhibit B	 	

EXHIBIT 10.73

AMENDMENT NO. 4
Dated as of October 1, 2013
to
PURCHASE AND SALE AGREEMENT
Dated as of November 30, 2001
This AMENDMENT NO. 4 (this “ Amendment ”) dated as of October 1, 2013 is entered into among ENERGY SERVICES FUNDING CORPORATION, a Delaware corporation (the “ Company ”), and UGI ENERGY SERVICES, LLC (as successor to UGI Energy Services, Inc.), a Pennsylvania limited liability company (the “ Originator ”).
RECITALS
WHEREAS, the parties hereto have entered into a certain Purchase and Sale Agreement dated as of November 30, 2001 (as amended, restated, supplemented or otherwise modified through the date hereof, the “ Agreement ”);
WHEREAS, effective as of the date hereof, (i) UGI Energy Services, Inc. will merge with and into UGI Newco, LLC, a Pennsylvania limited liability company (“ Newco ”), with Newco being the surviving entity and (ii) Newco will amend its name from “UGI Newco, LLC” to “UGI Energy Services, LLC” (such transaction, collectively, the “ Subject Event ”);
WHEREAS, concurrently herewith, Energy Services Funding Corporation, UGI Energy Services, LLC, Market Street Funding LLC and PNC Bank, National Association are entering into that certain Amendment No. 13 to Receivables Purchase Agreement, dated as of October 1, 2013 (the “ RPA Amendment ”); and
WHEREAS, the parties hereto wish to make certain changes to the Agreement as herein provided.
NOW, THEREFORE, in consideration of the promises and the mutual agreements contained herein and in the Agreement, the parties hereto agree as follows:
SECTION 1. Definitions . All capitalized terms not otherwise defined herein are used as defined in the Agreement.
SECTION 2.      Notice; Consent .
2.1      Notice . The Originator hereby provides notice of UGI Energy Services, Inc.’s intent to perform and consummate the Subject Event on the date hereof and requests that each of the parties hereto acknowledge and consent to the consummation of such merger and name change effective as of the date hereof.
2.2      Consent . Subject to terms and conditions set forth in this Amendment, each of the parties hereto hereby: (i) acknowledges such notice set forth in Section 2.1 above, (ii) consents to

	

consummation of the Subject Event on the date hereof and (iii) waives any notice requirement with respect to the Subject Event set forth in the Agreement or any other Transaction Document.
SECTION 3.      Assumption . Effective as of the date hereof, the Originator hereby (i) unconditionally assumes all of UGI Energy Services, Inc.’s rights, duties and obligations under the Agreement and each of the other Transaction Documents and (ii) agrees to be bound by all of the terms and conditions of the Agreement and the Transaction Documents applicable to UGI Energy Services, Inc.
SECTION 4.      Amendments to the Agreement . The Agreement is hereby amended as follows:
4.1      Each reference to “UGI Energy Services, Inc.” in the Agreement is hereby replaced with a reference to “UGI Energy Services, LLC”.
4.2      Each reference to the Originator as a “corporation” in the Agreement is hereby replaced with a reference to the Originator as a “limited liability company”.
4.3      Each reference to “corporate” in the Agreement with respect to the Originator is hereby replaced with a reference to “limited liability company”.
4.4      Schedule 5.14A of the Agreement is hereby replaced with Schedule 5.14A attached hereto.
4.5      Schedule 5.15 of the Agreement is hereby replaced with Schedule 5.15 attached hereto.
SECTION 5.      Representations and Warranties; No Default . The Originator hereby represents and warrants to the Company, the Issuer and the Administrator as follows:
(a)    its representations and warranties contained in Article V of the Agreement (as amended hereby) are true and correct as of the date hereof (unless stated to relate solely to an earlier date, in which case such representations and warranties were true and correct as of such earlier date);
(b)    its execution and delivery by of this Amendment, and the performance of its obligations under this Amendment and the Agreement (as amended hereby) are within its limited liability company powers and have been duly authorized by all necessary limited liability company action on its part, and this Amendment and the Agreement (as amended hereby) are its valid and legally binding obligations, enforceable in accordance with its terms, subject to the effect of bankruptcy, insolvency, reorganization or other similar laws affecting the enforcement of creditors’ rights generally; and
(c)    no Purchase and Sale Termination Event or Unmatured Purchase and Sale Termination Event has occurred, is continuing, or would occur as a result of this Amendment.

	
			
 	2 	 	

SECTION 6.      Miscellaneous .
6.1      Effectiveness . This Amendment shall become effective on the date, provided that each of the following conditions precedent have been satisfied (i) the Administrator and the Company shall have each received counterparts of this Amendment (whether by facsimile or otherwise), executed and delivered by each of the parties hereto and (ii) the RPA Amendment has become effective in accordance with its terms.
6.2      References to Agreement . Upon the effectiveness of this Amendment, each reference in the Agreement to “this Agreement”, “hereunder”, “hereof”, “herein”, or words of like import shall mean and be a reference to the Agreement as amended hereby, and each reference to the Agreement in any other document, instrument or agreement executed and/or delivered in connection with the Agreement shall mean and be a reference to the Agreement as amended hereby.
6.3      Effect on the Agreement . Except as specifically amended above, the Agreement and all other documents, instruments and agreements executed and/or delivered in connection therewith shall remain in full force and effect and are hereby ratified and confirmed.
6.4      No Waiver . The execution, delivery and effectiveness of this Amendment shall not operate as a waiver of any right, power or remedy of any party under the Agreement or any other document, instrument or agreement executed in connection therewith, nor constitute a waiver of any provision contained therein, except as specifically set forth herein.
6.5      Governing Law . This Amendment, including the rights and duties of the parties hereto, shall be governed by, and construed in accordance with, the laws of the State of New York (without giving effect to the conflicts of law principles thereof).
6.6      Successors and Assigns . This Amendment shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors and assigns.
6.7      Headings . The Section headings in this Amendment are inserted for convenience of reference only and shall not affect the meaning or interpretation of this Amendment or any provision hereof.
6.8      Counterparts . This Amendment may be executed by the parties hereto in several counterparts, each of which shall be deemed to be an original and all of which shall constitute together but one and the same agreement.
[Signature Pages Follow]

	
			
 	3 	 	

IN WITNESS WHEREOF, the parties have caused this Amendment to be executed by their respective officers thereunto duly authorized as of the date first above written.
ENERGY SERVICES FUNDING CORPORATION

By:       /s/ Angela K. Rodriguez    
Name:    Angela K. Rodriguez
Title:    Assistant Treasurer
UGI ENERGY SERVICES, LLC

By:       /s/ Angela K. Rodriguez    
Name:    Angela K. Rodriguez
		
Title:	Vice President and
Chief Financial Officer	

	
			
 	1 	Amendment No. 4 to UGI PSA	

CONSENTED TO:

PNC BANK, NATIONAL ASSOCIATION ,
as Administrator

By:       /s/ Mark Falcione _________________
Name:    Mark Falcione
Title:    Executive Vice President

	
			
 	2 	Amendment No. 4 to UGI PSA	

Schedule 5.14A
CHIEF EXECUTIVE OFFICE OF THE ORIGINATOR

				
Originator	Jurisdiction of Organization and Type of Organization	Chief Executive Office	Organizational Identification Number	
UGI Energy Services, LLC	Pennsylvania limited liability company	1100 Berkshire Blvd
Suite 305
Wyomissing, PA 19610	4175358	

	
			
 	1 	 	

Schedule 5.15
TRADE NAMES

			
Current Legal Name	Trade Names	Prior Legal Names	
UGI Energy Services, LLC	GASMARK	UGI Energy Services, Inc.	
	POWERMARK
UGI EnergyLink	UGI Newco, LLC	

	
			
 	Schedule 5.15	 	

EXHIBIT 10.74

AMENDMENT NO. 14
Dated as of November 1, 2013
to
RECEIVABLES PURCHASE AGREEMENT
Dated as of November 30, 2001
This AMENDMENT NO. 14 (this “ Amendment ”) dated as of November 1, 2013 is entered into among ENERGY SERVICES FUNDING CORPORATION, a Delaware corporation, as the seller (the “ Seller ”), UGI ENERGY SERVICES, LLC (as successor to UGI Energy Services, Inc.), a Pennsylvania limited liability company (“ UGI ”), as initial servicer (in such capacity, together with its successors and permitted assigns in such capacity, the “ Servicer ”), and PNC BANK, NATIONAL ASSOCIATION, a national banking association (“ PNC ”), as issuer (together with its successors and permitted assigns, the “ Issuer ”) and as administrator (in such capacity, together with its successors and assigns in such capacity, the “ Administrator ”).
RECITALS
WHEREAS, the parties hereto have entered into that certain Receivables Purchase Agreement, dated as of November 30, 2001 (as amended, supplemented or otherwise modified from time to time, the “ Agreement ”); and
WHEREAS, the parties hereto wish to amend the Agreement as set forth herein;
NOW, THEREFORE, in consideration of the promises and the mutual agreements contained herein and in the Agreement, the parties hereto agree as follows:
SECTION 1. Definitions . All capitalized terms used but not otherwise defined herein are used herein as defined in the Agreement.
SECTION 2.      Amendments to the Agreement . The Agreement is hereby amended as follows:
(a)      Clause (a) of the definition of “Facility Termination Date” set forth in Exhibit I to the Agreement is hereby amended by replacing the date “November 1, 2013” where it appears therein with the date “October 31, 2014”.
(b)      The definition of “Purchase Limit” set forth in Exhibit I to the Agreement is replaced in its entirety with the following:
“Purchase Limit” means (i) at any time on or after November 1, 2013 and prior to but excluding June 2, 2014, $150,000,000 and (ii) at any time on and after June 2, 2014, $75,000,000, in each case, as such amount may be subsequently reduced pursuant to Section 1.1(b) of the Agreement; provided , that any such reduction of the Purchase Limit then in effect pursuant

	

to clauses (i) or (ii) above, as applicable, shall automatically and permanently reduce the amount of the Purchase Limit set forth in such other clauses above in the same proportion as the percentage of the reduction of the Purchase Limit then in effect. References to the unused portion of the Purchase Limit shall mean, at any time, the Purchase Limit minus the then outstanding Capital.
SECTION 3.      Certain Representations, Warranties and Covenants . Each of the Seller, UGI and the Servicer, as to itself, hereby represents and warrants that:
(a)      the representations and warranties of such Person contained in Exhibit III to the Agreement (as amended hereby) are true and correct as of the date hereof (unless stated to relate solely to an earlier date, in which case such representations and warranties were true and correct as of such earlier date);
(b)      the execution and delivery by such Person of this Amendment, and the performance of its obligations under this Amendment and the Agreement (as amended hereby) are within its organizational powers and have been duly authorized by all necessary organizational action on its part, and this Amendment and the Agreement (as amended hereby) are its valid and legally binding obligations, enforceable in accordance with its terms, subject to the effect of bankruptcy, insolvency, reorganization or other similar laws affecting the enforcement of creditors’ rights generally; and
(c)      no Termination Event or Unmatured Termination Event has occurred, is continuing, or would occur as a result of this Amendment.
SECTION 4.      Effectiveness . This Amendment shall become effective as of the date hereof provided that the Administrator shall have received (a) counterparts of this Amendment (whether by facsimile or otherwise), executed and delivered by each of the parties hereto, (b) a certificate of the Secretary or Assistant Secretary of UGI and the Seller certifying the names and true signatures of its officers who are authorized to sign this Amendment and the other Transaction Documents and (c) certified copies of the resolutions of the Board of Managers of UGI and the Seller authorizing the execution, delivery and performance by UGI and the Seller, of this Amendment and the Agreement.
SECTION 5.      References to Agreement . Upon the effectiveness of this Amendment, each reference in the Agreement to “this Agreement”, “hereunder”, “hereof”, “herein”, or words of like import shall mean and be a reference to the Agreement as amended hereby, and each reference to the Agreement in any other document, instrument or agreement executed and/or delivered in connection with the Agreement shall mean and be a reference to the Agreement as amended hereby.
SECTION 6.      Effect on the Agreement . Except as specifically amended above, the Agreement and all other documents, instruments and agreements executed and/or delivered in connection therewith shall remain in full force and effect and are hereby ratified and confirmed.

	
			
 	2 	 	

SECTION 7.      No Waiver . The execution, delivery and effectiveness of this Amendment shall not operate as a waiver of any right, power or remedy of any party under the Agreement or any other document, instrument or agreement executed in connection therewith, nor constitute a waiver of any provision contained therein, except as specifically set forth herein.
SECTION 8.      Governing Law . THIS AMENDMENT, INCLUDING THE RIGHTS AND DUTIES OF THE PARTIES HERETO, SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE INTERNAL LAWS OF THE STATE OF NEW YORK (INCLUDING FOR SUCH PURPOSE SECTION 5-1401 AND 5-1402 OF THE GENERAL OBLIGATIONS LAW OF THE STATE OF NEW YORK).
SECTION 9.      Successors and Assigns . This Amendment shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors and assigns.
SECTION 10.      Headings . The Section headings in this Amendment are inserted for convenience of reference only and shall not affect the meaning or interpretation of this Amendment or any provision hereof.
SECTION 11.      Counterparts . This Amendment may be executed by the parties hereto in several counterparts, each of which shall be deemed to be an original and all of which shall constitute together but one and the same agreement. Delivery of an executed counterpart of a signature page to this Amendment by facsimile or electronic transmission shall be effective as delivery of a manually executed counterpart hereof.
SECTION 12.      Severability . Each provision of this Amendment shall be severable from every other provision of this Amendment for the purpose of determining the legal enforceability of any provision hereof, and the unenforceability of one or more provisions of this Amendment in one jurisdiction shall not have the effect of rendering such provision or provisions unenforceable in any other jurisdiction.
[Signature Pages Follow]

	
			
 	3 	 	

IN WITNESS WHEREOF, the parties have caused this Amendment to be executed by their respective officers thereunto duly authorized as of the date first above written.
ENERGY SERVICES FUNDING CORPORATION

By: ____________________________
Name:    Angela K. Rodriguez
Title:    Assistant Treasurer

UGI ENERGY SERVICES, LLC

By: ____________________________
Name:    Angela K. Rodriguez
Title:    Vice President and Chief Financial Officer

S- 1      Amendment No. 14 to
Receivables Purchase Agreement (UGI)

PNC BANK, NATIONAL ASSOCIATION ,
as Issuer and Administrator

By:__________________________________
Name:    
Title:    

         
S- 2      Amendment No. 14 to
Receivables Purchase Agreement (UGI)

EXHIBIT 21

SUBSIDIARIES OF UGI CORPORATION

	

SUBSIDIARY	 
   OWNERSHIP	   STATE OF
   INCORPORATION	
AMERIGAS, INC.	100%	PA	
AMERIGAS PROPANE, INC.	100%	PA	
AmeriGas Partners, L.P.	(1)	DE	
AmeriGas Finance Corp.	100%	DE	
AmeriGas Eagle Finance Corp.	100%	DE	
AP Eagle Finance Corp.	100%	DE	
AmeriGas Finance LLC	100%	DE	
AmeriGas Propane, L.P.	(2)	DE	
AmeriGas Propane Parts & Service, Inc.	100%	PA	
Heritage Energy Resources, LLC	100%	OK	
M-P Oils, Ltd.	100%	CANADA	
AmeriGas Eagle Holdings, Inc. (CP Holdings, Inc.)	100%	DE	
AmerE Holdings, Inc.	100%	DE	
Active Propane of Wisconsin, LLC	100%	DE	
902 Gilbert Street, LLC	100%	NC	
Metro Lawn, LLC	100%	DE	
AmeriGas Technology Group, Inc.	100%	PA	
Petrolane Incorporated	100%	PA	
FOUR FLAGS DRILLING COMPANY, INC.	100%	PA	
ASHTOLA PRODUCTION COMPANY	100%	PA	
UGI ETHANOL DEVELOPMENT CORPORATION	100%	PA	
NEWBURY HOLDING COMPANY	100%	DE	
UGI ENTERPRISES, INC.	100%	PA	
EASTFIELD INTERNATIONAL HOLDINGS, INC.	100%	DE	
EUROGAS HOLDINGS, INC.	100%	DE	
UGI BLACK SEA ENTERPRISES, INC.	100%	PA	
UGI CHINA, INC.	100%	DE	
UGI ENERGY SERVICES, LLC (d/b/a UGI EnergyLink, d/b/a GASMARK ®  and d/b/a POWERMARK)	100%	PA	
Energy Services Funding Corporation	100%	DE	
Hellertown Pipeline Company	100%	PA	
Homestead Holding Company	100%	DE	
UGI Asset Management, Inc.	100%	DE	
UGI Development Company	100%	PA	
UGID Holding Company	100%	DE	
UGI Hunlock Development Company	100%	PA	
UGI LNG, Inc.	100%	DE	
UGI Marcellus, LLC	100%	DE	
UGI Storage Company	100%	PA	
UGI HVAC ENTERPRISES, INC.	100%	DE	

1

	

SUBSIDIARY	 
   OWNERSHIP	   STATE OF
   INCORPORATION	
UGI INTERNATIONAL (CHINA), INC.	100%	DE	
UGI INTERNATIONAL (ROMANIA), INC.	100%	PA	
UGI INTERNATIONAL ENTERPRISES, INC.	100%	PA	
UGI Europe, Inc.	100%	DE	
UGI International Holdings BV	100%	NETHERLANDS	
Flaga GmbH (3)	100%	AUSTRIA	
Flaga Supply and Services GmbH (Austria)	100%	AUSTRIA	
               Kosan Gas A/S	100%	DENMARK	
Kosan Gas Sverige AB	100%	SWEDEN	
Kosan Gas Norge A/S	100%	NORWAY	
Kosan Gas Finland Oy	100%	FINLAND	
Flaga Suisse GmbH	100%	SWITZERLAND	
Zentraleuropa LPG Holding GmbH	100%	AUSTRIA	
AmeriGas Polska Sp. z.o.o.	100%	POLAND	
Newco LPG Sp. z.o.o.	100%	POLAND	
Flaga GPL Romania S.r.l.	100%	ROMANIA	
    SC Carpatgas S.R.L.	(4)	ROMANIA	
Flaga LPG SA	77.99%	ROMANIA	
Flaga s.r.o.	100%	CZECH REPUBLIC	
LPG Technik spol s.r.o.	100%	CZECH REPUBLIC	
Propantrans s.r.o.	50%	CZECH REPUBLIC	
Flaga spol s.r.o.	100%	SLOVAKIA	
ECO Energy Service spol s.r.o.	100%	SLOVAKIA	
Flaga Gaz Magyarorszag Kft.	100%	HUNGARY	
UGI Bordeaux Holding	100%	FRANCE	
Antargaz Belgium N.V.	(5)	BELGIUM	
Antargaz Nederland B.V.	100%	NETHERLANDS	
Antargaz Luxembourg S.A.	100%	LUXEMBOURG	
Gasbottling N.V.	(6)	BELGIUM	
Energy Sud S.A.	(7)	BELGIUM	
AGZ Holding	100%	FRANCE	
 Antargaz (8)	100%	FRANCE	
 Aquitaine Rhone Gaz	100%	FRANCE	
Gaz Energie Distribution	100%	FRANCE	
Norgal	52.66%	FRANCE	
Rhone Gaz	50.62%	FRANCE	
Sigap Ouest	66%	FRANCE	
Sobegal	72%	FRANCE	
 Engas (Andorre)	29.47%	FRANCE	
 Gie Donges	50%	FRANCE	
 Cobogal	15%	FRANCE	
 SP Queven	50%	FRANCE	
 Geovexin	44.9%	FRANCE	
 Groupement Technique Citernes	16.67%	FRANCE	

2

	

SUBSIDIARY	 
   OWNERSHIP	   STATE OF
   INCORPORATION	
 Geogaz	16.67%	FRANCE	
UGI Midlands Limited	100%	UNITED KINGDOM	
AvantiGas Limited	100%	UNITED KINGDOM	
Amazon Gas Limited	100%	UNITED KINGDOM	
UGI ROMANIA, INC.	100%	PA	
UGI PROPERTIES, INC.	100%	PA	
UGI UTILITIES, INC.	100%	PA	
UGI ENERGY VENTURES, INC.	100%	DE	
UGI PENN NATURAL GAS, INC.	100%	PA	
UGI Penn HVAC Services, Inc.	100%	PA	
UGI CENTRAL PENN GAS, INC.	100%	PA	
UGI Central Penn Propane, LLC	100%	PA	
UGI Petroleum Products of Delaware, Inc.	100%	DE	
UGI STONERIDGE I, LLC	100%	DE	
UGI Stoneridge II, LLC	100%	DE	
UNITED VALLEY INSURANCE COMPANY	100%	VT	

(1)	AmeriGas Propane, Inc. and its subsidiary, Petrolane Incorporated, hold a combined 26% (approx.) interest in AmeriGas Partners, L.P.	

(2)	1.0101% owned by AmeriGas Propane, Inc., the General Partner; and 98.9899% owned by AmeriGas Partners, L.P., the Limited Partner.	

(3) A nominal share is held by Reinhard Schoëdlbauer.

(4) 99.996% owned by Flaga GPL Romania S.R.L. and .0004% owned by Zentraleuropa LPG Holding GmbH.

(5) .09% owned by UGI Bordeaux Holding and 99.91% owned by AGZ Holding.

(6) 99.5% owned by Antargaz Belgium N.V. and .5% owned by Antargaz Luxembourg S.A.

(7) 90% owned by Antargaz Belgium N.V. and 10% owned by Antargaz Luxembourg S.A.

(8) A nominal share is held by each of Lon R. Greenberg, Donald J. Groth, Matthew A. Woodward, Eric Naddeo and HC Conseil EURL ( Mr. Hervé Couffin).

3

EXHIBIT 23

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
We hereby consent to the incorporation by reference in the Registration Statements on Form S-8 (Nos. 333-186178, 333-167099, 333-22305, 333-49080, 333-104938, 333-118147 and 333-142010) of UGI Corporation of our report dated December 16, 2013 relating to the financial statements, financial statement schedules and the effectiveness of internal control over financial reporting, which appears in this Form 10‑K.   

/s/ PricewaterhouseCoopers LLP
Philadelphia, PA
December 16, 2013

1

EXHIBIT 31.1
CERTIFICATION
I, John L. Walsh, certify that:

		
1.	I have reviewed this annual report on Form 10-K of UGI Corporation;	

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

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

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

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

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

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

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

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

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

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

			
Date:	December 16, 2013	 	
 	 	/s/ John L. Walsh	
 	 	John L. Walsh	
 	 	President and Chief Executive Officer of
UGI Corporation	

EXHIBIT 31.2
CERTIFICATION
I, Kirk R. Oliver, certify that:

1.	I have reviewed this annual report on Form 10-K of UGI Corporation;	

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

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

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

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

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

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

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

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

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

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

			
Date:	December 16, 2013	 	
 	 	/s/ Kirk R. Oliver	
 	 	Kirk R. Oliver	
 	 	Chief Financial Officer of UGI Corporation	

EXHIBIT 32
Certification by the Chief Executive Officer and Chief Financial Officer
Relating to a Periodic Report Containing Financial Statements

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

(1)	The Company’s annual report on Form 10-K for the period ended September 30, 2013 (the “Form 10-K”) fully complies with the requirements of Section 13(a) of the Securities Exchange Act of 1934, as amended; and	

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

¬¬¬

					
CHIEF EXECUTIVE OFFICER	 	CHIEF FINANCIAL OFFICER	
 	 	 	 	 	
/s/ John L. Walsh	 	/s/ Kirk R. Oliver	
John L. Walsh	 	Kirk R. Oliver	
 	 	 	 	 	
Date:	December 16, 2013	 	Date:	December 16, 2013