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SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
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FORM 10-K
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED SEPTEMBER 30, 1996
Commission file number 1-11071
UGI CORPORATION
(EXACT NAME OF REGISTRANT AS SPECIFIED IN ITS CHARTER)
Pennsylvania 23-2668356
(STATE OR OTHER JURISDICTION OF (I.R.S. EMPLOYER IDENTIFICATION NO.)
INCORPORATION OR ORGANIZATION)
460 North Gulph Road, King of Prussia, PA 19406
(ADDRESS OF PRINCIPAL EXECUTIVE OFFICES) (ZIP CODE)
(610) 337-1000
(REGISTRANT'S TELEPHONE NUMBER, INCLUDING AREA CODE)
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
NAME OF EACH EXCHANGE
TITLE OF CLASS ON WHICH REGISTERED
Common Stock, without par value New York Stock Exchange, Inc.
Philadelphia Stock Exchange, Inc.
SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT: None
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 X NO .
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INDICATE BY CHECK MARK IF DISCLOSURE OF DELINQUENT FILERS PURSUANT TO ITEM 405
OF REGULATION S-K 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. [X]
The aggregate market value of UGI Corporation Common Stock held by
nonaffiliates of the registrant on December 1, 1996 was $721,933,822.
At December 1, 1996 there were 33,163,162 shares of UGI Corporation Common
Stock issued and outstanding.
DOCUMENTS INCORPORATED BY REFERENCE: Portions of the Annual Report to
Shareholders for the year ended September 30, 1996 are incorporated by
reference into Parts I and II of this Form 10-K. Portions of the Proxy
Statement for the Annual Meeting of Shareholders to be held on February 25,
1997 are incorporated by reference into Part III of this Form 10-K.
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TABLE OF CONTENTS
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<S> <C> <C>
PART I BUSINESS PAGE
Items 1 and 2 Business and Properties . . . . . . . . . . . . . . . . . . . . . . . 1
General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Propane Partnership Business . . . . . . . . . . . . . . . . . . . . 2
Utility Operations . . . . . . . . . . . . . . . . . . . . . . . . . 10
UGI Enterprises, Inc. . . . . . . . . . . . . . . . . . . . . . . . . 17
Item 3 Legal Proceedings. . . . . . . . . . . . . . . . . . . . . . . . . . 18
Item 4 Submission of Matters to a Vote of
Security Holders.. . . . . . . . . . . . . . . . . . . . . . . . . . 24
PART II SECURITIES AND FINANCIAL INFORMATION
Item 5 Market for Registrant's Common Equity
and Related Stockholder Matters . . . . . . . . . . . . . . . . . . . 24
Item 6 Selected Financial Data. . . . . . . . . . . . . . . . . . . . . . . 26
Item 7 Management's Discussion and Analysis of
Financial Condition and Results of Operations . . . . . . . . . . . . 27
Item 8 Financial Statements and Supplementary Data . . . . . . . . . . . . . 27
Item 9 Changes in and Disagreements with
Accountants on Accounting and Financial Disclosure. . . . . . . . . . 27
PART III UGI MANAGEMENT AND SECURITY HOLDERS
Item 10 Directors and Executive Officers of the Registrant . . . . . . . . . 27
Item 11 Executive Compensation. . . . . . . . . . . . . . . . . . . . . . . . 27
Item 12 Security Ownership of Certain Beneficial
Owners and Management . . . . . . . . . . . . . . . . . . . . . . . . 27
Item 13 Certain Relationships and Related Transactions . . . . . . . . . . . 30
PART IV ADDITIONAL EXHIBITS, SCHEDULES AND REPORTS
Item 14 Exhibits, Financial Statement Schedules
and Reports on Form 8-K . . . . . . . . . . . . . . . . . . . . . . . 30
Signatures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37
</TABLE>
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PART I: BUSINESS
ITEMS 1 AND 2. BUSINESS AND PROPERTIES
GENERAL
UGI Corporation ("UGI" or the "Company") is a holding company with two
principal lines of business: propane distribution and utilities. The Company's
AmeriGas, Inc. subsidiary ("AmeriGas") conducts the nation's largest retail
propane distribution business through AmeriGas Partners, L.P., a Delaware
limited partnership ("AmeriGas Partners" or, the "Partnership") and its 98.99%
owned subsidiary AmeriGas Propane, L.P. (the "Operating Partnership").
AmeriGas Propane, Inc., a Pennsylvania corporation and a wholly owned
subsidiary of AmeriGas, is the Partnership's sole general partner (the "General
Partner"). The common units of AmeriGas Partners, which represent limited
partner interests, are traded on the New York Stock Exchange under the symbol
"APU." Through its subsidiaries, AmeriGas owns 59% of the Partnership, and the
remaining interest is publicly held. The Company has been in the propane
distribution business since 1959. The Company's utility business is conducted
through its subsidiary, UGI Utilities, Inc. ("Utilities"), which owns and
operates natural gas distribution and electric utilities in Pennsylvania. The
Company has been in the utility business for over 100 years and supplies gas
and electric utility services to approximately 247,000 and 60,000 customers,
respectively.
UGI Enterprises, Inc., a wholly owned UGI subsidiary formed in 1994
("UGI Enterprises"), conducts a retail gas marketing business and evaluates and
develops new business opportunities. Black Sea LPG, L.P. is Enterprises' first
joint venture. The project will create an energy import and distribution
business in Romania. Other joint ventures in international energy markets are
being developed.
UGI was incorporated in Pennsylvania in 1991 as part of the
restructuring of Utilities (formerly, UGI Corporation) into a holding company
system effective April 10, 1992. UGI is not subject to regulation by the
Pennsylvania Public Utility Commission ("PUC"). UGI is also exempt from
registration as a holding company and not otherwise subject to regulation under
the Public Utility Holding Company Act of 1935, except for Section 9(a)(2)
thereof, which relates to the acquisition of voting securities of an electric
or gas utility company. UGI's executive offices are located at 460 North Gulph
Road, King of Prussia, Pennsylvania 19406, and its telephone number is (610)
337-1000. References to "UGI" or the "Company" include its consolidated
subsidiaries unless the context indicates otherwise. Similarly, references to
"AmeriGas Partners" and the "Partnership" include the Operating Partnership,
its predecessors and its subsidiaries.
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PROPANE PARTNERSHIP BUSINESS
The Company's propane distribution business is conducted through
AmeriGas Partners. The Partnership is the largest retail propane distributor
in the United States, with over 600 district locations in 44 states at
September 30, 1996. Wholly owned subsidiaries of the Company hold an aggregate
59% interest in the Partnership, including the sole general partner interest in
each of AmeriGas Partners and the Operating Partnership.
BACKGROUND
On July 15, 1993, AmeriGas acquired a significant equity interest in,
and other UGI subsidiaries assumed management of, Petrolane Incorporated
("Petrolane"). The Petrolane acquisition expanded substantially the size of
the propane distribution network under the Company's management. From July 15,
1993 to April 19, 1995, the Company's investment in Petrolane was accounted for
by the equity method, under which the investment was recorded at cost and
adjusted by the Company's share (originally, approximately 30%) of Petrolane's
undistributed income or loss. On April 19, 1995, Petrolane became a wholly
owned subsidiary of the General Partner, and through a series of related
transactions, all of the propane businesses of AmeriGas, including Petrolane,
were transferred to the Operating Partnership (the "Partnership Formation").
Although the Company's consolidated financial statements now include 100% of
the Partnership's revenues and assets, the Company's net income reflects only
its 59% share in the income or loss of the Partnership, due to the public's
limited partner interest in the Partnership.
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 its detection. Propane is clean burning, producing negligible
amounts of pollutants when properly consumed.
The primary customers for propane are residential, commercial,
agricultural, engine fuel and industrial users to whom natural gas is not
readily available. Customers use propane primarily for home heating, water
heating, cooking, engine fuel and process applications. Propane is typically
more expensive than natural gas, competitive with fuel oil when operating
efficiencies are taken into account and, in most areas, cheaper than
electricity on an equivalent energy basis. Several states have adopted or are
considering proposals that would substantially deregulate the electric utility
industry and thereby permit retail electric customers to choose their electric
supplier. Proponents of electric utility deregulation believe that competition
will ultimately reduce the cost of electricity. The Company is unable to
predict the impact that electric utility deregulation may have on propane's
competitive price advantage over electricity.
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PRODUCTS, SERVICES AND MARKETING
As of September 30, 1996, the Partnership distributed propane to
approximately 968,000 customers from over 600 district locations in 44 states.
The Partnership's operations are located primarily in the Northeast, Southeast,
Great Lakes and West Coast regions of the United States. From many of its
district locations, the Partnership also sells, installs and services equipment
related to its propane distribution business, including heating and cooking
appliances and, at some locations, propane fuel systems for motor vehicles.
Typically, district locations are found in suburban and rural areas where
natural gas is not available. Districts generally consist of an office,
appliance showroom, warehouse and service facilities, with one or more 18,000
to 30,000 gallon storage tanks on the premises. The Partnership also engages
in the business of delivering liquified petroleum gases by truck as a common
carrier. The Partnership operates as an interstate carrier in 49 states
throughout the United States, and as an intrastate carrier in 46 states. It is
also licensed as a carrier in Canada; a license is pending in Mexico. The
Partnership's trucking capacity is part of its overall transportation and
distribution infrastructure which is utilized in the conduct of its business.
The Partnership sells propane primarily to five markets: residential,
commercial/industrial, engine fuel, agricultural and wholesale. Approximately
73% of the Partnership's 1996 fiscal year sales (based on gallons sold) were to
retail accounts (31% to residential customers, 27% to industrial/commercial
customers, 9% to engine fuel customers and 6% to agricultural customers), and
approximately 27% were to wholesale customers. Sales to residential customers
in fiscal 1996 represented approximately 42% of retail gallons sold and 54% of
the Partnership's total margin. No single customer accounts for 10% or more of
the Partnership's consolidated revenues.
In the residential market, which includes both conventional and mobile
homes, propane is used primarily for home heating, water heating and cooking
purposes. Commercial users, which include motels, hotels, restaurants and
retail stores, generally use propane for the same purposes as residential
customers. As an engine fuel, propane is burned in internal combustion engines
that power over-the-road vehicles, forklifts and stationary engines.
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. Agricultural uses include
tobacco curing, crop drying and poultry brooding.
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 2,200 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 100 gallons to approximately 1,200 gallons, with a typical tank
having a capacity of 300 to 400 gallons. The Partnership also delivers propane
to retail customers in portable cylinders, which typically have a capacity of 5
to 25 gallons. When these cylinders are delivered to customers, empty
cylinders are picked up for replenishment at district locations or are filled
in place. In its wholesale operations, the Partnership principally sells
propane to large industrial end-users and other propane distributors.
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PROPANE SUPPLY AND STORAGE
Supplies of propane from the Partnership's sources historically have
been readily available. In the year ended September 30, 1996, the Amoco
companies (Amoco Canada and Amoco USA) and Warren Petroleum Company ("Warren"),
a division of Chevron U.S.A., provided approximately 14% and 12%, respectively,
of the Partnership's total propane supply. Management believes that if supplies
from either source were interrupted, it would be able to secure adequate
propane supplies from other sources without a material disruption of its
operations; however, the cost of procuring replacement supplies might be
materially higher, and at least on a short-term basis, margins could be
affected. Aside from Amoco and Warren, no single supplier provided more than
10% of the Partnership's total domestic propane supply in the fiscal year ended
September 30, 1996. On a regional basis, however, certain suppliers provide 70
to 80% 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 propane supply is purchased from over 175 oil
companies and natural gas processors in the United States and Canada, and the
Partnership also makes purchases on the spot market. The Partnership purchases
approximately 80% of its propane supplies from domestic suppliers.
Approximately 70% of propane purchases by the Partnership in the 1996 fiscal
year were on a contractual basis under one-year agreements subject to annual
renewal, but the percentage of contract purchases will vary from year-to-year
as determined by the General Partner. The General Partner believes that, as
the largest retail propane distributor in the United States, the Partnership
generally will be able to obtain propane supplies at competitive prices. Most
supply contracts provide for pricing based upon posted prices at the time of
delivery or the current prices established at major storage points such as Mont
Belvieu, Texas, or Conway, Kansas. In addition, some agreements provide
maximum and minimum seasonal purchase guidelines. 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 facilities in Arizona, Rhode
Island and several other locations.
Because the Partnership's profitability is sensitive to changes in
wholesale propane costs, management generally seeks to pass on increases in the
cost of propane to customers. There is no assurance, however, that the
Partnership will be able to pass on product cost increases fully, particularly
when product costs rise rapidly, as they did in 1996. For example, the average
Mont Belvieu price per gallon of propane more than doubled between April 1,
1996 ($.34625) and December 3, 1996 ($.70375) as a result of several unrelated
events. Propane inventory levels remained below historic levels during the
second half of fiscal year 1996, following an unusually cold winter in the
eastern United States. Other factors contributing to the reduced industry
inventory levels include a normal 1995-96 winter in Europe, which reduced the
amount of propane available for import, and a midsummer explosion affecting gas
processing plants in Mexico.
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Despite increased product cost, the Partnership expects to be able to
secure adequate supplies for its customers during fiscal year 1997, however,
periods of severe cold weather, supply interruptions, or other unforeseen
events, could result in further increases in product cost. The General Partner
is gradually expanding its product price risk management activities to reduce
the effect of price volatility on its product costs. Current strategies
include the use of contracts to purchase product at fixed prices in the future
and, to some extent, options and propane price swaps.
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The following table shows the average quarterly prices of propane on
the propane spot market during the last five fiscal years at Mont Belvieu,
Texas and Conway, Kansas, two major storage areas.
QUARTERLY PRICE AVERAGES
<TABLE>
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Oct-91 39.588 33.283 Sep 30, 96 50.925 51.588
Jan-92 28.386 23.963 Oct 07, 96 49.550 49.488
Apr-92 31.296 25.939 Oct 14, 96 49.925 49.250
Jul-92 35.508 27.181 Oct 21, 96 53.450 52.963
Oct-92 33.095 33.31 Oct 28, 96 54.266 54.875
1st QRT-93 33.812 37.957 Oct 31, 96 53.215 55.5
2nd QRT-93 33.384 33.102
3rd QRT-93 30.811 33.566
Oct-93 27.352 30.651
1st QRT-94 28.143 26.769
2nd QRT-94 29.076 28.488
3rd QRT-94 29.806 29.092
Oct-94 33.545 30.128
1st QRT-95 32.513 29.496
2nd QRT-95 32.303 30.922
3rd QRT-95 31.172 32.344
Oct-95 32.407 34.564
1st QRT-96 38.028 36.674
2nd QRT-96 35.141 34.979
3rd QRT-96 40.363 40.01
Sep 30-96 49.5 48.675
</TABLE>
COMPETITION
Propane is sold in competition with other sources of energy, some of
which are less costly for equivalent energy value. Propane distributors
compete for customers against suppliers of electricity, fuel oil and natural
gas, principally on the basis of price, availability and portability.
Electricity is a major competitor of propane, but propane generally enjoys a
competitive price advantage over electricity for space heating, water heating
and cooking. As previously stated, the Company is unable to predict the impact
that electric utility deregulation may have on propane's current competitive
price advantage. In the last two decades, many new homes were built to use
electrical heating systems and appliances. Fuel oil is also a major competitor
of propane and is generally less expensive than propane. Operating
efficiencies and other factors such as air quality and environmental
advantages, however, generally make propane competitive with fuel oil as a
heating source. Furnaces and appliances that burn propane will not operate on
fuel oil, and vice versa, and, therefore, a conversion from one fuel to the
other requires the installation of new equipment. Propane serves as an
alternative to natural gas in rural and suburban areas where natural gas is
unavailable or portability of product is required. Natural gas is generally a
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
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propane. However, natural gas pipelines are not present in many regions of the
country where propane is sold for heating and cooking purposes.
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. Based on the most recent information supplied by
the American Petroleum Institute, the 1995 domestic retail market for propane
(annual sales for other than chemical uses) was approximately 9.3 billion
gallons and, according to LP-GAS magazine, the ten largest propane companies
(including AmeriGas Partners) comprise approximately 33% of domestic sales.
The Partnership's retail volume of approximately 855 million gallons in fiscal
year 1996 represented approximately 9% of 1995 total domestic retail sales.
The ability to compete effectively depends on reliability of service,
responsiveness to customers and maintaining competitive retail prices.
Competition can intensify in response to a variety of factors,
including significantly warmer-than-normal weather, higher prices resulting
from extraordinary increases in the cost of propane, and recessionary economic
factors. In the past, AmeriGas Propane has experienced greater than normal
customer losses in certain years when competitive conditions reflected these
factors.
In the engine fuel market, propane competes with gasoline and diesel
fuel. When gasoline prices are high relative to propane, propane competes
effectively. The wholesale propane business is highly competitive. Propane
sales to other retail distributors and large-volume, direct-shipment industrial
end users are price sensitive and frequently involve a competitive bidding
process.
PROPERTIES
As of September 30, 1996, the Partnership owned approximately 60% of
its district locations. In addition, the Partnership subleases three
one-million barrel underground storage caverns in Arizona to store propane and
butane for itself and third parties. The Partnership also leases a 600,000
barrel refrigerated, above-ground storage facility in California, which could
be used in connection with waterborne imports or exports of propane. The
California facility, which the Partnership operates, is currently subleased to
several refiners for the storage of butane. Petrolane, now a wholly owned
subsidiary of the General Partner, owns a 50% interest in a joint venture which
owns a 480,000 barrel storage facility in Virginia. This facility is currently
used by third parties. The Partnership leases a 420,000 barrel storage
facility in Rhode Island, which is owned by a third party. Both the Virginia
and Rhode Island facilities may be used in connection with waterborne imports
of propane and the Virginia facility may be used in connection with exports.
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. The Partnership has a
fleet of approximately 421 transport trucks, of which 206
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are owned by the Partnership, as well as 586 railroad tank cars, of which 21
are owned by the Partnership. In addition, the Partnership utilizes
approximately 2,300 bobtail and rack trucks, of which approximately 53% are
owned, and approximately 1,980 other delivery and service vehicles, of which
approximately 61% are owned. As of September 30, 1996, the Partnership owned
more than 800,000 stationary storage tanks with typical capacities of 300 to
400 gallons and approximately 900,000 portable propane cylinders with typical
capacities of 5 to 25 gallons. The obligations of the Partnership under its
borrowings are secured by liens and mortgages on the Partnership's real and
personal property.
TRADE NAMES; TRADE AND SERVICE MARKS
The Partnership markets propane principally under the "AmeriGas" and
"America's Propane Company" trade name and related service marks. UGI owns,
directly or indirectly, all the right, title and interest in the "AmeriGas" and
"Petrolane" trade names and related trade and service marks. The Partnership
has an exclusive (except for use by AmeriGas and the General Partner),
royalty-free license to use these names and trade and service marks. The
General Partner has discontinued widespread use of the "Petrolane" trade name
and conducts Partnership operations almost exclusively under the "AmeriGas"
and "America's Propane Company" trade names.
UGI, Petrolane and the General Partner each have the option to
terminate their respective license agreements on 12 months' prior notice, or
immediately in the case of the General Partner, 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, UGI, Petrolane and the General Partner will each have
the option to terminate the license agreements immediately upon payment of a
fee equal to the fair market value of the licensed trade names.
SEASONALITY
The Partnership's retail sales volume is seasonal, with approximately
59% of the Partnership's fiscal year 1996 retail sales volume and approximately
90% of its earnings occurring during the five-month peak heating season from
November through March, because many customers use propane for heating
purposes. As a result of this seasonality, sales are concentrated in the
Partnership's first and second fiscal quarters (October 1 through March 31),
and cash receipts are greatest 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 general economic conditions.
Long-term, historic weather data from the National Weather Service Climate
Analysis Center indicate that average annual temperatures have remained
relatively constant over the last 30 years with fluctuations occurring on a
year-to-year basis only. Actual
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weather conditions in the Partnership's various service territories, however,
can vary substantially from historical averages. For information concerning
average annual variations in weather across the Partnership's service
territories, 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, safety and transportation laws and regulations governing the
storage, distribution and transportation of propane. These laws include, among
others, the Resource Conservation and Recovery Act, the Comprehensive
Environmental Response, Compensation and Liability Act ("CERCLA"), the Clean
Air Act, the Occupational Safety and Health Act, the Emergency Planning and
Community Right to Know Act, the Clean Water Act and comparable state statutes.
CERCLA, also known as the "Superfund" law, imposes joint and several liability
without regard to fault or the legality of the original conduct on certain
classes of persons considered to have contributed to the release or threatened
release of a "hazardous substance" into the environment. Propane is not a
hazardous substance within the meaning of federal and state environmental laws.
However, the Partnership owns and operates real property where such hazardous
substances may exist. See Note 12 to the Company's Consolidated Financial
Statements.
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. The Partnership maintains various permits under
environmental laws that are necessary to operate some of its facilities, some
of which may be material to the operations of the Partnership. Management
believes that the 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 the Federal Motor
Carrier Safety Act. These regulations cover the transportation of hazardous
materials and are administered by the United States Department of
Transportation. With respect to general operations, National Fire Protection
Association Pamphlets No. 54 and No. 58, which establish a set of rules and
procedures governing the safe handling of propane, or comparable regulations,
have been adopted as the industry standard in a majority of the states in which
the Partnership operates.
The Natural Gas Safety Act of 1968 required the U.S. Department of
Transportation ("DOT") to develop and enforce minimum safety regulations for
the transportation of gases by pipeline. The DOT's pipeline safety code
applies to, among other things, a propane gas system which supplies 10 or more
customers from a single source, and a propane system, any portion of which is
located in a public place. The code requires operators of all gas systems to
provide
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training and written instructions for employees, establish written procedures
to minimize the hazards resulting from gas pipeline emergencies, and keep
records of inspections and testing. Significant expense could be incurred if
additional safety requirements are imposed that exceed the current DOT
standards.
Future developments, such as stricter safety or environmental laws,
regulations and enforcement policies thereunder, could affect the handling,
transportation, manufacture, use, emission or disposal of propane or solid or
hazardous waste. It is not anticipated that the Partnership's compliance with,
or liabilities, if any, under safety and environmental laws and regulations,
including CERCLA, will have a material adverse effect on the Partnership. To
the extent that there are any environmental liabilities unknown to the
Partnership or safety or environmental laws or regulations are made more
stringent, there can be no assurance that the Partnership's results of
operations will not be materially and adversely affected.
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, 1996, the
General Partner had 5,071 employees, including 241 temporary and part-time
employees.
Approximately two percent of the General Partner's employees are
represented by eleven local labor unions which are affiliated with the
International Brotherhood of Teamsters (9), the United Steelworkers of America
(1) and the Warehouse, Processing and Distribution Workers Union of the
International Longshoremen's and Warehousemen's Union, AFL-CIO (1).
UTILITY OPERATIONS
The Company's utility business is conducted by Utilities, a wholly
owned subsidiary of the Company. Utilities operates its utility business
through two divisions, the gas division ("Gas Utility") and the electric
division ("Electric Utility"). The business conducted by each of these
divisions is described below.
DISTRIBUTION OF NATURAL GAS
Service Area; Revenue Analysis. Gas Utility distributes natural gas
to approximately 247,000 customers in portions of 14 eastern and southeastern
Pennsylvania counties through its distribution system of approximately 4,100
miles of gas mains. The service area consists of approximately 3,000 square
miles and includes the cities of Allentown, Bethlehem, Easton, Harrisburg,
Hazleton, Lancaster, Lebanon and Reading, Pennsylvania. Located in Gas
Utility's
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service area are major production centers for basic industries such as steel
fabrication. For the fiscal years ended September 30, 1996, 1995 and 1994,
revenues of Gas Utility accounted for approximately 25%, 33% and 44%,
respectively, of UGI's total consolidated revenues.
System throughput (the volume of gas sold to customers within Gas
Utility's distribution system, plus the volume of gas transported for such
customers) for the 1996 fiscal year was approximately 85.4 billion cubic feet
("bcf"). System sales of gas accounted for approximately 47% of system
throughput, while gas transported for commercial and industrial customers (who
buy their gas from others) accounted for approximately 53% of system
throughput. Based on industry data for 1995, residential customers account for
approximately 36% of total system throughput by local gas distribution
companies in the United States. By contrast, for the 1996 fiscal year, Gas
Utility's residential customers represented 23% of its total system throughput.
Sources of Supply and Pipeline Capacity. Gas Utility meets its
service requirements by utilizing a diverse mix of natural gas purchase
contracts with producers and marketers, storage and transportation services
from pipeline companies, and its own propane-air and liquefied natural gas
peak-shaving facilities. Purchases of natural gas in the spot market are also
made to reduce costs and manage storage inventory levels. These arrangements
enable Gas Utility to purchase gas from Gulf Coast, mid-continent, Appalachian
and Canadian sources. For the transportation and storage function, Utilities
has agreements with a number of pipeline companies, including Texas Eastern
Transmission Corporation, Columbia Gas Transmission Corporation ("Columbia"),
ANR Pipeline Company, Columbia Gulf Transmission Company, CNG Transmission
Corporation, National Fuel Gas Supply Corporation, Transcontinental Gas
Pipeline Corporation, Trunkline Gas Company, Texas Gas Transmission Corporation
and Panhandle Eastern Pipe Line Company.
Gas Supply Contracts. During the 1996 fiscal year, Gas Utility
purchased approximately 41.8 bcf of natural gas and sold approximately 40.4 bcf
to customers. Gas not sold to customers was used by Gas Utility principally
for storage for later sale to customers. Approximately 23.8 bcf or 57% of the
volumes purchased were supplied under agreements with Mobil Natural Gas Inc.,
Exxon Company USA, Pan Energy Trading L.L.C., Amerada Hess Corp., Natural Gas
Clearinghouse and Midcon Gas Services Corp. The remaining 18.0 bcf or 43% of
gas purchased was supplied by producers and marketers under other arrangements,
including multi-month agreements at spot prices. Certain gas supply contracts
require minimum gas purchases. Each of these agreements, however, either
terminates in fiscal year 1997, or includes provisions which entitle Utilities
to terminate in the event the agreement is not market responsive.
Storage and Peak Shaving. Gas Utility contracts for 10.8 bcf of
seasonal storage with several interstate pipelines. Gas is injected in storage
during the summer and delivered during the winter at combined peak day
capacities of approximately .14 bcf. In Harrisburg, Reading and Bethlehem,
Pennsylvania, Gas Utility operates peak shaving facilities capable of producing
.06 bcf of gas per day from propane air and liquefied natural gas facilities.
These facilities are used to meet winter peak service requirements.
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Seasonal Variation. Approximately 58% of Gas Utility's system
throughput for the 1996 fiscal year occurred during the winter season from
November 1, 1995 through March 31, 1996, because many of its customers use gas
for heating purposes.
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 fuel utilization equipment. Electric utilities in Gas
Utility's service area offer extensive rebate programs, primarily in the new
construction market. Competition with fuel oil dealers is focused on
industrial customers. Gas Utility responds to this competition with marketing
efforts designed to retain and grow its customer base.
In substantially all of its service territory, Gas Utility is the only
regulated gas distribution utility having the right, granted by the PUC or by
law, to provide transportation services. While unregulated gas marketers have
been selling gas to commercial and industrial customers in Gas Utility's
service territory for over 11 years, Gas Utility provides transportation
services for those sales. It is possible, however, for certain large customers
to seek transportation services directly from interstate pipelines, "bypassing"
Utilities, although none have done so. Gas Utility is closely monitoring
certain third-party "bypass" proceedings throughout the United States before
FERC, state agencies and the courts.
Customers representing approximately 22% of the Company's
non-residential system throughput (10% of non-residential revenues) have the
ability to switch to an alternate fuel at any time, and therefore, are served
under flexible, interruptible rates which are competitively priced with respect
to their alternate fuel. Gas Utility's margins from these customers,
therefore, are affected by the spread between the customers' delivered cost of
gas and the customers' delivered alternate fuel cost. In addition, other
customers representing 27% of non-residential system throughput (7% of
non-residential revenues) have locations which afford them the option of
seeking transportation service directly from interstate pipelines, thereby
bypassing Gas Utility. The majority of these customers are served under
transportation contracts having three- to five-year terms. Included in these
two groups are the ten Utilities' customers with the highest volume of system
throughput. Although no single customer represents, or is anticipated to
represent, more than 10% of the total revenues of Gas Utility, the loss of
several of such customers could have a material adverse effect on Gas Utility.
Outlook for Gas Service and Supply. Gas Utility expects to meet the
full requirements of all firm customers through fiscal year 1997 and into the
foreseeable future. Supply mix is diversified and it is delivered pursuant to
various firm transportation and storage arrangements.
During the 1996 fiscal year, Gas Utility supplied transportation
service to three major cogeneration installations. Gas Utility continues to
pursue opportunities to supply natural gas to electric generation projects
located in its service territory. Gas Utility also continues to seek new
residential, commercial and industrial customers for both firm and
interruptible service. In the residential market sector, Gas Utility connected
6,372 additional heating customers during the 1996 fiscal year, a decrease of
4% from the previous year. The decrease in Gas Utility's
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residential activity was primarily due to the severe winter weather which
delayed construction schedules. Approximately 61% of the additions represent
gas customers from the new construction market. The remaining 39% represent
customers converting from other energy sources, primarily oil, and existing
non-heating gas customers who have added gas heating systems to replace other
energy sources. The number of new commercial heating customers was 739, down
from 981 in fiscal year 1995.
Utilities continues to monitor and participate extensively in
third-party proceedings before the Federal Energy Regulatory Commission
("FERC") affecting the rates and the terms and conditions under which Gas
Utility purchases, transports and stores natural gas. Among these proceedings
are those arising out of certain FERC orders and/or pipeline filings which
relate to (i) pipelines' requests to increase their base rates, or change the
terms and conditions of their storage and transportation services; (ii) the
flexibility of the terms and conditions of pipeline service contracts; and
(iii) the relative pricing of pipeline services in a competitive energy market
place.
Gas Utility continues to take the measures it believes necessary, in
negotiations with interstate pipeline and natural gas suppliers and in cases
before regulatory agencies, to assure availability of supply, transportation
and storage alternatives to serve market requirements at the lowest cost
consistent with security of supply considerations. Those measures include
negotiating for additional firm transportation capacity from production areas
on all pipelines serving Gas Utility, arranging for appropriate storage and
peak shaving resources, negotiating with producers for competitively priced
secure gas purchases and aggressively participating in regulatory proceedings
related to transportation rights, costs of service and gas costs.
GENERATION AND DISTRIBUTION OF ELECTRICITY
Service Area; Revenue Analysis. Electric Utility supplies electric
service to approximately 60,000 customers in portions of Luzerne and Wyoming
Counties in northeastern Pennsylvania through a system consisting of
approximately 2,100 miles of transmission and distribution lines and 14
transmission substations. For the 1996 fiscal year, about 54% of sales volume
came from residential customers, 34% from commercial customers and 12% from
industrial customers and others. For the 1996, 1995 and 1994 fiscal years,
revenues of Electric Utility accounted for approximately 4%, 8% and 8%,
respectively, of UGI's total consolidated revenues.
Sources of Supply. Electric Utility distributes electricity which it
generates or purchases from others. Utilities owns and operates Hunlock
generating station located near Kingston, Pennsylvania ("Hunlock Station"), and
has a 1.11% ownership interest in the Conemaugh generating station located near
Johnstown, Pennsylvania ("Conemaugh Station"), which is operated by another
utility. These two coal-fired stations can generate up to 69 megawatts of
electric power for Electric Utility and provided approximately 48% of its
energy requirements during the 1996 fiscal year.
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Coal supplies from various sources will be adequate to meet the
operating needs of Hunlock Station for the foreseeable future. As a result of
improvements made to Hunlock Station, its useful life has been extended to
2004.
Utilities has a long-term power supply agreement with Pennsylvania
Power & Light Company ("PP&L"). Under this agreement, PP&L supplies all the
electric power required by Electric Utility above that provided from other
sources, through February 28, 2008. The cost of electricity supplied by PP&L
is based on PP&L's actual system costs. In December 1993, Utilities entered
into an agreement with Foster Wheeler Power Resources ("Foster Wheeler") to
purchase power from a wood-fired generator which Foster Wheeler plans to
construct. Electric Utility reviews least-cost power supply options on an
annual basis in order to plan for its long-term power supply.
Environmental Factors. The operation of Hunlock Station complies with
the air quality standards of the Pennsylvania Department of Environmental
Resources ("DER") with respect to stack emissions. Under the Federal Water
Pollution Control Act, Utilities has a permit from the DER to discharge water
from Hunlock Station into the North Branch of the Susquehanna River.
The Federal Clean Air Act Amendments of 1990 (the "Clean Air Act
Amendments") impose emissions limitations for certain compounds, including
sulfur dioxide and nitrous oxides. The Conemaugh Station is in compliance with
these standards, and the Hunlock Station is required to meet these emission
standards by 1999.
In compliance with the Clean Air Act Amendments, the DER issued final
Reasonably Available Control Technology ("RACT") regulations for nitrous oxides
in January 1994. These regulations are applicable to Hunlock and Conemaugh
Stations. Utilities' compliance plan for Hunlock Station and Conemaugh Station
compliance plan have both been approved by the DER. Capital expenditures
associated with the RACT regulations are not expected to be material.
More stringent regulation of nitrous oxide omissions at both Hunlock
and Conemaugh Stations may be required due to the actions of the Northeast
Ozone Transport Commission. The Commission was created by the Clean Air Act
Amendments to provide a plan to reduce ground level ozone in the Northeast to a
level acceptable to the U.S. Environmental Protection Agency (the "EPA").
Future actions of the Commission may cause the DER to modify its nitrous oxide
RACT plans and thereby affect the compliance plans of Hunlock and Conemaugh
Stations.
Competition. Electric Utility is the only regulated electric utility
having the right, granted by the PUC or by law, to provide public utility
electric service in its service territory. On December 3, 1996, the Governor
of Pennsylvania signed into law the Electric Generation Customer Choice and
Competition Act ("Customer Choice Act"). The Customer Choice Act permits all
retail electric customers to choose their electric generation supplier.
One-third of the peak load of each customer class of an electric utility will
have the opportunity for direct access to generation suppliers by January 1,
1999, two-thirds of the peak load of each customer class by January 1, 2000,
and all customers will have direct access by January 1, 2001, although the PUC
can delay these implementation dates by a period of up to one year under
certain circumstances.
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The PUC also has authority under the Customer Choice Act to order electric
utilities to submit proposals for retail access pilot programs to begin as of
April 1, 1997.
Additional provisions of the Customer Choice Act establish a mechanism
for claiming the recovery of transition or stranded costs, and establish a rate
cap at the level of rates in effect as of the effective date of the Customer
Choice Act until such time as 100 percent of an electric utility's customers
have the right to choose their electric generation supplier and any charges for
the recovery of transition or stranded costs have been removed from the
electric utility's rates. Under the Customer Choice Act, Electric Utility will
continue to be the only regulated electric utility having the right, granted by
the PUC or by law, to transmit and distribute electric energy in its service
territory. Electric Utility does not expect any material adverse effects on
its operations as a result of the Customer Choice Act or open access wholesale
wheeling (See "Utility Regulation and Rates - FERC Orders 888 and 889") because
it owns relatively low-cost coal generation and purchases the remaining
electric power needs of its system.
Seasonality. Sales of electricity for residential heating purposes
accounted for approximately 24% of the total sales of Electric Utility during
the 1996 fiscal year. Electricity competes with natural gas, oil, propane and
other heating fuels in this use. Approximately 56% of sales occurred in the
six coldest months of the 1996 fiscal year, demonstrating modest seasonality
favoring winter due to the use of electricity for residential heating purposes.
PROPERTIES
Utilities' Mortgage and Deed of Trust constitutes a first lien on
substantially all real and personal property of Utilities.
UTILITY REGULATION AND RATES
FERC Orders 888 and 889. In April 1996, FERC issued Orders No. 888
and 889 which established rules for the use of electric transmission facilities
for wholesale transactions. In compliance with these orders, Electric Utility
filed an open access wholesale electric transmission tariff with FERC on July
9, 1996. In addition, Electric Utility is in the process of renegotiating
certain transmission owner agreements to which it is a party to bring these
agreements into compliance with the requirements of FERC Order 888.
Pennsylvania Public Utility Commission Jurisdiction. Utilities' gas
and electric utility operations are subject to regulation by the PUC as to
rates, terms and conditions of service, accounts, issuance of securities,
contracts and other arrangements with affiliated entities, and various other
matters.
Purchased Gas Cost Rates. Gas Utility's gas service tariff contains
Purchased Gas Cost ("PGC") rates which provide for annual increases or
decreases in the rate per thousand cubic feet ("mcf") which Gas Utility charges
for natural gas sold by it, to reflect Utilities' projected cost of
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purchased gas. In accordance with regulations adopted by the PUC on June 14,
1995, PGC rates may also be adjusted quarterly to reflect actual purchased gas
costs. Each proposed PGC rate is required to be filed with the PUC six 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 which meet that standard. The
PGC mechanism also provides for an annual reconciliation. Utilities has two
PGC rates. PGC (1) is applicable to small, firm, core market customers
consisting of the residential and small commercial and industrial classes; PGC
(2) is applicable to firm, contractual, high-load factor customers served on
three specific rates (Rates BD, BD-L and N/CIAC). In addition, residential
customers maintaining a high load may qualify for the PGC(2) rate. In
accordance with the schedule established by law and PUC regulations, Gas
Utility will file a new PGC tariff on June 3, 1997, to be effective December 1,
1997. When filed, the proposed tariff will reflect estimated PGC
over-collections and under-collections through November 30, 1997.
Energy Cost Rates. Electric Utility's electric service tariff
contains an Energy Cost Rate ("ECR") which permits an adjustment to customers'
monthly charges to reflect annual changes in the cost of purchased power, fuel,
interchange power and the cost of transmitting power purchased from external
sources. Electric Utility's ECR collections are reconciled annually as of
January 31.
Gas Rate Case. On January 27, 1995, Gas Utility filed with the PUC
for an increase in base rates. The PUC approved a settlement of this
proceeding, effective August 31, 1995, resulting in base rates which are
expected to increase annual revenues by $19.5 million. As part of its
settlement with the PUC, Utilities agreed not to file for another gas base rate
increase before January 25, 1997.
Electric Rate Case. On January 26, 1996 Electric Utility filed with
the PUC for a $6.2 million increase in its base rates, to be effective March
26, 1996. On July 18, 1996, the PUC approved a settlement of this proceeding
authorizing a $3.1 million increase in annual revenues. This increase in base
rates became effective on July 19, 1996.
Deferred Fuel Adjustments. Utilities defers the difference between
the amount of revenue recognized, and the applicable purchased gas costs and
purchased power costs incurred, until subsequently billed or refunded to
customers under the PGC and ECR.
State Tax Surcharge Clauses. Utilities' gas and electric 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 Utilities from the effect of increases in most of the
Pennsylvania taxes to which it is subject.
Recent Regulatory Environment. Since December 1982, Utilities has
provided transportation service for commercial and industrial customers who
purchase their gas from others. As previously reported, this unbundled service
accounted for approximately 53% of Utilities' system throughput in
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fiscal year 1996. Certain states, including Pennsylvania, are considering
whether transportation service options should be extended to residential and
small commercial customers, and have begun to approve pilot programs extending
such services on a limited basis. Among the issues to be addressed are the
standards necessary to ensure reliability of future gas supplies, the recovery
of costs of existing gas supplies, relationships with affiliated gas marketers
and consumer education requirements. Utilities is considering a number of
options for addressing the opening of unbundled transportation services to
residential and small commercial customers, including the termination of
bundled retail sales services. Because the PUC currently permits gas costs to
be passed through to customers on a dollar-for-dollar basis, Utilities does not
expect any reduction in revenues from the sale of gas caused by an expansion in
the availability of gas transportation services to have a material negative
impact on its financial condition. See also "UTILITY OPERATIONS - Generation
and Distribution of Electricity - Competition."
UTILITY FRANCHISES
Utilities holds 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 it believes are adequate
to authorize it to carry on its business in substantially all the territory to
which it now renders gas and electric service. Under applicable Pennsylvania
law, Utilities also has certain rights of eminent domain as well as the right
to maintain its facilities in streets and highways in its territories.
OTHER GOVERNMENT REGULATION
In addition to regulation by the PUC, the gas and electric utility
operations of Utilities are subject to various federal, state and local laws
governing environmental matters, occupational health and safety, pipeline
safety and other matters. Certain of Utilities' activities involving the
interstate movement of natural gas, the wheeling of electricity, transactions
with non-utility generators of electricity and other matters, are also subject
to the jurisdiction of FERC.
Utilities 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
Utilities. See ITEM 3. "LEGAL PROCEEDINGS-Environmental Matters." The
electric generation activities of Utilities are also subject to the Clean Air
Act Amendments, the Federal Water Pollution Control Act and comparable state
statutes and regulations. See "UTILITY OPERATIONS-Generation and Distribution
of Electricity-Environmental Factors."
UGI ENTERPRISES, INC.
UGI Enterprises, Inc. is a wholly owned subsidiary of UGI, formed in
1994. Through subsidiaries, UGI Enterprises is developing the energy
businesses described below.
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In 1995, the gas marketing business previously conducted by a
subsidiary of Utilities was transferred to UGI Energy Services, Inc. ("Energy
Services"), a wholly owned subsidiary of UGI Enterprises. Energy Services
conducts this business under the trade name GASMARK. GASMARK is taking
advantage of current trends in deregulation to sell natural gas directly to
commercial and industrial customers. In 1996, GASMARK expanded its marketing
territory beyond the MidAtlantic region to serve customers in Massachusetts,
New York and Ohio. Currently, GASMARK supplies natural gas to more than 700
customers in seven states through the transportation systems of 14 utilities.
During 1996, UGI Enterprises formed a joint venture with affiliates of
Energy Transportation Group, Inc. ("ETG") and North American World Trade, Ltd.
to develop, build and operate a liquified petroleum gas ("LPG") import project
in Romania. ETG operates a major fleet of liquified natural gas ("LNG")
vessels, and North American World Trade, Ltd. is a consulting firm with
Romanian expertise. The joint venture is known as Black Sea LPG, L.P. The
project will include construction of a 26 million gallon refrigerated marine
LPG import terminal and an LPG pipeline with propane-air mixing plants to
deliver propane to Bucharest, Romania's capital. It is expected to begin
operation in 1999. UGI has funded the initial development of the joint
venture through UGI Black Sea Enterprises, Inc., a wholly owned subsidiary of
UGI Enterprises. ETG will be the developer of the project and UGI Black Sea
Enterprises, Inc. will operate the terminal and the propane-air plants.
UGI Enterprises is also pursuing energy development partnerships in
other emerging markets overseas. In these markets, UGI Enterprises' principal
objective is to capitalize on the operating and financing skills of its U.S.
affiliates and apply them in joint ventures with international partners in
potentially high-growth, energy-consuming regions.
BUSINESS SEGMENT INFORMATION
The table stating the amounts of revenues, operating income (loss) and
identifiable assets attributable to each of UGI's industry segments for the
1996, 1995 and 1994 fiscal years appears on page 20 of UGI's 1996 Annual Report
to Shareholders and is incorporated in this Report by reference.
EMPLOYEES
At September 30, 1996, UGI and its subsidiaries had 6,371 employees.
ITEM 3. LEGAL PROCEEDINGS
With the exception of the matters set forth below, no material legal
proceedings are pending involving UGI, any of its subsidiaries or any of their
properties, and no such proceedings are known to be contemplated by
governmental authorities.
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ENVIRONMENTAL MATTERS - MANUFACTURED GAS PLANTS
Prior to the general availability of natural gas, in the 1800s through
the mid-1900s, manufactured gas was a chief source of gas for lighting and
heating nationwide. The process involved heating certain combustibles such as
coal, oil and coke in a low-oxygen atmosphere. Methods of production included
coal carbonization, carbureted water gas and catalytic cracking. These methods
were employed at many different sites throughout the country. The residue from
gas manufacturing, including coal tar, was typically stored on site, burned in
the gas plant, or sold for commercial use. Some constituents of coal tars
produced from the manufactured gas process are today considered hazardous
substances under the Superfund Law.
The gas distribution business has been one of Utilities' principal
lines of business since its inception in 1882. One of the ways Utilities
initially expanded its business in its early years was by entering into
agreements with other gas companies to operate their businesses. After 1888,
the principal means by which Utilities expanded its gas business was to acquire
all or a portion of the stock of companies engaged in this business. Utilities
also provided management and administrative services to some of these
companies. Utilities grew rapidly by means of stock acquisitions and became
one of the largest public utility holding companies in the country. Pursuant
to the requirements of the Public Utility Holding Company Act of 1935,
Utilities divested all of its utility operations other than those which now
constitute the Gas Utility and the Electric Utility.
The manufactured gas process was once used by Utilities in connection
with providing gas service to its customers. In addition, virtually all of the
gas companies that Utilities operated or to which it provided services, or in
which Utilities held stock, utilized a manufactured gas process. Utilities has
been notified of several sites outside Pennsylvania on which (i) gas plants
were formerly operated by it or owned or operated by its former subsidiaries
and (ii) either environmental agencies or private parties are investigating the
extent of environmental contamination and the necessity of environmental
remediation. Utilities is currently litigating two claims against it relating
to out-of-state sites. If Utilities were found liable as a "responsible party"
as defined in the Superfund Law (or comparable state statutes) with respect to
any of these sites, it would have joint and several liability with other
responsible parties for the full amount of the cleanup costs. A "responsible
party" under that statute includes (i) the current owner of the affected
property and (ii) each owner or operator of a facility during the time when
hazardous substances were released on the property.
Management believes that Utilities should not have significant
liability in those instances in which a former subsidiary operated a
manufactured gas plant because Utilities generally is not legally liable for
the obligations of its subsidiaries. Under certain circumstances, however,
courts have found parent companies liable for environmental damage caused by
subsidiary companies when the parent company exercised such substantial control
over the subsidiary that the court concluded that the parent company either (i)
itself operated the facility causing the environmental damage or (ii) otherwise
so controlled the subsidiary that the subsidiary's separate corporate form
should be disregarded. There could be, therefore, significant future costs of
an uncertain amount associated with environmental damage caused by manufactured
gas plants that Utilities owned or
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directly operated, or that were owned or operated by former subsidiaries of
Utilities, if a court were to conclude that the level of control exercised by
Utilities over the subsidiary satisfies the standard described above.
Utilities believes that there are approximately 40 manufactured gas
plant sites in Pennsylvania where either (i) Utilities formerly operated the
plant or (ii) Utilities owns or at one time owned the site. Most of the sites
are no longer owned by Utilities and the gas plants formerly operated at these
40 sites have all been out of operation since at least the early 1950s. Two of
the sites, located in Palmyra and Lebanon, Pennsylvania, respectively, are
discussed below. Based on the 1995 settlement agreement with the PUC relating
to Gas Utilities' 1995 base rate increase filing, rate relief will be permitted
for certain remediation expenditures on environmentally contaminated sites
located in Pennsylvania.
The following is a short description of the status of certain matters
involving Utilities related to manufactured gas plants located in Pennsylvania
and in other states. See also Note 12 to the Company's Consolidated Financial
Statements which appears on pages 36 and 37 of its 1996 Annual Report to
Shareholders.
A. PENNSYLVANIA GAS PLANT SITES
1. Palmyra. On May 5, 1993, Petroleum Heat and Power Company
("Petroleum") informed Utilities that Utilities may be responsible for
contamination at property owned by Petroleum in Palmyra, Pennsylvania.
Utilities is the corporate successor to a company that operated a manufactured
gas plant on this site from approximately 1910 to 1928. Petroleum operates a
fuel oil dealership at the site and removed a number of underground gasoline
storage tanks, some of which were found to be leaking. In the course of
remediating the gasoline contamination, Petroleum's consultant discovered
creosote or coal tar contamination in one of the groundwater monitoring wells
to a depth of approximately twenty feet. Utilities and Petroleum have jointly
conducted and shared the cost of additional investigation which suggests that
the coal tar-like contaminants are contained in a small area of the site and
that they have not entered the groundwater. Utilities and Petroleum have
completed investigation of the site, have removed contaminated soils and expect
the DER to approve a recommendation that the parties take no further action.
2. Lebanon. In October 1990, Utilities notified the DER of the
discovery of coal tar at a site formerly operated by a predecessor company of
Utilities as a gas plant in Lebanon, Pennsylvania. This material was
discovered during the excavation of the foundation of a new service building
that Utilities was constructing on the site. Utilities subsequently removed
and disposed of coal tar contaminated soil to the extent practicable.
Utilities has continued to monitor groundwater wells on and adjacent to the
site. Some of these wells have produced petroleum hydrocarbon contaminated
water consistent with leaking underground gasoline tanks. Properties to the
east and south of Utilities' property have histories of such leaking tanks.
The latest communication from the DER concludes that the predominant
contamination at the site is related to the leaking gasoline storage tanks.
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B. OUT OF STATE GAS PLANT SITES
1. Halladay Street, Jersey City, New Jersey. By letter dated April
12, 1993, Public Service Electric and Gas Company ("PSE&G") informed Utilities
that PSE&G had been named as a defendant in a civil action pending in the
United States District Court of the District of New Jersey, seeking damages as
a result of contamination relating to the former manufactured gas plant
operations at Halladay Street in Jersey City, New Jersey. The Halladay Street
gas plant operated from approximately 1884 until 1950. PSE&G asserted that
Utilities is liable for that portion of the costs associated with operations of
the plant between 1886 and 1899. PPG Industries, Inc. has also been named as a
defendant in the action for costs associated with chemical contamination at the
site unrelated to gas plant operations. In July 1993, PSE&G served Utilities
with a complaint naming Utilities as a third-party defendant in this civil
action. PSE&G subsequently amended the complaint to allege additional theories
of liability for the period from 1899 to 1940. That action is continuing.
Management is currently investigating Utilities' involvement in operations of
the site and evaluating its defenses. Investigations of the site conducted to
date are insufficient to establish the extent of environmental remediation
necessary, if any. Hence, Utilities is unable to estimate the total cost of
cleanup associated with manufactured gas plant wastes at this site.
2. Burlington, Vermont. By letter dated November 24, 1992, the EPA
notified Utilities of potential liability with respect to contamination at the
Pine Street Canal Superfund Site, Burlington, Vermont. The EPA has also
identified eighteen other "potentially responsible parties." The site is the
location of a former manufactured gas plant owned and operated by Burlington
Gas Light Company ("BGLC") and Burlington Light and Power Company ("BLPC"). The
EPA contends that Utilities is potentially liable because it assumed the
liabilities of American Gas Company of New Jersey, a one-time parent of BGLC
and BLPC. In 1985, the EPA removed approximately 15,000 tons of coal tar
contaminated material from a portion of the site. From 1986 through 1992, the
EPA conducted investigations and developed potential remedial actions at the
site. The results of EPA's investigations show that coal gasification wastes,
particularly polynuclear aromatic hydrocarbons and coal tar, are present in
surface and subsurface soils as well as groundwater. The contamination also
extends to wetlands adjacent to the site.
In November 1992, the EPA proposed a cleanup of the site that, among
other actions, would consist of on-site containment, dredging and excavation,
dewatering and consolidation of contaminated soils, treatment of groundwater
and restoration of wetlands. The estimated cost of the proposed plan would
have been approximately $50 million. In May 1993, after reviewing extensive
public comment concerning the proposed plan of remediation, the EPA withdrew
the proposed plan and announced that it would work with community groups,
potentially responsible parties and others to develop an alternative plan.
Management is unable to estimate the cost of any alternative plan of
remediation, but it does not expect such cost to exceed the estimated cost of
the original proposed plan. Utilities has responded to the EPA letter and
denied liability for any contamination caused by the former operator of the gas
plant. Management believes that Utilities has substantial defenses to any
claim that may be made for investigative or remedial costs because, among other
things, the plant was operated by a subsidiary of a predecessor company.
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3. Savannah, Georgia. On March 2, 1992, Atlanta Gas Light Company
("AGL") informed Utilities that it was investigating contamination that appears
to be related to manufactured gas plant operations at a site owned by AGL in
Savannah, Georgia. AGL believes that Utilities may be liable for investigative
and remedial costs as a result of having operated the gas plant through a
subsidiary company in the early 1900s. AGL has stated its intention to bring
suit against Utilities. AGL estimates that total costs to remediate the site
may exceed $5 million. Management believes that Utilities has substantial
defenses to any action that may arise out of the activities of its former
subsidiary at this site.
4. Concord, New Hampshire. By letter dated October 18, 1993,
EnergyNorth Natural Gas, Inc. ("EnergyNorth") informed Utilities that the New
Hampshire Department of Environmental Services ("NHDES") has alleged that there
is environmental contamination on property in Concord, N.H., where a
manufactured gas plant was once located. EnergyNorth requested that Utilities,
as a former operator of the plant, participate in investigation of the site.
Because this gas plant appears to have been operated almost exclusively by
former subsidiary companies of Utilities, Utilities declined to participate.
On September 17, 1995 EnergyNorth filed suit against Utilities alone in federal
District Court in New Hampshire, seeking Utilities' allocable share of response
costs associated with remediating gas plant related contamination at that site.
The complaint alleges that EnergyNorth has spent $3.5 million to remove
contaminants from a gas holder at the site and will be required to spend an
unknown amount in the future. As a result of investigations of gas plant
related contamination in a nearby pond completed in 1996, EnergyNorth has
recommended to NHDES a remedial plan that would cost approximately $4 million.
Utilities is currently defending this suit.
OTHER MATTERS
1. Mateel Environmental Justice Foundation v. AmeriGas Propane, L.P.
et al. On July 29, 1996, Mateel Environmental Justice Foundation ("Mateel")
filed a complaint in the Superior Court of the State of California, County of
San Francisco, alleging that the Operating Partnership, and several other major
propane gas distributors, are in violation of Proposition 65, "The Safe
Drinking Water and Toxic Enforcement Act of 1986" (commonly referred to as
"Prop 65"). The Operating Partnership is a 98.99% owned subsidiary of the
Partnership. The Complaint alleges that the Operating Partnership and its
co-defendants are required to provide warnings that the use of liquid propane
would result in exposure to chemicals known to cause cancer and birth defects,
and that the burning of liquid propane in heaters and other appliances causes
exposure to carbon monoxide, benzene, formaldehyde and acetaldehyde. The
maximum penalty under Prop 65 is $2,500 per day, per person exposed. In
addition to the maximum penalty, Mateel is seeking attorney's fees and costs,
together with an Order mandating compliance with Prop 65. Management believes
that the Operating Partnership has substantial defenses to this claim. The
Operating Partnership has entered into settlement negotiations with Mateel and
the California Attorney General's office. The amount of the proposed
settlement is immaterial to the Partnership.
22
<PAGE> 25
2. Commercial Row Cases, Judicial Council of California, Coordination
Proceeding No. 3096. Beginning in June 1994, twenty-one complaints were filed
against AmeriGas Propane, Inc., a Delaware corporation ("AGP"), and a
predecessor of the Operating Partnership, in the Superior Court of California,
arising from an explosion which occurred in Truckee, California on November 30,
1993. The explosion is alleged to have occurred as the result of propane gas
which escaped from a fractured fitting in an underground supply line. The
complaints sought relief for alleged personal injuries and/or property damage,
and named as defendants the manufacturer and distributor of the fitting, in
addition to AGP. The cases have been consolidated by the Judicial Council of
California as the Commercial Row Cases, Judicial Council Coordination
Proceeding No. 3096. All of the complaints requested damages in unspecified
amounts; some of the complaints sought punitive damages as well as compensatory
damages. A number of complaints were settled during 1996. During pretrial
discovery, the remaining claimants have asserted demands which in the aggregate
now exceed $18 million. The claims asserted in the complaints are fully
insured, subject to a $500,000 self-insured retention, except for awards of
punitive damages or that portion of a settlement attributable to punitive
damages, which may not be covered by insurance. Trial currently is scheduled
to begin on February 24, 1997.
23
<PAGE> 26
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matter was submitted to a vote of security holders during the last
fiscal quarter of the 1996 fiscal year.
UGI'S EXECUTIVE OFFICERS
Information regarding UGI's executive officers is included in Part III
of this Report and is incorporated in Part I by reference.
PART II: SECURITIES AND FINANCIAL INFORMATION
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
AND RELATED STOCKHOLDER MATTERS
MARKET INFORMATION
The Company's Common Stock is traded on the New York and Philadelphia
Stock Exchanges. The following table sets forth the high and low sales prices
for the Company's 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:
<TABLE>
<CAPTION>
1996 FISCAL YEAR HIGH LOW
<S> <C> <C>
4th Quarter $24 7/8 $21 7/8
3rd Quarter 24 7/8 20
2nd Quarter 22 3/4 20 1/8
1st Quarter 21 7/8 19 3/4
</TABLE>
<TABLE>
<CAPTION>
1995 FISCAL YEAR HIGH LOW
<S> <C> <C>
4th Quarter $21 3/4 $19 3/4
3rd Quarter 22 1/8 18 7/8
2nd Quarter 22 19
1st Quarter 20 7/8 18 1/4
</TABLE>
24
<PAGE> 27
DIVIDENDS
Quarterly dividends on UGI Common Stock were paid in the 1996 and 1995
fiscal years as follows:
<TABLE>
<CAPTION>
1996 FISCAL YEAR AMOUNT
<S> <C>
4th Quarter $.35 1/2
3rd Quarter .35
2nd Quarter .35
1st Quarter .35
</TABLE>
<TABLE>
<CAPTION>
1995 FISCAL YEAR AMOUNT
<S> <C>
4th Quarter $.35
3rd Quarter .34 1/2
2nd Quarter .34 1/2
1st Quarter .34 1/2
</TABLE>
HOLDERS
On December 1, 1996, UGI had 14,588 holders of record of Common Stock.
The information concerning restrictions on dividends required by Item
5 is incorporated in this Report by reference to Note 5 to the Company's
Consolidated Financial Statements which appears on pages 30 through 32 of its
1996 Annual Report to Shareholders.
25
<PAGE> 28
ITEM 6. SELECTED FINANCIAL DATA
<TABLE>
<CAPTION>
Year
Year Ended Nine Months Ended Ended
September 30, September 30, December 31,
----------------------------------- -------------------------- ------------
1996 1995(a) 1994(a) 1993 1992 1992
--------- --------- --------- --------- --------- ------------
(Unaudited)
(Millions of dollars, except per share amounts)
<S> <C> <C> <C> <C> <C> <C>
FOR THE PERIOD:
Income statement data:
Revenues $ 1,557.6 $ 877.6 $ 762.2 $ 509.5 $ 486.8 $ 708.1
========== ========= ========= ========= ========= =========
Income (loss) from:
Continuing operations $ 39.5 $ 7.9 $ 37.4 $ 12.6 $ 15.3 $ 31.5
Discontinued operations - - 7.6 - 1.7 2.2
---------- --------- --------- --------- --------- ---------
Income before extraordinary loss
and change in accounting 39.5 7.9 45.0 12.6 17.0 33.7
Extraordinary loss - debt restructuring - (13.2) - - - -
Change in accounting for
postemployment benefits - (3.1) - - - -
---------- --------- --------- --------- --------- ---------
Net income (loss) $ 39.5 $ (8.4) $ 45.0 $ 12.6 $ 17.0 $ 33.7
========== ========= ========= ========= ========= =========
Per common share data:
Earnings from continuing
operations $ 1.19 $ .24 $ 1.16 $ .41 $ .57 $ 1.14
Earnings (loss) from
discontinued operations - - .23 - .06 .08
---------- --------- --------- --------- --------- ---------
Earnings before extraordinary loss
and change in accounting 1.19 .24 1.39 .41 .63 1.22
Extraordinary loss - debt restructuring - (.40) - - - -
Change in accounting for
postemployment benefits - (.10) - - - -
---------- --------- --------- --------- --------- ---------
Net earnings (loss) $ 1.19 $ (.26) $ 1.39 $ .41 $ .63 $ 1.22
========== ========= ========= ========= ========= =========
Cash dividends declared $ 1.41 $ 1.39 $ 1.36 $ .995 $ .96 $ 1.285
========== ========= ========= ========= ========= =========
AT PERIOD END:
Balance sheet data:
Total assets $ 2,144.9 $ 2,164.0 $ 1,182.2 $ 1,211.4 $ 1,076.3 $ 1,103.5
========== ========= ========= ========= ========= =========
Capitalization:
Debt:
Bank loans - Propane $ 15.0 $ - $ - $ - $ - $ -
Bank loans - Utilities 50.5 42.0 17.0 - - 36.3
Long-term debt
(including current maturities):
Propane 692.5 658.5 210.3 210.2 211.0 210.8
Utilities 174.8 206.3 175.6 200.4 196.2 153.7
Other 9.0 9.3 9.6 9.9 - -
---------- --------- --------- --------- --------- ---------
Total debt 941.8 916.1 412.5 420.5 407.2 400.8
---------- --------- --------- --------- --------- ---------
Minority interest in AmeriGas Partners 284.4 318.9 - - - -
UGI Utilities preferred stock subject
to mandatory redemption 35.2 35.2 35.2 33.2 35.2 34.2
Common stockholders' equity 377.6 380.5 424.3 414.5 375.5 389.9
---------- --------- --------- --------- --------- ---------
Total capitalization $ 1,639.0 $ 1,650.7 $ 872.0 $ 868.2 $ 817.9 $ 824.9
========== ========= ========= ========= ========= =========
Ratio of capitalization:
Total debt 57.5% 55.5% 47.3% 48.4% 49.8% 48.6%
Minority interest 17.4 19.3 - - - -
UGI Utilities preferred stock 2.1 2.1 4.0 3.8 4.3 4.1
Common stockholders' equity 23.0 23.1 48.7 47.8 45.9 47.3
---------- --------- --------- --------- --------- ---------
100.0% 100.0% 100.0% 100.0% 100.0% 100.0%
========== ========= ========= ========= ========= =========
</TABLE>
(a)On April 19, 1995, a wholly owned subsidiary of AmeriGas acquired by merger
the approximately 65% of Petrolane common shares not already owned by UGI or
AmeriGas and combined the propane distribution businesses of Petrolane and
the Company. The consolidated results of the Company include those of
Petrolane for periods subsequent to April 19, 1995. Prior to April 19, 1995,
the Company's investment in Petrolane (commencing with its July 15, 1993
acquisition of a significant equity investment in Petrolane) was accounted
for by the equity method. On a pro forma basis as if the acquisition of the
65% of Petrolane had occurred at the beginning of fiscal 1994, revenues would
have been $1,244.5 and $1,344.2, and income from continuing operations would
have been $20.5 and $38.8 during the years ended September 30, 1995 and 1994,
respectively.
26
<PAGE> 29
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, entitled "Financial Review" and contained on pages 10
through 18 of UGI's 1996 Annual Report to Shareholders, is incorporated in this
Report by reference.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The Financial Statements and Financial Statement Schedules referred to
in the Index contained on pages F-2 and F-3 of this Report are incorporated
herein by reference.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
ACCOUNTING AND FINANCIAL DISCLOSURE
None.
PART III: UGI MANAGEMENT AND SECURITY HOLDERS
ITEMS 10 THROUGH 12.
In accordance with General Instruction G(3), and except as set forth
below, the information required by Items 10, 11 and 12 is incorporated in this
Report by reference to the following portions of UGI's Proxy Statement, which
will be filed with the Securities and Exchange Commission by January 27, 1997:
<TABLE>
<CAPTION>
CAPTIONS OF PROXY STATEMENT
INFORMATION INCORPORATED BY REFERENCE
----------- ----------------------------
<S> <C>
Item 10. Directors and Executive Election of Directors - Nominees
Officers of Registrant.
Item 11. Executive Compensation. Compensation of Executive Officers
Compensation of Directors
Item 12. Security Ownership of Securities Ownership of Management
Certain Beneficial
Owners and Management.
Security Ownership of Certain
Beneficial Owners
</TABLE>
27
<PAGE> 30
The information concerning the Company's executive officers required
by Item 10 is set forth below.
EXECUTIVE OFFICERS
<TABLE>
<CAPTION>
NAME AGE POSITION
---- --- --------
<S> <C> <C>
Lon R. Greenberg 46 Chairman, Director, President
and Chief Executive Officer
Charles L. Ladner 58 Senior Vice President - Finance
and Chief Financial Officer
Brendan P. Bovaird 48 Vice President and General Counsel
Michael J. Cuzzolina 51 Vice President - Accounting
and Financial Control
Bradley C. Hall 43 Vice President - New Business Development
Richard L. Bunn 60 President and Chief Executive
Officer, UGI Utilities, Inc.
</TABLE>
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.
The following is a summary of the business experience of the executive
officers listed above during at least the last five years. For purposes of the
summary of business experience set forth below, references to "the Company,"
"UGI" and "the Board" prior to February 19, 1992 refer to Utilities (formerly,
UGI Corporation) or the Board of Directors of Utilities, respectively.
Lon R. Greenberg
Mr. Greenberg was elected Chairman of UGI effective August 1, 1996,
having been elected Chief Executive Officer effective August 1, 1995. He was
elected Director and President of UGI and a Director of UGI Utilities in July
1994. Mr. Greenberg was Senior Vice President - Legal and Corporate
Development (1989 to 1994), and also served as Vice President - Legal and
Corporate Development (1987 to 1989). Previously, he was Vice President -
Legal (1984 to 1987), General Counsel (1983 to 1994) and Secretary (1982 to
1988). He joined the Company in 1980 as Corporate Development Counsel. Mr.
Greenberg is also a director on the Mellon PSFS Advisory Board.
28
<PAGE> 31
Charles L. Ladner
Mr. Ladner is Senior Vice President-Finance (since 1978). He joined
the Company in August 1973 as Vice President-Finance.
Brendan P. Bovaird
Mr. Bovaird is Vice President and General Counsel of UGI (since April
1995). He is also Vice President and General Counsel of UGI Utilities, Inc.,
and AmeriGas, Inc. (since April 1995). Mr. Bovaird previously served as
Division Counsel and Member of the Executive and Operations Committees of
Wyeth-Ayerst International Inc. (1992 to 1995) and Senior Vice President,
General Counsel and Secretary of Orion Pictures Corporation (1990 to 1991).
Mr. Bovaird also engaged in private practice from 1991 to 1992.
Michael J. Cuzzolina
Mr. Cuzzolina is Vice President-Accounting and Financial Control of
the Company (since 1984) and Treasurer of AmeriGas Propane, Inc. (since 1995).
He joined the Company in 1974 and has previously served as Treasurer and
Assistant Controller of the Company and as Vice President-Finance of AmeriGas.
Bradley C. Hall
Mr. Hall was elected Vice President-New Business Development on
October 25, 1994, having been Vice President-Marketing and Rates, UGI
Utilities, Inc. Gas Division. He joined the Company in 1982 and has held
various positions in the Gas Division.
Richard L. Bunn
Mr. Bunn is President and Chief Executive Officer of UGI Utilities,
Inc., (since May 1992). He previously served as Senior Vice
President-Utilities Division of UGI (1987 to May 1992) and Senior Vice
President-Energy of UGI (1978 to 1987). Mr. Bunn began his career with UGI as
an engineer in the Electric Utility Division (1958).
29
<PAGE> 32
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
None.
PART IV: ADDITIONAL EXHIBITS, SCHEDULES AND REPORTS
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES,
AND REPORTS ON FORM 8-K
(a) DOCUMENTS FILED AS PART OF THIS REPORT:
(1), (2) The financial statements and financial statement
schedules incorporated by reference or included in this Report
are listed in the accompanying Index to Financial Statements
and Financial Statement Schedules set forth on pages F-2
through F-3 of this Report, which is incorporated herein by
reference.
(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):
30
<PAGE> 33
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------------------------------------------
INCORPORATION BY REFERENCE
- -----------------------------------------------------------------------------------------------------------------
EXHIBIT NO. EXHIBIT REGISTRANT FILING EXHIBIT
- -----------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
3.1 (Second) Amended and Restated Articles of UGI Amendment No. 1 on 3.(3)(a)
Incorporation of the Company Form 8 to Form 8-B
(4/10/92)
3.2 Bylaws of UGI as in effect since October UGI Form 10-K 3.2
31, 1995. (9/30/95)
- -----------------------------------------------------------------------------------------------------------------
4 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 its long-term debt not required to be
filed pursuant to the description of
Exhibit 4 contained in Item 601 of
Regulation S-K)
4.1 Rights Agreement, as amended as of April UGI Form 8-K 4.1
17, 1996, between the Company and Mellon (4/17/96)
Bank, N.A., successor to Mellon Bank
(East) N.A., as Rights Agent, and
Assumption Agreement dated April 7, 1992
4.2 The description of the Company's Common UGI Form 8-B/A 3.(4)
Stock contained in the Company's (4/17/96)
registration statement filed under the
Securities Exchange Act of 1934, as
amended
4.3 UGI's (Second) Amended and Restated
Articles of Incorporation and Bylaws
referred to in 3.1 and 3.2 above.
4.4 Utilities' Articles of Incorporation Utilities Form 8-K 4(a)
(9/22/94)
- -----------------------------------------------------------------------------------------------------------------
</TABLE>
31
<PAGE> 34
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------------
INCORPORATION BY REFERENCE
- ------------------------------------------------------------------------------------------------------------------
EXHIBIT NO. EXHIBIT REGISTRANT FILING EXHIBIT
- ------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
4.5 First Mortgage Notes Agreement dated as AmeriGas Form 10-Q 10.8
of April 12, 1995 among The Prudential Partners, L.P. (3/31/95)
Insurance Company of America,
Metropolitan Life Insurance Company, and
certain other institutional investors and
AmeriGas Propane, L.P., New AmeriGas
Propane, Inc. and Petrolane Incorporated
- ------------------------------------------------------------------------------------------------------------------
10.1 Service Agreement (Rate FSS) dated as of UGI Form 10-K 10.5
November 1, 1989 between Utilities and (9/30/95)
Columbia, as modified pursuant to the
orders of the Federal Energy Regulatory
Commission at Docket No. RS92-5-000
reported at Columbia Gas Transmission
Corp., 64 FERC paragraph 61,060 (1993),
order on rehearing, 64 FERC paragraph
61,365 (1993)
10.2 Service Agreement (Rate FTS) dated June Utilities Form 10-K (10)o.
1, 1987 between Utilities and Columbia, (12/31/90)
as modified by Supplement No. 1 dated
October 1, 1988; Supplement No. 2 dated
November 1, 1989; Supplement No. 3 dated
November 1, 1990; Supplement No. 4 dated
November 1, 1990; and Supplement No. 5
dated January 1, 1991, as further
modified pursuant to the orders of the
Federal Energy Regulatory Commission at
Docket No. RS92-5-000 reported at
Columbia Gas Transmission Corp., 64 FERC
paragraph 61,060 (1993), order on
rehearing, 64 FERC paragraph 61,365
(1993)
- ------------------------------------------------------------------------------------------------------------------
</TABLE>
32
<PAGE> 35
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------------
INCORPORATION BY REFERENCE
- ------------------------------------------------------------------------------------------------------------------
EXHIBIT NO. EXHIBIT REGISTRANT FILING EXHIBIT
- ------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
10.3 Transportation Service Agreement (Rate Utilities Form 10-K (10)p.
FTS-1) dated November 1, 1989 between (12/31/90)
Utilities and Columbia Gulf Transmission
Company, as modified pursuant to the
orders of the Federal Energy Regulatory
Commission in Docket No. RP93-6-000
reported at Columbia Gulf Transmission
Co., 64 FERC paragraph 61,060 (1993),
order on rehearing, 64 FERC paragraph
61,365 (1993)
10.4 Amended and Restated Sublease Agreement UGI Form 10-K 10.35
dated April 1, 1988 between Southwest (9/30/94)
Salt Co. and AP Propane, Inc. (the
"Southwest Salt Co. Agreement")
10.5 Letter dated September 26, 1994 pursuant UGI Form 10-K 10.36
to Article 1, Section 1.2 of the (9/30/94)
Southwest Salt Co. Agreement re option to
renew for period of June 1, 1995 to May
31, 2000
10.6** UGI Corporation 1992 Directors' Stock UGI Form 10-Q (10)ff
Plan (6/30/92)
10.7** UGI Corporation Directors Deferred UGI Form 10-K 10.39
Compensation Plan dated August 26, 1993 (9/30/94)
- ------------------------------------------------------------------------------------------------------------------
</TABLE>
33
<PAGE> 36
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------------------------------------------
INCORPORATION BY REFERENCE
- -----------------------------------------------------------------------------------------------------------------
EXHIBIT NO. EXHIBIT REGISTRANT FILING EXHIBIT
- -----------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
10.8** UGI Corporation Retirement Plan for UGI Form 10-K 10.40
Outside Directors dated October 1, 1993 (9/30/94)
10.9** UGI Corporation 1992 Stock Option and UGI Form 10-Q (10)ee
Dividend Equivalent Plan, as amended May (6/30/92)
19, 1992
10.10** UGI Corporation Annual Bonus Plan dated UGI Form 10-Q 10.4
March 8, 1996 (6/30/96)
10.11** Amended and Restated Senior Executive UGI Form 10-K 10.43
Retirement Plan for Certain Employees of (9/30/94)
UGI Corporation and its Subsidiaries and
Affiliates, effective October 27, 1992
10.12** UGI Corporation Senior Executive UGI Form 10/K 10.44
Severance Pay Plan dated April 30, 1993 (9/30/94)
10.13** Change of Control Agreement between UGI UGI Form 10-Q 10.1
Corporation and Lon R. Greenberg (6/30/96)
10.14** Form of Change of Control between UGI UGI Form 10-Q 10.2
Corporation and each of Messrs. Bunn and (6/30/96)
Ladner
10.15** Form of Change of Control Agreement UGI Form 10-Q 10.3
between UGI Corporation and each of (6/30/96)
Messrs. Bovaird, Cuzzolina and Hall
10.16** Agreement with Robert C. Mauch dated July AmeriGas Form 10-K 10.22
25, 1996 Partners (9/30/96)
- -----------------------------------------------------------------------------------------------------------------
</TABLE>
34
<PAGE> 37
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------------------------------------------
INCORPORATION BY REFERENCE
- -----------------------------------------------------------------------------------------------------------------
EXHIBIT NO. EXHIBIT REGISTRANT FILING EXHIBIT
- -----------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
10.17 Credit Agreement dated as of April 12, AmeriGas Registration 10.1
1995 among AmeriGas Propane, L.P., Partners, L.P. Statement on Form
AmeriGas Propane, Inc., Petrolane S-4 (No. 33-92734)
Incorporated, Bank of America National
Trust and Savings Association, as Agent
and certain banks
10.18 First Amendment dated as of July 31, 1995 AmeriGas Form 10-K 10.2
to Credit Agreement Partners, L.P. (9/30/96)
10.19 Second Amendment dated as of October 28, AmeriGas Form 10-K 10.3
1996 to Credit Agreement Partners, L.P. (9/30/96)
10.20 Intercreditor and Agency Agreement dated AmeriGas Form 10-Q 10.2
as of April 19, 1995 among AmeriGas Partners, L.P. (3/31/95)
Propane, Inc., Petrolane Incorporated,
AmeriGas Propane, L.P., Bank of America
National Trust and Savings Association
("Bank of America") as Agent, Mellon
Bank, N.A. as Cash Collateral Sub-Agent,
Bank of America as Collateral Agent and
certain creditors of AmeriGas Propane,
L.P.
10.21 General Security Agreement dated as of AmeriGas Form 10-Q 10.3
April 19, 1995 among AmeriGas Propane, Partners, L.P. (3/31/95)
L.P., Bank of America National Trust and
Savings Association and Mellon Bank, N.A.
10.22 Subsidiary Security Agreement dated as of AmeriGas Form 10-Q 10.4
April 19, 1995 among AmeriGas Propane, Partners, L.P. (3/31/95)
L.P., Bank of America National Trust and
Savings Association as Collateral Agent
and Mellon Bank, N.A. as Cash Collateral
Agent
- -----------------------------------------------------------------------------------------------------------------
</TABLE>
35
<PAGE> 38
<TABLE>
<CAPTION>
- ----------------------------------------------------------------------------------------------------------------
INCORPORATION BY REFERENCE
- ----------------------------------------------------------------------------------------------------------------
EXHIBIT NO. EXHIBIT REGISTRANT FILING EXHIBIT
- ----------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
10.23 Restricted Subsidiary Guarantee dated as AmeriGas Form 10-Q 10.5
of April 19, 1995 by AmeriGas Propane Partners, L.P. (3/31/95)
L.P. for the benefit of Bank of America
National Trust and Savings Association,
as Collateral Agent
10.24 Trademark License Agreement dated April AmeriGas Form 10-Q 10.6
19, 1995 among UGI Corporation, AmeriGas, Partners, L.P. (3/31/95)
Inc., AmeriGas Propane, Inc., AmeriGas
Partners, L.P. and AmeriGas Propane, L.P.
10.25 Trademark License Agreement, dated April AmeriGas Form 10-Q 10.7
19, 1995 among AmeriGas Propane, Inc., Partners, L.P. (3/31/95)
AmeriGas Partners, L.P. and AmeriGas
Propane, L.P.
10.26 Credit Agreement dated October 28, 1996 AmeriGas Form 10-K 10.19
between AmeriGas Propane, Inc. and Partners, L.P. (9/30/96)
AmeriGas Partners, L.P.
- ----------------------------------------------------------------------------------------------------------------
*11 Statement re: Computation of Per Share
Earnings
- ----------------------------------------------------------------------------------------------------------------
*13 Pages 10 through 39 of 1996 Annual Report
to Shareholders
- ----------------------------------------------------------------------------------------------------------------
*21 Subsidiaries of the Registrant
- ----------------------------------------------------------------------------------------------------------------
*23 Consent of Coopers & Lybrand L.L.P.
- ----------------------------------------------------------------------------------------------------------------
*27 Financial Data Schedule
- ----------------------------------------------------------------------------------------------------------------
*99 Cautionary Statements affecting
Forward-looking Information
- ----------------------------------------------------------------------------------------------------------------
</TABLE>
* Filed herewith.
** As required by Item 14(a)(3), this exhibit is identified as a
compensatory plan or arrangement.
(b) Reports on Form 8-K:
During the last quarter of the 1996 fiscal year, the Company
filed no Current Reports on Form 8-K.
36
<PAGE> 39
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 10, 1996 By: Charles L. Ladner
-------------------------------
Charles L. Ladner
Senior Vice President - Finance
and Chief Financial Officer
Pursuant to the requirements of the Securities Exchange Act of 1934,
this Report has been signed below on December 10, 1996, by the following
persons on behalf of the Registrant in the capacities indicated.
<TABLE>
<CAPTION>
SIGNATURE TITLE
--------- -----
<S> <C>
Lon R. Greenberg Chairman, President
- --------------------------- and Chief Executive Officer
Lon R. Greenberg (Principal Executive Officer)
and Director
Charles L. Ladner Senior Vice President -
- ----------------------------- Finance and Chief Financial
Charles L. Ladner Officer (Principal
Financial Officer)
Michael J. Cuzzolina Vice President -
- ---------------------------- Accounting and
Michael J. Cuzzolina Financial Control
(Principal Accounting
Officer)
Stephen D. Ban Director
- ------------------------------
Stephen D. Ban
Robert C. Forney Director
- -----------------------------
Robert C. Forney
</TABLE>
37
<PAGE> 40
<TABLE>
<CAPTION>
SIGNATURE TITLE
- --------- -----
<S> <C>
Richard C. Gozon Director
- ----------------------------
Richard C. Gozon
Cyrus H. Holley Director
- ------------------------------
Cyrus H. Holley
Anne Pol Director
- -----------------------------
Anne Pol
Quentin I. Smith, Jr. Director
- -----------------------------
Quentin I. Smith, Jr.
James W. Stratton Director
- ----------------------------
James W. Stratton
David I. J. Wang Director
- ------------------------------
David I. J. Wang
</TABLE>
38
<PAGE> 41
UGI CORPORATION AND SUBSIDIARIES
FINANCIAL INFORMATION
FOR INCLUSION IN ANNUAL REPORT ON FORM 10-K
YEAR ENDED SEPTEMBER 30, 1996
F-1
<PAGE> 42
UGI CORPORATION AND SUBSIDIARIES
INDEX TO FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES
The consolidated financial statements and supplementary data of UGI Corporation
and subsidiaries, together with the report thereon of Coopers & Lybrand L.L.P.
dated November 22, 1996, listed in the following index, are included in UGI's
1996 Annual Report to Shareholders and are incorporated in this Form 10-K
Annual Report by reference. With the exception of the pages listed in this
index and information incorporated in Items 1, 2, 5, 7 and 8, the 1996 Annual
Report to Shareholders is not to be deemed filed as part of this Report.
<TABLE>
<CAPTION>
Reference
-------------------------------------
Annual
Report to
Form 10-K Shareholders
(page) (page)
--------- --------------
<S> <C> <C>
UGI Corporation:
----------------
Report of Independent Accountants:
On Consolidated Financial Statements 39
On Financial Statement Schedules F-4
Financial Statements:
Consolidated Balance Sheets, September 30,
1996 and 1995 22 - 23
For the years ended September 30, 1996,
1995 and 1994:
Consolidated Statements of Income 21
Consolidated Statements of Cash Flows 24
Consolidated Statements of Stockholders'
Equity 25
Notes to Consolidated Financial
Statements 26 - 38
</TABLE>
F-2
<PAGE> 43
UGI CORPORATION AND SUBSIDIARIES
INDEX TO FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES (CONTINUED)
<TABLE>
<CAPTION>
Reference
-------------------------------------
Annual
Report to
Form 10-K Shareholders
(page) (page)
--------- --------------
<S> <C> <C>
UGI Corporation (continued)
---------------------------
Supplementary Data (unaudited):
Quarterly Data for the years ended
September 30, 1996 and 1995 38
Financial Statement Schedules:
For the years ended September 30, 1996,
1995 and 1994:
I - Condensed Financial
Information of Registrant
(Parent Company) S-1 to S-3
II - Valuation and Qualifying
Accounts S-4 to S-5
</TABLE>
Annual Reports on Form 10-K/A
Annual Reports on Form 10-K/A for the UGI Utilities, Inc. and AmeriGas
Propane, Inc. savings plans will be filed by amendment within the time
period specified by Rule 15d-21(b).
All other financial statement schedules are omitted because the required
information is not present or not present in amounts sufficient to require
submission of the schedule or because the information required is included
elsewhere in the respective financial statements or notes thereto contained or
incorporated by reference herein.
F-3
<PAGE> 44
REPORT OF INDEPENDENT ACCOUNTANTS
To The Board of Directors
and Stockholders
UGI Corporation
Valley Forge, Pennsylvania
Our report on the consolidated financial statements of UGI Corporation and
subsidiaries, which includes an explanatory paragraph regarding the Company's
change in its method of accounting for postemployment benefits in 1995, has
been incorporated by reference in this Form 10-K from page 39 of the 1996
Annual Report to Shareholders of UGI Corporation and subsidiaries. In
connection with our audits of such financial statements, we have also audited
the financial statement schedules listed in the index on pages F-2 and F-3
inclusive, of this Form 10-K.
In our opinion, the financial statement schedules (pages S-1 to S-5, inclusive)
referred to above, when considered in relation to the basic financial
statements taken as a whole, present fairly, in all material respects, the
information required to be included therein.
COOPERS & LYBRAND L.L.P.
2400 Eleven Penn Center
Philadelphia, Pennsylvania
November 22, 1996
F-4
<PAGE> 45
UGI CORPORATION AND SUBSIDIARIES
SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)
BALANCE SHEETS
(Millions of dollars)
<TABLE>
<CAPTION>
September 30,
ASSETS 1996 1995
- ------ --------- ---------
<S> <C> <C>
Current assets:
Cash and cash equivalents $ 51.4 $ 19.1
Short-term investments 23.1 2.0
Accounts receivable 0.4 0.4
Deferred income taxes 0.2 0.2
Prepaid expenses and other current assets 0.2 0.3
--------- ---------
Total current assets 75.3 22.0
Investments in subsidiaries 326.5 383.2
Other assets 1.0 2.3
--------- ---------
Total assets $ 402.8 $ 407.5
========= =========
LIABILITIES AND COMMON STOCKHOLDERS' EQUITY
- -------------------------------------------
Current liabilities:
Accounts and notes payable $ 12.2 $ 10.6
Accrued liabilities 11.7 12.6
--------- ---------
Total current liabilities 23.9 23.2
Noncurrent liabilities 1.3 3.8
Common stockholders' equity:
Common Stock, without par value (authorized - 100,000,000 shares;
issued - 33,198,731 and 32,921,830 shares, respectively) 392.0 386.1
Accumulated deficit (12.9) (5.5)
--------- ---------
379.1 380.6
Less treasury stock, at cost 1.5 0.1
--------- ---------
Total common stockholders' equity 377.6 380.5
--------- ---------
Total liabilities and common stockholders' equity $ 402.8 $ 407.5
========= =========
</TABLE>
S-1
<PAGE> 46
UGI CORPORATION AND SUBSIDIARIES
SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)
STATEMENTS OF INCOME
(Millions of dollars, except per share amounts)
<TABLE>
<CAPTION>
Year Ended
September 30,
----------------------------------------------
1996 1995 1994
---------- ----------- ----------
<S> <C> <C> <C>
Revenues $ - $ - $ -
Costs and expenses:
Operating and administrative expenses 10.1 16.4 15.9
Petrolane management fee income - (6.8) (11.7)
Miscellaneous income, net (13.4) (16.7) (14.7)
---------- ----------- ----------
(3.3) (7.1) (10.5)
---------- ----------- ----------
Operating income 3.3 7.1 10.5
Interest income 0.1 0.2 -
---------- ----------- ----------
Income before income taxes 3.4 7.3 10.5
Income taxes 1.4 3.2 4.4
---------- ----------- ----------
Income before equity in income
of unconsolidated subsidiaries
and equity investees 2.0 4.1 6.1
Equity in continuing operations
of unconsolidated subsidiaries 37.5 3.7 31.6
Equity in Petrolane - 0.1 (0.3)
---------- ----------- ----------
Income from continuing operations 39.5 7.9 37.4
Equity in discontinued operations
of unconsolidated subsidiaries - - 7.6
---------- ----------- ----------
Income before extraordinary loss and change
in accounting for postemployment benefits 39.5 7.9 45.0
Extraordinary loss - debt restructuring - subsidiaries - (13.2) -
Change in accounting for postemployment benefits - subsidiaries - (3.1) -
---------- ----------- ----------
Net income (loss) $ 39.5 $ (8.4) $ 45.0
========== =========== ==========
Earnings per common share:
Continuing operations $ 1.19 $ .24 $ 1.16
Discontinued operations - - .23
---------- ----------- ----------
Earnings before extraordinary loss and change
in accounting for postemployment benefits 1.19 .24 1.39
Extraordinary loss - debt restructuring - subsidiaries - (.40) -
Change in accounting for postemployment benefits - subsidiaries - (.10) -
---------- ----------- ----------
Net earnings (loss) $ 1.19 $ (.26) $ 1.39
========== =========== ==========
</TABLE>
S-2
<PAGE> 47
UGI CORPORATION AND SUBSIDIARIES
SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT (PARENT COMPANY)
STATEMENTS OF CASH FLOWS
(Millions of dollars)
<TABLE>
<CAPTION>
Year Ended
September 30,
------------------------------------------------------
1996 1995 1994
----------- ------------ -----------
<S> <C> <C> <C>
NET CASH PROVIDED BY OPERATING
ACTIVITIES (a) $ 96.6 $ 25.0 $ 46.4
CASH FLOWS FROM INVESTING ACTIVITIES:
Expenditures for property, plant and equipment - (0.2) -
Net repayments from
unconsolidated subsidiaries - 0.5 2.5
Investments in unconsolidated subsidiaries (1.1) (0.6) (36.0)
Other (21.1) (2.0) (6.1)
----------- ------------ -----------
Net cash provided (used) by investing activities (22.2) (2.3) (39.6)
CASH FLOWS FROM FINANCING ACTIVITIES:
Payment of dividends on Common Stock (46.4) (45.2) (42.8)
Issuance of Common Stock 11.3 10.1 9.5
Purchase of Common Stock (7.1) - -
----------- ------------ -----------
Net cash used by financing activities (42.2) (35.1) (33.3)
----------- ------------ -----------
Cash and cash equivalents increase (decrease) $ 32.2 $ (12.4) $ (26.5)
=========== ============ ===========
Cash and cash equivalents:
End of period $ 51.3 $ 19.1 $ 31.5
Beginning of period 19.1 31.5 58.0
----------- ------------ -----------
Increase (decrease) $ 32.2 $ (12.4) $ (26.5)
=========== ============ ===========
</TABLE>
(a)Includes dividends received from unconsolidated subsidiaries of $95.2, $22.1
and $37.3, respectively, for the years ended September 30, 1996, 1995 and
1994.
Supplemental disclosure of non-cash investing activities:
During the year ended September 30, 1995, UGI Corporation contributed a
$10 noninterest bearing demand note to its wholly owned subsidiary, AmeriGas,
Inc. During the year ended September 30, 1996, the note was contributed to
AmeriGas Propane, Inc., a subsidiary of AmeriGas, Inc.
S-3
<PAGE> 48
UGI CORPORATION AND SUBSIDIARIES
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
(Millions of dollars)
<TABLE>
<CAPTION>
Charged
Balance at (credited) Balance at
beginning to costs and end of
of year expenses Other year
---------- ------------ --------- ----------
<S> <C> <C> <C> <C>
YEAR ENDED SEPTEMBER 30, 1996
- -----------------------------
Reserves deducted from assets in
the consolidated balance sheet:
Allowance for doubtful accounts $ 7.3 $ 10.5 $ (7.2)(1) $ 10.6
========== =========
Allowance for amortization of deferred
financing costs - Propane $ 0.7 $ 1.5 $ - $ 2.2
========== =========
Allowance for amortization of
other deferred costs - Propane $ 1.8 $ 1.0 $ - $ 2.8
========== =========
Other reserves:
Self-insured property and casualty liability $ 48.5 $ 14.0 $ (14.8)(2) $ 47.7
========== =========
Insured property and casualty liability $ 11.7 $ 6.8 $ 0.5 (4) $ 19.0
========== =========
Environmental $ 18.4 $ (5.9) $ (0.6)(2) $ 11.9
========== =========
Other $ 7.7 $ (1.2) $ (2.3)(2) $ 4.2
========== =========
YEAR ENDED SEPTEMBER 30, 1995
- -----------------------------
Reserves deducted from assets in
the consolidated balance sheet:
Allowance for doubtful accounts $ 4.7 $ 5.4 $ (7.3)(1) $ 7.3
========== 4.5 (3) =========
Allowance for amortization of deferred
financing costs - Propane $ - $ 0.7 $ - $ 0.7
========== =========
Allowance for amortization of
other deferred costs - Propane $ 6.3 $ 1.6 $ 0.4 (3) $ 1.8
========== (6.5)(4) =========
Other reserves:
Self-insured property and casualty liability $ 13.6 $ 11.3 $ (9.6)(2) $ 48.5
========== 33.0 (3) =========
0.2 (4)
Insured property and casualty liability $ - $ 14.9 $ (2.1)(2) $ 11.7
========== (1.1)(4) =========
Environmental $ 0.5 $ - $ 21.4 (3) $ 18.4
========== (3.4)(4) =========
(0.1)(2)
Other $ - $ 0.2 $ 10.9 (3) $ 7.7
========== (0.5)(2) =========
(2.9)(4)
</TABLE>
S-4
<PAGE> 49
UGI CORPORATION AND SUBSIDIARIES
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS (continued)
(Millions of dollars)
<TABLE>
<CAPTION>
Charged
Balance at (credited) Balance at
beginning to costs and end of
of year expenses Other year
---------- ------------ --------- ----------
<S> <C> <C> <C> <C>
YEAR ENDED SEPTEMBER 30, 1994
- -----------------------------
Reserves deducted from assets in
the consolidated balance sheet:
Allowance for doubtful accounts $ 3.7 $ 5.9 $ (4.9)(1) $ 4.7
========== =========
Allowance for amortization of
other deferred costs - Propane $ 5.9 $ 2.0 $ (1.6)(4) $ 6.3
========== =========
Other reserves:
Self-insured property and casualty liability $ 9.1 $ 9.7 $ (5.2)(2) $ 13.6
========== =========
Environmental $ 0.5 $ - $ - $ 0.5
========== =========
</TABLE>
(1)Uncollectible accounts written off, net of recoveries.
(2)Payments.
(3)Represents amounts for Petrolane Incorporated (Petrolane) as a result of the
purchase on April 19, 1995 of the 65% of the common stock of Petrolane not
already owned by UGI or its subsidiary AmeriGas, Inc.
(4)Other adjustments.
S-5
<PAGE> 50
EXHIBIT INDEX
<TABLE>
<CAPTION>
EXHIBIT NO. DESCRIPTION
- ----------- -----------
<S> <C>
11 Statement re: Computation of Per Share Earnings
13 Pages 10 to 39 of 1996 Annual Report to Shareholders
21 Subsidiaries of the Registrant
23 Consent of Coopers & Lybrand L.L.P.
27 Financial Data Schedule
99 Cautionary Statements affecting Forward-looking
Information
</TABLE>
<PAGE> 1
UGI CORPORATION AND SUBSIDIARIES Exhibit (11)
COMPUTATION OF EARNINGS PER SHARE (Page 1 of 2)
(Millions, except per share amounts)
<TABLE>
<CAPTION>
Year Ended
September 30,
--------------------------------------------
1996 1995 1994
--------- --------- ---------
<S> <C> <C> <C>
Primary earnings per share:
- ---------------------------
Actual average common shares outstanding 33.0 32.7 32.2
Incremental shares issuable upon exercise
of stock options outstanding 0.1 - 0.1
--------- --------- ---------
Total average common and common
equivalent shares outstanding 33.1 32.7 32.3
========= ========= =========
Earnings applicable to common and
common equivalent shares:
Continuing operations $ 39.5 $ 7.9 $ 37.4
Discontinued operations - - 7.6
--------- --------- ---------
Earnings before extraordinary
loss and accounting change 39.5 7.9 45.0
Extraordinary loss - debt restructuring - (13.2) -
Change in accounting for
postemployment benefits - (3.1) -
--------- --------- ---------
Net earnings (loss) $ 39.5 $ (8.4) $ 45.0
========= ========= =========
Primary earnings per common and
common equivalent share:
Continuing operations $ 1.19 $ .24 $ 1.16
Discontinued operations - - .23
--------- --------- ---------
Earnings before extraordinary
loss and accounting change 1.19 .24 1.39
Extraordinary loss - debt restructuring - (.40) -
Change in accounting for
postemployment benefits - (.10) -
--------- --------- ---------
Net earnings (loss) $ 1.19 $ (.26) $ 1.39
========= ========= =========
</TABLE>
<PAGE> 2
UGI CORPORATION AND SUBSIDIARIES Exhibit (11)
COMPUTATION OF EARNINGS PER SHARE (Page 2 of 2)
(Millions, except per share amounts)
<TABLE>
<CAPTION>
Year Ended
September 30,
--------------------------------------------
1996 1995 1994
--------- --------- ---------
<S> <C> <C> <C>
Fully diluted earnings per share:
- ---------------------------------
Actual average common shares outstanding 33.1 32.7 32.2
Incremental shares issuable upon exercise
of stock options outstanding 0.1 - 0.1
--------- --------- ---------
Total shares for fully diluted computation 33.2 32.7 32.3
========= ========= =========
Earnings applicable to common and
common equivalent shares:
Continuing operations $ 39.5 $ 7.9 $ 37.4
Discontinued operations - - 7.6
--------- --------- ---------
Earnings before extraordinary
loss and accounting change 39.5 7.9 45.0
Extraordinary loss - debt restructuring - (13.2) -
Change in accounting for
postemployment benefits - (3.1) -
--------- --------- ---------
Net earnings (loss) $ 39.5 $ (8.4) $ 45.0
========= ========= =========
Fully diluted earnings per common share:
Continuing operations $ 1.19 $ .24 $ 1.16
Discontinued operations - - .23
--------- --------- ---------
Earnings before extraordinary
loss and accounting change 1.19 .24 1.39
Extraordinary loss - debt restructuring - (.40) -
Change in accounting for
postemployment benefits - (.10) -
--------- --------- ---------
Net earnings (loss) $ 1.19 $ (.26) $ 1.39
========= ========= =========
</TABLE>
<PAGE> 1
FINANCIAL REVIEW
BUSINESS OVERVIEW
PROPANE
The Company's propane business is conducted primarily through AmeriGas
Partners, L.P. and its operating subsidiary, AmeriGas Propane, L.P.
(collectively referred to herein as "the Partnership"). The Operating
Partnership, in which the Company holds a 58.7% equity interest, is the largest
retail propane marketer in the U.S. It serves residential, commercial,
industrial, motor fuel and agricultural customers from locations in 44 states,
including Alaska and Hawaii.
The Operating Partnership competes in the retail propane distribution
business with other large national and regional propane marketers and thousands
of small independent operators. It also competes against providers of other
sources of energy such as natural gas, fuel oil and electricity.
UTILITIES
The Company's utility business is conducted through UGI Utilities, Inc. (UGI
Utilities) which operates a natural gas distribution utility in parts of
eastern and southeastern Pennsylvania and an electric utility in northeastern
Pennsylvania (collectively, "Utilities").
The rates Utilities can charge customers are subject to regulation by
the Pennsylvania Public Utility Commission (PUC). In addition, with respect to
activities involving the interstate movement of natural gas, the wheeling of
electricity, transactions with nonutility generators of electricity and other
matters, Gas Utility and Electric Utility are also subject to regulation by the
Federal Energy Regulatory Commission.
Gas Utility sells gas to residential, commercial and industrial
(collectively, "core market") customers. It also provides firm transportation
service to large commercial and industrial customers. Under transportation
service, Gas Utility bills for the transportation of the gas but not for the
gas itself. Gas Utility also sells and transports gas under interruptible rates
to customers who have alternate fuel capability. Interruptible rates are
competitively priced with respect to the prices of alternative fuels,
principally oil. Gas Utility's core market tariffs as well as the tariffs of
Electric Utility contain purchased gas cost (PGC) and energy cost (EC) rates
10 UGI Corporation 1996 Annual Report
<PAGE> 2
which provide for dollar-for-dollar recovery of prudently incurred gas costs
and costs to purchase or generate electricity. Although changes in these rates
affect revenues, they do not affect total margin because they are designed to
recover actual costs.
Federal and state regulators of the electric utility industry have
recently undertaken several actions to increase competition within the
industry. Certain states, including Pennsylvania, are also considering whether
natural gas transportation service options should be extended to residential
and small commercial accounts. Utilities does not expect that these actions
will have a material adverse effect on its financial condition and will
continue to monitor proceedings in these areas.
ENERGY MARKETING
UGI also owns an energy marketing business which is conducted through UGI
Enterprises, Inc. and its subsidiary, UGI Energy Services, Inc. (UGI Energy
Services). UGI Energy Services sells and markets natural gas under the
tradename of GASMARK directly to commercial and industrial customers and also
manages its delivery. GASMARK purchases natural gas for many of Gas Utility's
commercial and industrial customers as well as customers of other gas utilities
in the Mid-Atlantic and Northeast regions. Enterprises is also engaged in a
joint venture project in Romania and is pursuing other joint venture
opportunities for providing energy and related services in developing markets
outside of the U.S.
RESULTS OF OPERATIONS
All participants in the retail propane distribution business are affected by a
number of common factors. The business is highly competitive with numerous
large national and regional marketers and thousands of small independent
marketers. Propane competes with other sources of energy such as natural gas,
fuel oil and electricity. In addition, weather has a significant impact on
demand for propane and profitability principally because many customers use
propane for heating purposes. Geographic variations in weather can
significantly affect retail volumes and profitability primarily because of
regional differences in weather-sensitive volumes and unit margins. Regional
demand for propane can also be affected by economic conditions, particularly in
commercial and industrial markets.
The retail propane business is sensitive to changes in wholesale
propane prices. As a commodity, propane is subject to rapid price changes over
short periods of time. It is not always possible to pass on to customers rapid
increases in the wholesale cost of propane due to a number of factors including
competitive conditions in markets served by the Partnership. If increased
product costs are not passed on, margins will decline. The Partnership from
time to time enters into transactions to reduce the effects of product cost
volatility. Because the retail propane industry is relatively mature, low
growth in existing markets is expected for the foreseeable future.
Gas Utility results, and to a lesser extent Electric Utility results,
are also influenced by weather and by economic conditions in the regions in
which they operate. However, Gas Utility has sizable commercial and industrial
throughput which mitigates the effects of weather extremes. Much of this
nonresidential throughput is for customers with alternate fuel capability,
principally oil, and margins are affected by differences between the cost of
gas and the cost of the alternate fuels.
11
<PAGE> 3
FINANCIAL REVIEW (Continued)
GASMARK's results are affected by the volumes of gas sold and the
difference between its selling prices and the costs at which it can procure and
deliver the supply requirements of its customers. Volumes can be affected by
weather and economic conditions and, with respect to customers having alternate
fuel capabilities, the prices of alternate fuels.
The following analysis of the results of operations includes the
consolidated results of the Company and each of its principal business
segments. Comparisons of the results of the Company's consolidated propane
operations for 1996, 1995 and 1994 are complicated by the April 19, 1995
acquisition of the 65% of Petrolane Incorporated (Petrolane) not already owned
by the Company (the "Petrolane Merger") and the combining of its propane
business with the Company's then-existing consolidated propane business (the
"Partnership Formation"). In order to permit more meaningful analysis, the
discussion of consolidated propane is presented on a pro forma basis as if the
effects of the Petrolane Merger and the Partnership Formation had occurred as
of the beginning of 1994.
1996 COMPARED WITH 1995
CONSOLIDATED RESULTS
<TABLE>
<CAPTION>
Year ended September 30, 1996 1995 Increase
- -------------------------------------------------------------------------------------
(Millions of dollars, except per share)
<S> <C> <C> <C> <C>
Revenues $1,557.6 $877.6 $680.0 77.5%
Total margin $ 652.4 $426.1 $226.3 53.1%
Operating income $ 159.7 $ 78.3 $ 81.4 104.0%
Income from continuing
operations $ 39.5 $ 7.9 $ 31.6 400.0%
Net income (loss) $ 39.5 $ (8.4) $ 47.9 N.M.
Net income (loss)
per share $ 1.19 $ (.26) $ 1.45 N.M.
</TABLE>
N.M.-Not Meaningful.
The Company's results in 1996 reflect the full-year consolidation of
the Partnership, colder heating-season weather, and the full-year impact of Gas
Utility's 1995 base rate increase. Although the combined operating income of
the Gas and Electric utilities represented approximately 50% of 1996
consolidated operating income, Utilities provided more than 90% of the
Company's consolidated net income due to the Partnership's significant minority
interest, higher interest charges and higher effective income tax rate. Results
in 1995 include after-tax charges of $24.9 million associated with the
formation of AmeriGas Partners (see Note 2 to Consolidated Financial
Statements) and $3.1 million from a change in accounting for postemployment
benefits (see Note 7 to Consolidated Financial Statements).
CONSOLIDATED PROPANE
<TABLE>
<CAPTION>
Year ended September 30, 1996 1995 Increase
- --------------------------------------------------------------------------------------------
(Millions of dollars)
<S> <C> <C> <C> <C>
Actual:
Retail gallons sold--
millions 855.4 468.6 386.8 82.5%
Revenues $1,013.2 $511.7 $501.5 98.0%
Total margin $ 443.5 $250.7 $192.8 76.9%
Operating income $ 80.8 $ 21.8 $ 59.0 270.6%
EBITDA (1) $ 144.9 $ 62.6 $ 82.3 131.5%
Pro Forma:
Retail gallons sold--
millions 855.4 788.0 67.4 8.6%
Degree days--% colder
(warmer) than normal 1.4 (12.1) - -
Revenues $1,013.2 $878.6 $134.6 15.3%
Total margin $ 443.5 $419.6 $ 23.9 5.7%
Operating income $ 80.8 $ 73.7 $ 7.1 9.6%
EBITDA (1) $ 144.9 $138.0 $ 6.9 5.0%
</TABLE>
(1) EBITDA (earnings before interest expense, income taxes, depreciation and
amortization) should not be considered as an alternative to operating 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).
PRO FORMA PROPANE. Retail volumes of propane sold increased 67.4
million gallons in 1996 reflecting the effects of colder weather, acquisitions
and volume growth. Regional temperature differences in 1996 were significant
with the western U.S. experiencing substantially warmer than normal
temperatures and lower retail sales, and the eastern and midwestern U.S.
experiencing colder than normal temperatures and higher retail sales. Wholesale
volumes of propane sold were significantly higher reflecting an increase in
sales of low-margin excess storage inventories.
Total revenues increased during 1996 reflecting the increase in
propane sales as well as higher average retail propane selling prices. Total
cost of sales increased $110.7 million as a result of the higher volumes of
propane sold and higher average propane product costs. The Partnership's
propane product cost averaged approximately five cents a gallon higher in 1996
than in pro forma 1995. The spot price of propane at Mont Belvieu, Texas, a
major storage and distribution hub, increased dramatically in August and
September 1996, rising to 50.5 cents per gallon on September 30, 1996 compared
to 31.63 cents per gallon a year earlier. The general trend of propane product
cost increases has continued through November.
Total propane margin was higher in 1996 as a result of the greater
volumes of propane sold. Average retail unit margins in 1996 were slightly
lower than in pro forma 1995, notwithstanding an increase in average retail
selling price, reflecting the impact of higher average propane product costs
which were not completely passed through to customers.
The increases in 1996 operating income and EBITDA reflect principally
the increase in total propane margin partially offset by higher operating and
administrative expenses. Operating expenses in 1996 are net of $4.4 million
from a refund of insurance premium deposits made in prior years and $3.3
million from reductions to reserves for environmental matters recorded in the
quarter ended March 31. Operating expenses in pro forma 1995 include $4.3
million in accruals for management reorganization activities. Operating
expenses of
12 UGI Corporation 1996 Annual Report
<PAGE> 4
the Partnership, exclusive of these items, increased $27.8 million reflecting
higher employee compensation expenses associated with the Partnership's new
management structure; higher vehicle and distribution expenses due in part to
the higher retail volumes and severe eastern U.S. winter weather; higher
expenses associated with sales and marketing programs; increased customer
equipment repairs and maintenance expenses; and incremental costs associated
with acquisitions and new district locations. The Partnership instituted cost
reduction programs in mid-1996, which are continuing, in order to reduce the
level of operating and administrative costs.
UTILITIES
<TABLE>
<CAPTION>
Increase
Year ended September 30, 1996 1995 (Decrease)
- -------------------------------------------------------------------------------------------
(Millions of dollars)
<S> <C> <C> <C> <C>
GAS UTILITY:
Natural gas system
throughput--bcf 85.4 82.4 3.0 3.6%
Degree days--% colder
(warmer) than normal 4.2 (5.4) - -
Revenues $391.0 $291.3 $ 99.7 34.2%
Total margin $169.7 $140.9 $ 28.8 20.4%
Operating income $ 72.9 $ 51.9 $ 21.0 40.5%
ELECTRIC UTILITY:
Electric sales--gwh 884.7 860.9 23.8 2.8%
Degree days--% colder
(warmer) than normal 1.2 (16.3) - -
Revenues $ 69.5 $ 66.1 $ 3.4 5.1%
Total margin $ 33.0 $ 32.1 $ .9 2.8%
Operating income $ 8.6 $ 9.1 $ (.5) (5.5)%
</TABLE>
bcf-billions of cubic feet. gwh-millions of kilowatt hours. Total margin
represents revenues less cost of sales and revenue-related taxes.
GAS UTILITY. Weather in Gas Utility's service territory in 1996 was
colder than normal and also colder than in 1995. The increase in total system
throughput includes a 5.4 bcf increase in sales to core market customers and a
.7 bcf increase in throughput to interruptible customers. Partially offsetting
these increases was a decrease in firm delivery service volumes as a result of
customer switching to interruptible delivery service.
The increase in Gas Utility total revenues reflects higher sales to
core market customers, greater off-system sales, higher base rate revenues
resulting from Gas Utility's $19.5 million annual base rate increase effective
August 31, 1995, and lower refunds of producer settlement charges. Cost of gas
sold was $206.3 million during 1996, an increase of $67.7 million from 1995,
reflecting principally the greater sales to core market customers, higher
off-system sales, and lower refunds of producer settlement charges.
The increase in Gas Utility total margin in 1996 reflects a $34.5
million increase in total margin from core market customers as a result of the
colder weather and higher base rates. However, partially offsetting the
increase in core market margin was a decrease in total margin from
interruptible customers, principally as a result of higher 1996 gas costs, and
a decrease in total margin from firm delivery service customers due in large
part to the lower volumes.
Gas Utility operating income in 1996 benefitted from the increase in
total margin. However, the benefit was partially offset by higher operating and
administrative expenses and higher charges for depreciation.
ELECTRIC UTILITY. Electric Utility sales increased during 1996
principally from colder heating-season weather. The increase in Electric
Utility revenues reflects the impact of the higher sales, a higher EC rate, and
an increase in base rates effective July 19, 1996. Electric Utility cost of
sales was $33.4 million, an increase of $2.3 million from the prior year. The
increase in the cost of sales resulted from higher sales and a higher average
EC rate.
Electric Utility total margin increased as a result of the increased
sales and higher base rates effective in July. However, operating income
declined as the increase in Electric Utility total margin was more than offset
by higher distribution system maintenance expenses, general and administrative
expenses, and depreciation.
ENERGY MARKETING
<TABLE>
<CAPTION>
Year ended September 30, 1996 1995 Increase
- -------------------------------------------------------------------------------------
(Millions of dollars)
<S> <C> <C> <C> <C>
Total margin $6.2 $2.4 $3.8 158.3%
Operating income $4.4 $1.8 $2.6 144.4%
</TABLE>
ENERGY MARKETING. Total margin and operating income from energy
marketing activities were significantly higher in 1996 reflecting higher billed
volumes from an increase in sales outside the Gas Utility service territory.
Unit margins also were significantly higher in 1996 due to favorable gas supply
purchases.
1995 COMPARED WITH 1994
CONSOLIDATED RESULTS
<TABLE>
<CAPTION>
Increase
Year ended September 30, 1995 1994 (Decrease)
- ---------------------------------------------------------------------------------------------------------------------------
(Millions of dollars, except per share)
<S> <C> <C> <C> <C>
Revenues $877.6 $762.2 $ 115.4 15.1%
Total margin $426.1 $364.0 $ 62.1 17.1%
Operating income $ 78.3 $116.4 $ (38.1) (32.7)%
Income from continuing
operations $ 7.9 $ 37.4 $ (29.5) (78.9)%
Net income (loss) $ (8.4) $ 45.0 $ (53.4) N.M.
Net income (loss)
per share $ (.26) $ 1.39 $ (1.65) N.M.
</TABLE>
The Company's results in 1995 reflect the impact of $24.9 million in
transaction costs related to the Partnership Formation, a higher seasonal
propane loss subsequent to April 19 resulting principally from the
consolidation of the operations of Petrolane, and the impact of significantly
warmer heating-season weather in the Company's utility and propane operating
territories. In addition, 1995 net loss includes a charge of $3.1 million from
a change in accounting for postemployment benefits while 1994 net income
includes $7.6 million of income from discontinued operations (see Note 16 to
Consolidated Financial Statements).
13
<PAGE> 5
CONSOLIDATED PROPANE
<TABLE>
<CAPTION>
Increase
Year ended September 30, 1995 1994 (Decrease)
- ----------------------------------------------------------------------------------------------
(Millions of dollars)
<S> <C> <C> <C> <C>
ACTUAL:
Retail gallons sold--
millions 468.6 332.4 136.2 41.0%
Revenues $511.7 $367.1 $144.6 39.4%
Total margin $250.7 $190.3 $ 60.4 31.7%
Operating income $ 21.8 $ 55.0 $(33.2) (60.4)%
EBITDA $ 62.6 $ 78.1 $(15.5) (19.8)%
PRO FORMA:
Retail gallons sold--
millions 788.0 829.3 (41.3) (5.0)%
Degree days--% colder
(warmer) than normal (12.1) (3.3) - -
Revenues $878.6 $949.1 $(70.5) (7.4)%
Total margin $419.6 $461.0 $(41.4) (9.0)%
Operating income $ 73.7 $129.8 $(56.1) (43.2)%
EBITDA $138.0 $192.2 $(54.2) (28.2)%
</TABLE>
PRO FORMA PROPANE. Retail volumes of propane sold in 1995 were lower
principally due to warmer weather and, to a lesser extent, modest customer
losses. The lower volumes, combined with lower average retail selling prices
and lower wholesale sales, were the principal reasons for the decrease in total
propane revenues. The 1995 average retail selling price in the Partnership's
residential market, which market represented approximately 40% of total retail
gallons and more than half of total retail margin in 1995, was more than two
cents a gallon lower than in 1994. The decrease reflects to a large extent the
impact of aggressive sales and marketing programs initiated mid-year to improve
customer retention rates and to attract new customers.
Total propane margin was lower in 1995 reflecting lower retail sales,
a decrease in average retail selling prices, and slightly higher average
product costs.
Operating income and EBITDA declined in 1995 reflecting the decrease
in total margin and higher operating expenses including $4.3 million of accrued
expenses relating to management organizational changes, higher expenses
associated with sales and marketing programs, and higher employee compensation
expenses.
UTILITIES
<TABLE>
<CAPTION>
Increase
Year ended September 30, 1995 1994 (Decrease)
- -----------------------------------------------------------------------------------------------------
(Millions of dollars)
<S> <C> <C> <C> <C>
GAS UTILITY:
Natural gas system
throughput--bcf 82.4 83.5 (1.1) (1.3)%
Degree days--% colder
(warmer) than normal (5.4) 11.4 - -
Revenues $291.3 $331.4 $(40.1) (12.1)%
Total margin $140.9 $141.7 $ (.8) (.6)%
Operating income $ 51.9 $ 54.6 $ (2.7) (4.9)%
ELECTRIC UTILITY:
Electric sales--gwh 860.9 873.7 (12.8) (1.5)%
Degree days--% colder
(warmer) than normal (16.3) 1.9 - -
Revenues $ 66.1 $ 63.7 $ 2.4 3.8%
Total margin $ 32.1 $ 31.0 $ 1.1 3.5%
Operating income $ 9.1 $ 8.5 $ .6 7.1%
</TABLE>
GAS UTILITY. Results in 1995 were impacted by warmer heating-season
weather which reduced sales to core market customers. Although the warmer
weather reduced core market sales, it resulted in fewer interruptions of
service to interruptible customers. During 1994, severely cold January and
February weather resulted in significant interruptions of service to these
customers. Such interruptions were necessary to meet the higher demand for gas
from firm customers.
The decrease in 1995 Gas Utility revenues includes a $42.1 million
decrease in revenues from core market customers reflecting lower volumes sold,
lower PGC rates and the full-year pass-through of producer settlement refunds
partially offset by the one-month effect of Gas Utility's $19.5 million annual
base rate settlement. Cost of gas sold was $138.6 million in 1995 compared with
$175.8 million in 1994 reflecting the recovery of lower purchased gas costs
through PGC rates and lower volumes of gas sold to core market customers.
The decrease in 1995 total margin reflects a $5.3 million decrease in
total margin from core market customers, a $2.1 million decrease in total
margin from firm delivery service customers, and the fact that 1994 margin
includes $1.4 million of income resulting from the PUC's June 2, 1994 decision
on the sharing of producer settlement refunds (see Note 4 to Consolidated
Financial Statements). Offsetting these decreases was an $8.1 million increase
in interruptible margin reflecting higher interruptible volumes and higher
average margins resulting from a greater difference between gas and oil prices
despite relatively stable oil prices.
Gas Utility operating income declined as a result of the lower total
margin, higher charges for depreciation, higher customer service and
information expenses, and costs associated with Gas Utility's base rate filing.
14 UGI Corporation 1996 Annual Report
<PAGE> 6
ELECTRIC UTILITY. Sales in 1995 decreased principally as a result of
the warmer winter's effect on heating-related sales. The decrease was
partially offset by greater sales during the cooling season resulting from
record-setting temperatures in July and August 1995. Notwithstanding the lower
1995 sales, Electric Utility revenues increased as a result of a higher average
1995 EC rate and slightly higher base rate revenues from the full-year effect
of the July 1994 $1.3 million annual base rate increase. Cost of sales
increased $1.3 million, despite the lower sales, as a result of the greater
average EC rate. Electric Utility total margin increased $1.1 million in 1995
due to the full-year effect of the July 1994 base rate increase. However, the
increase in total margin was partially offset by higher charges for
depreciation and greater system distribution expenses.
ENERGY MARKETING
<TABLE>
<CAPTION>
Year ended September 30, 1995 1994 Increase
- --------------------------------------------------------------------------------
(Millions of dollars)
<S> <C> <C> <C> <C>
Total margin $2.4 $1.0 $1.4 140.0%
Operating income $1.8 $ .8 $1.0 125.0%
</TABLE>
ENERGY MARKETING. Total margin from energy marketing activities in
1995 was higher than in 1994 due to higher unit margins and higher billed
sales. The increase in unit margins reflects in large part lower natural gas
costs.
FINANCIAL CONDITION AND LIQUIDITY
CAPITALIZATION AND LIQUIDITY
AMERIGAS PARTNERS. AmeriGas Partners' debt outstanding at September 30, 1996
totaled $707.5 million compared to $657.7 million at September 30, 1995. The
increase is principally a result of $52 million in combined borrowings under
the Operating Partnership's Bank Credit Facilities. The Bank Credit Facilities
consist of a Revolving Credit Facility, an Acquisition Facility and a Special
Purpose Facility, each governed by the Bank Credit Agreement. The Operating
Partnership's obligations under these facilities are collateralized by
substantially all of its assets.
The Operating Partnership's revolving credit facilities which include
the Revolving Credit Facility, the General Partner Credit Facility, and a
portion of the Special Purpose Facility as described below, provide for
borrowings of up to $105 million to fund working capital, capital expenditures,
and interest and distribution payments. The Revolving Credit Facility provides
for borrowings of up to $70 million including a $35 million sublimit for
letters of credit. Borrowings under this facility totaled $15 million at
September 30, 1996. The Revolving Credit Facility expires April 12, 1998, but
may be extended, upon timely notice, for additional one-year periods with the
consent of the participating banks representing at least 80% of the commitments
thereunder.
The General Partner Credit Facility, which became effective October
28, 1996, provides for borrowings of up to $20 million. This agreement is
coterminous with the Operating Partnership's Revolving Credit Facility.
Borrowings under the General Partner Credit Facility will be unsecured and
subordinated in right of payment to all of the Partnership's existing senior
debt. UGI has agreed to contribute on an as needed basis through its
subsidiaries up to $20 million to the General Partner to fund such borrowings.
The Special Purpose Facility is a $30 million nonrevolving line of
credit which can be used for the payment of certain liabilities of Petrolane
assumed by the Operating Partnership that relate to potential liabilities for
tax, insurance and environmental matters. The Special Purpose Facility expires
April 12, 2000 at which time all amounts then outstanding will become
immediately due and payable. Effective October 28, 1996, the Bank Credit
Agreement was amended to include a revolving $15 million sublimit under the
Special Purpose Facility which can be used to fund working capital, capital
expenditures, and interest and distribution payments. This sublimit is
scheduled to expire April 12, 1998. As of September 30, 1996, there were $7
million in special purpose borrowings outstanding under the Special Purpose
Facility.
The Acquisition Facility provides the Operating Partnership with the
ability to borrow up to $75 million to finance propane business acquisitions.
The Acquisition Facility operates as a revolving facility through October 12,
1997 at which time any amounts then outstanding will convert to a quarterly
amortizing 4 1/2-year term loan. The Partnership expects to refinance such loans
on a long-term basis. As of September 30, 1996, there were $30 million in loans
outstanding under the Acquisition Facility.
The ability of the Partnership to issue debt under the above
facilities is subject to provisions in the Partnership's loan agreements which
require, among other things, minimum debt-to-capital and interest coverage
ratios. Based upon such ratios calculated as of September 30, 1996, the
Operating Partnership could borrow the maximum amount available under its
Revolving Credit, Special Purpose and General Partner revolving credit
facilities.
15
<PAGE> 7
The Partnership has succeeded to certain lease guarantees and
scheduled claim obligations relating to certain of Petrolane's former
businesses and has also succeeded to Petrolane's agreements with third parties
for payment indemnification relating to such obligations. At September 30,
1996, the lease guarantee obligations totaled approximately $91 million and
scheduled claims of at least $68 million were pending. To date, the Partnership
has not paid any amounts under these lease guarantee and scheduled claim
obligations (see Note 12 to Consolidated Financial Statements).
UGI UTILITIES. UGI Utilities' debt outstanding at September 30, 1996
totaled $227.2 million compared to $250.2 million at September 30, 1995. The
decrease principally reflects the redemption of $45.9 million face value of 9%
First Mortgage Bonds from the proceeds of UGI Utilities' September 1995
issuance of $22 million of twenty-year notes and $26 million of seven-year
notes. During 1996, UGI Utilities issued $20 million of 6.62% notes due May 15,
2005 the proceeds of which were used to reduce UGI Utilities' bank loans. UGI
Utilities has a shelf registration for the issuance from time to time of up to
$75 million of debt securities, none of which has been issued. UGI Utilities
has revolving credit agreements providing for borrowings of up to $67 million
under committed lines through June 30, 1999. At September 30, 1996, borrowings
under its revolving credit agreements totaled $50.5 million.
DIVIDENDS AND DISTRIBUTIONS
In April 1996, 1995 and 1994, UGI increased the annual dividend rate
on its Common Stock to $1.42, $1.40 and $1.38, respectively. As a holding
company, the ability of UGI to declare and pay cash dividends is substantially
dependent upon its cash balances and the receipt of cash dividends from its
wholly owned operating subsidiaries, principally UGI Utilities and AmeriGas.
AmeriGas's ability to pay dividends is dependent on distributions from the
Partnership. During 1996, UGI Utilities and AmeriGas paid cash dividends of
$32.9 million and $61.9 million, respectively, to UGI.
The Company has a 58.7% effective interest in the Partnership
comprising 4.3 million Common Units, 19.8 million Subordinated Units and a 2%
general partner interest. The remaining 41.3% effective interest, comprising
17.6 million Common Units, is publicly held. The Partnership makes
distributions to its partners approximately 45 days after the end of each
fiscal quarter in an amount equal to its Available Cash (as defined in the
Amended and Restated Agreement of Limited Partnership) for such quarter,
subject to limitations under its loan agreements. (For a description of
Available Cash and the priority of its distribution to unitholders, see Note 2
to Consolidated Financial Statements). During 1996, the Partnership paid the
full Minimum Quarterly Distribution (MQD) of $.55 on all limited partner units
outstanding. The amount of Available Cash needed to distribute the MQD on all
such units as well as the 2% general partner interest during 1996 was
approximately $93.7 million ($48.3 million for the Common Units; $43.5 million
for the Subordinated Units; and $1.9 million for the general partner
interests). A reasonable proxy for the amount of distributable cash actually
generated by the Partnership during 1996, determined by subtracting maintenance
capital expenditures of $9.3 million from the Partnership's earnings before
depreciation and amortization, was approximately $63 million. Although
distributions in 1996 were in excess of cash generated by the Partnership, the
Partnership had cash and short-term investment balances of $48.6 million at the
beginning of the year. Due to the seasonality of its operating cash flows and
working capital needs, during 1996 the Partnership was required on a short-term
basis to use the Revolving Credit Facility to fund a portion of
16 UGI Corporation 1996 Annual Report
<PAGE> 8
such distribution payments. Although the level of distributable cash generated
in 1996 is more than sufficient to pay the full MQD on all Common Units, the
ability of the Partnership to continue to pay the full MQD on its Subordinated
Units will depend upon a number of factors including a significant improvement
in the level of Partnership earnings, the cash needs of the Partnership's
operations (including cash needed for maintenance and growth capital), and the
Partnership's ability to finance externally such cash needs. The Partnership's
management expects the Partnership's earnings to improve as a result of a
number of factors including a continued focus on reducing operating expenses,
volume increases through acquisitions and internal growth, increased monitoring
of pricing, improved propane product cost management, and improved customer
retention as a result of an emphasis on customer service. Such earnings
improvement, however, is subject to a number of factors beyond the control of
the Partnership including weather, competitive conditions in the markets served
by the Partnership, and the cost of propane, among others.
As further described in Note 2 to Consolidated Financial Statements,
the Subordinated Units' period of subordination will generally extend until the
first day of any quarter beginning on or after April 1, 2000 in respect of
which certain cash performance and distribution measurements are attained. In
addition, if the Partnership attains certain cash performance and distribution
measurements, 4.9 million Subordinated Units may convert to Common Units on or
after March 31, 1998 and an additional 4.9 million Subordinated Units may
convert on or after March 31, 1999. Based upon such cash performance
measurements to date, it appears unlikely that the cash performance
measurements required for early conversion will be attained by March 31, 1998.
CAPITAL EXPENDITURES
The following table presents capital expenditures, including capital leases, by
business segment for 1996, 1995 and 1994, as well as expected amounts for
fiscal 1997. The Company expects to finance 1997 capital expenditures through
internally generated cash and borrowings under UGI Utilities' and the
Partnership's credit facilities. The table excludes amounts relating to
acquisitions.
<TABLE>
<CAPTION>
Year ended September 30, 1997 1996 1995 1994
- -----------------------------------------------------------------------------------------------------
(Millions of dollars) (estimate)
<S> <C> <C> <C> <C>
Consolidated propane $27.1 $22.9 $17.2 $10.9
Gas Utility 36.0 34.6 45.3 33.1
Electric Utility 5.1 5.0 6.0 6.0
Other (including corporate) .7 .2 .3 .1
- -----------------------------------------------------------------------------------------------------
$68.9 $62.7 $68.8 $50.1
</TABLE>
CASH FLOWS
The Company's consolidated cash and cash equivalents totaled $74.0 million at
September 30, 1996 compared with $121.7 million at September 30, 1995. Included
in these amounts are cash and cash equivalents at UGI of $51.4 million and
$19.2 million, respectively. At September 30, 1996 and 1995, UGI also had
short-term investments of $23.1 million and $2.0 million, respectively.
OPERATING ACTIVITIES. Consolidated cash flow from operating activities
was $111.2 million in 1996 compared with $76.8 million in 1995. Cash flows from
operating activities before changes in operating working capital were $138.3
million in 1996 compared with $66.9 million in 1995. During 1996, the Company's
major operating subsidiaries UGI Utilities and AmeriGas Partners provided $71.7
million and $68.4 million, respectively, of operating cash flow before changes
in working capital. The significant increase in 1996 consolidated operating
cash flow before changes in working capital reflects the full-period
consolidation of the operations of Petrolane subsequent to the Partnership
Formation and improved consolidated propane and Gas Utility results. Changes in
operating working capital in 1996 reflect a net use of cash of $27.1 million
principally from an increase in accounts receivable, an increase in
inventories, and undercollections of purchased gas costs partially offset by an
increase in accounts payable. In 1995, changes in operating working capital
provided $9.9 million in operating cash flows.
INVESTING ACTIVITIES. Expenditures for property, plant and equipment
totaled $62.7 million in 1996 compared with $68.8 million in 1995. The decrease
in capital expenditures reflects an $11.7 million decrease in UGI Utilities'
capital expenditures, principally Gas Utility, and an increase in consolidated
propane capital expenditures due to the full-year consolidation of the
operations of Petrolane. During 1996, the Company paid an aggregate $28.0
million for propane business acquisitions which were financed through the
issuance of Partnership debt.
FINANCING ACTIVITIES. During 1996, the Company paid cash dividends of
$46.4 million compared with $45.2 million in the prior year. In addition, the
Partnership paid distributions of $38.7 million to public unitholders (and
$55.0 million to the General Partner) representing the MQD on all Partnership
units. Net borrowings during 1996 under UGI Utilities' and the Operating
Partnership's working capital facilities were $8.5 million and $15.0 million,
respectively. During 1996, in addition to scheduled maturities of long-term
debt, UGI Utilities redeemed $45.9 million face value of its 9% First Mortgage
Bonds at a redemption price of 104% of the principal amount outstanding and
issued $20 million of notes under its Medium-Term Note program. During 1996,
the Partnership borrowed an aggregate $37 million under its Acquisition and
Special Purpose facilities. Pursuant to its continuing stock buy-back program,
UGI repurchased $7.1 million of its Common Stock.
UTILITY BASE RATES
During the three-year period ended September 30, 1996, the following increases
in Gas and Electric utilities' base rates became effective:
<TABLE>
<CAPTION>
Increase in Annual
Revenues
----------------------
Division Effective Date Requested Granted
- ----------------------------------------------------------------------------------------
(Millions of dollars)
<S> <C> <C> <C>
Electric Utility July 19, 1996 $ 6.2 $ 3.1
Gas Utility August 31, 1995 41.3 19.5
Electric Utility July 27, 1994 4.2 1.3
</TABLE>
17
<PAGE> 9
MANUFACTURED GAS PLANTS
The gas distribution business has been one of UGI Utilities' principal lines of
business since its inception in 1882. Prior to the construction of major
natural gas pipelines in the 1950s, gas for lighting and heating was produced
at manufactured gas plants (MGPs) from processes involving coal, coke or oil.
Some constituents of coal tars produced from the manufactured gas process are
today considered hazardous substances under the Comprehensive Environmental
Response, Compensation and Liability Act (Superfund Law) and may be located at
those sites.
One of the ways UGI Utilities initially expanded its business in its
early years was by entering into agreements with other gas companies to operate
their businesses. After 1888, the principal means by which UGI Utilities
expanded its gas business was to acquire all or a portion of the stock of
companies engaged in this business. UGI Utilities also provided management and
administrative services to some of these companies. UGI Utilities grew rapidly
to become one of the largest public utility holding companies in the U.S.
Pursuant to the Public Utility Holding Company Act of 1935, UGI Utilities
divested all of its utility operations other than those which now constitute
Gas Utility and Electric Utility.
The Company has been notified of several sites outside Pennsylvania
where MGPs were operated by UGI Utilities or owned or operated by its former
subsidiaries and environmental agencies or private parties are investigating
the extent of environmental contamination and the necessity of environmental
remediation. If UGI Utilities were found liable as a "responsible party" as
defined in the Superfund Law (or comparable state statutes) with respect to any
of these sites, it would have joint and several liability with other
responsible parties for the full amount of the cleanup costs. A "responsible
party" under that statute includes the current owner of the affected property
and each owner or operator of a facility during the time when hazardous
substances were released on the property.
Management believes that UGI Utilities should not have significant
liability in those instances in which a former subsidiary operated a MGP
because UGI Utilities generally is not legally liable for the obligations of
its subsidiaries. Under certain circumstances, however, courts have found
parent companies liable for environmental damage caused by subsidiary companies
when the parent company exercised substantial control over the subsidiary.
There could be, therefore, significant future costs of an uncertain amount
associated with environmental damage caused by MGPs that UGI Utilities owned or
directly operated, or that were owned or operated by former subsidiaries of UGI
Utilities if a court were to conclude that UGI Utilities exercised substantial
control over such subsidiaries.
The Company's policy is to accrue environmental investigation and
cleanup costs when it is probable that a liability exists and the amount or
range of amounts is reasonably estimable. Management believes, after
consultation with counsel, that future costs of investigation and remediation,
if any, will not have a material adverse effect on the Company's financial
position but could be material to operating results and cash flows depending on
the nature and timing of future developments and the amounts of future
operating results and cash flows. The Company intends to pursue recovery of
these costs through all appropriate means, including regulatory relief,
although such recovery cannot be assured. For a more detailed discussion of
environmental matters related to MGP sites, see Note 12 to Consolidated
Financial Statements.
ACCOUNTING PRINCIPLES NOT YET
ADOPTED
In October 1995, the Financial Accounting Standards Board issued Statement of
Financial Accounting Standards No. 123, "Accounting for Stock-Based
Compensation" (SFAS 123). SFAS 123 encourages, but does not require, companies
to recognize compensation expense for grants of stock, stock options, and other
equity instruments to employees based upon fair value or, alternatively,
permits them to continue to apply the existing accounting rules contained in
Accounting Principles Board Opinion No. 25, "Accounting for Stock Issued to
Employees" (APB No. 25). Companies choosing not to adopt the expense
recognition provisions of SFAS 123 are required to disclose pro forma net
income and earnings per share data as if such provisions had been applied. The
Company will adopt SFAS 123 in fiscal 1997 and will continue to account for
stock-based compensation in accordance with APB No. 25. As a result, the
adoption of SFAS 123 will not have an impact on the Company's financial
position or results of operations.
IMPACT OF INFLATION
Inflation impacts the Company's propane operations in the prices it pays for
operating and administrative services and, to some extent, propane gas.
Competitive pressures in recent years have limited the Company's ability to
recover fully propane product cost increases.
Inflation also impacts the Company's gas and electric utility
operations primarily in the prices they pay for labor, materials and services.
Because Gas and Electric utilities' base rates can be adjusted only through
general rate filings with the PUC, increased costs, absent timely rate relief,
can have a significant impact on the utilities' results. Under current tariffs,
Gas and Electric utilities are permitted, after annual PUC review, to recover
certain costs of purchased gas, fuel and power which comprise a substantial
portion of Gas and Electric utilities' costs and expenses.
The Company attempts to limit the effects of inflation on its results
of operations through cost control efforts, productivity improvements and, with
respect to Gas and Electric utilities, timely rate relief.
FORWARD-LOOKING STATEMENTS
Except for the historical information contained herein, certain of the matters
discussed in this Report are forward-looking statements that are subject to
risks and uncertainties. The factors that could cause actual results to differ
materially include those discussed herein as well as those listed in Exhibit 99
to the Company's Annual Report on Form 10-K for the year ended September 30,
1996. Readers are cautioned not to place undue reliance on these
forward-looking statements, which speak only as of the date of this Report. The
Company undertakes no obligation to publicly release any revision to these
forward-looking statements to reflect events or circumstances after the date of
this Report.
18 UGI Corporation 1996 Annual Report
<PAGE> 10
INDEX TO FINANCIAL INFORMATION
UGI CORPORATION AND SUBSIDIARIES
<TABLE>
<S> <C>
SEGMENT INFORMATION . . . . . . . . . . . . . . . . . . . . . 20
CONSOLIDATED STATEMENTS OF INCOME . . . . . . . . . . . . . . 21
CONSOLIDATED BALANCE SHEETS . . . . . . . . . . . . . . . . . 22
CONSOLIDATED STATEMENTS OF CASH FLOWS . . . . . . . . . . . . 24
CONSOLIDATED STATEMENTS OF
STOCKHOLDERS' EQUITY . . . . . . . . . . . . . . . . . . . 25
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS . . . . . . . . . 26
REPORT OF MANAGEMENT . . . . . . . . . . . . . . . . . . . . 39
REPORT OF INDEPENDENT ACCOUNTANTS . . . . . . . . . . . . . . 39
FINANCIAL STATISTICS . . . . . . . . . . . . . . . . . . . . 40
OPERATING STATISTICS . . . . . . . . . . . . . . . . . . . . 42
SHAREHOLDER INFORMATION . . . . . . . . . . . . . . . . . . . 44
</TABLE>
19
<PAGE> 11
SEGMENT INFORMATION
(Millions of dollars)
UGI CORPORATION AND SUBSIDIARIES
<TABLE>
<CAPTION>
Year Ended
September 30,
-------------------------------------------------------------------
1996 1995 1994
==================================================================================================================================
<S> <C> <C> <C> <C>
REVENUES Propane $1,013.2 $ 511.7 $ 367.1
Gas utility 391.0 291.3 331.4
Electric utility 69.5 66.1 63.7
Energy marketing (a) 83.9 8.5 -
----------------------------------------------------------------------------------------------------------------
Total consolidated operations $1,557.6 $ 877.6 $ 762.2
Petrolane (b) - 372.1 589.7
==================================================================================================================================
OPERATING Propane $ 80.8 $ 21.8 $ 55.0
INCOME Gas utility 72.9 51.9 54.6
(LOSS) Electric utility 8.6 9.1 8.5
Energy marketing 4.4 1.8 .8
Petrolane management fee - 6.8 11.7
Corporate general and other (7.0) (13.1) (14.2)
----------------------------------------------------------------------------------------------------------------
Total consolidated operations $ 159.7 $ 78.3 $ 116.4
Petrolane (b) - 41.5 56.9
==================================================================================================================================
IDENTIFIABLE Propane $1,400.2 $1,457.8 $ 547.7
ASSETS Gas utility 561.1 553.7 482.1
Electric utility 83.9 86.6 77.6
Energy marketing 13.5 6.2 .3
Corporate general and other 86.2 59.7 74.5
----------------------------------------------------------------------------------------------------------------
Total consolidated operations $2,144.9 $2,164.0 $1,182.2
Petrolane (b) - - 914.2
==================================================================================================================================
DEPRECIATION Propane--depreciation $ 38.3 $ 23.8 $ 13.7
AND Propane--amortization 25.8 17.0 9.4
AMORTIZATION Gas utility 17.6 16.1 15.1
Electric utility 4.0 3.7 3.4
Corporate general and other .3 .3 .2
----------------------------------------------------------------------------------------------------------------
Total consolidated operations $ 86.0 $ 60.9 $ 41.8
Petrolane--depreciation (b) - 13.1 21.0
Petrolane--amortization (b) - 14.3 25.0
==================================================================================================================================
CAPITAL Propane $ 22.9 $ 17.2 $ 10.9
EXPENDITURES Gas utility 34.6 45.3 33.1
Electric utility 5.0 6.0 6.0
Corporate general and other .2 .3 .1
----------------------------------------------------------------------------------------------------------------
Total consolidated operations $ 62.7 $ 68.8 $ 50.1
Petrolane (b) - 7.3 25.1
==================================================================================================================================
</TABLE>
(a) Subsequent to July 31, 1995, the Company's energy
marketing business records separately the revenues and
related cost of sales associated with its billed
volumes. Prior to August 1, 1995, net margin from the
Company's energy marketing business was reflected as a
component of miscellaneous income.
(b) Includes 100% of amounts for Petrolane through April
19, 1995. The results of operations of Petrolane are
reflected in the consolidated financial statements of
the Company on the equity method of accounting through
April 19, 1995.
20 UGI Corporation 1996 Annual Report
<PAGE> 12
CONSOLIDATED STATEMENTS OF INCOME
(Millions of dollars, except per share amounts)
UGI CORPORATION AND SUBSIDIARIES
<TABLE>
<CAPTION>
Year Ended
September 30,
-----------------------------------------------------
1996 1995 1994
=================================================================================================================================
<S> <C>
REVENUES Propane $1,013.2 $511.7 $367.1
(note 1) Utilities 460.5 357.4 395.1
Energy marketing 83.9 8.5 -
---------------------------------------------------------------------------------------------------------------
1,557.6 877.6 762.2
- ---------------------------------------------------------------------------------------------------------------------------------
COSTS AND Propane cost of sales 569.7 261.0 176.8
EXPENSES Utilities--gas, fuel and purchased power (note 1) 239.7 169.7 205.6
Energy marketing cost of sales 77.7 8.0 -
Operating and administrative expenses 437.5 331.6 264.0
Depreciation and amortization (note 1) 86.0 60.9 41.8
Petrolane fee income (note 3) - (20.5) (33.3)
Miscellaneous income, net (note 14) (12.7) (11.4) (9.1)
---------------------------------------------------------------------------------------------------------------
1,397.9 799.3 645.8
- ---------------------------------------------------------------------------------------------------------------------------------
OPERATING INCOME 159.7 78.3 116.4
Interest charges, net (79.5) (59.3) (43.3)
Minority interest in AmeriGas Partners (notes 1 and 2) (4.3) 19.7 -
---------------------------------------------------------------------------------------------------------------
INCOME BEFORE INCOME TAXES, SUBSIDIARY PREFERRED
STOCK DIVIDENDS AND EQUITY IN PETROLANE 75.9 38.7 73.1
Income taxes (notes 1, 2 and 6) (33.6) (22.7) (33.4)
Dividends on UGI Utilities Series
Preferred Stock (2.8) (2.8) (1.3)
Equity in Petrolane (notes 1, 2 and 3) - (5.3) (1.0)
---------------------------------------------------------------------------------------------------------------
INCOME FROM CONTINUING OPERATIONS 39.5 7.9 37.4
Income from discontinued operations (note 16) - - 7.6
---------------------------------------------------------------------------------------------------------------
INCOME BEFORE EXTRAORDINARY LOSS
AND ACCOUNTING CHANGE 39.5 7.9 45.0
Extraordinary loss--propane debt restructuring (note 2) - (13.2) -
Change in accounting for postemployment
benefits (note 7) - (3.1) -
- ---------------------------------------------------------------------------------------------------------------------------------
NET INCOME (LOSS) $ 39.5 $ (8.4) $ 45.0
=================================================================================================================================
EARNINGS (LOSS) Continuing operations $ 1.19 $ .24 $ 1.16
PER COMMON Discontinued operations - - .23
SHARE ----------------------------------------------------------------------------------------------------------------
Earnings before extraordinary loss
and accounting change 1.19 .24 1.39
Extraordinary loss--propane debt restructuring - (.40) -
Change in accounting for postemployment benefits - (.10) -
---------------------------------------------------------------------------------------------------------------
Net earnings (loss) $ 1.19 $ (.26) $ 1.39
=================================================================================================================================
</TABLE>
The accompanying notes are an integral part of these
financial statements.
21
<PAGE> 13
CONSOLIDATED BALANCE SHEETS
(Millions of dollars)
UGI CORPORATION AND SUBSIDIARIES
<TABLE>
<CAPTION>
ASSETS September 30,
--------------------------------------
1996 1995
=============================================================================================================================
<S> <C>
CURRENT Cash and cash equivalents (note 1) $ 74.0 $ 121.7
ASSETS Short-term investments, at cost which approximates market value 23.1 11.0
Accounts receivable (less allowances for
doubtful accounts of $10.6 and $7.3, respectively) 113.3 85.9
Accrued utility revenues (note 1) 8.6 7.9
Inventories (notes 1 and 8) 113.2 102.2
Deferred income taxes (notes 1 and 6) 17.4 22.1
Insurance indemnification receivable 19.0 -
Prepaid expenses and other current assets 13.0 16.5
-----------------------------------------------------------------------------------------------------------
Total current assets 381.6 367.3
- -----------------------------------------------------------------------------------------------------------------------------
PROPERTY, Propane 602.0 566.3
PLANT AND Utilities 729.9 697.6
EQUIPMENT Other 10.9 10.8
(notes 1 and 5) -----------------------------------------------------------------------------------------------------------
1,342.8 1,274.7
Less accumulated depreciation and amortization 368.2 320.0
-----------------------------------------------------------------------------------------------------------
Net property, plant and equipment 974.6 954.7
- -----------------------------------------------------------------------------------------------------------------------------
OTHER Intangible assets (less accumulated amortization
ASSETS of $94.9 and $74.3, respectively) (note 1) 692.5 740.7
Regulatory income tax asset (notes 1 and 6) 42.9 36.9
Other assets (note 1) 53.3 64.4
- -----------------------------------------------------------------------------------------------------------------------------
Total assets $2,144.9 $2,164.0
=============================================================================================================================
</TABLE>
The accompanying notes are an integral part of these
financial statements.
22 UGI Corporation 1996 Annual Report
<PAGE> 14
<TABLE>
<CAPTION>
LIABILITIES AND STOCKHOLDERS' EQUITY September 30,
--------------------------------------------
1996 1995
- -----------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
CURRENT Current maturities of long-term debt--Propane (note 5) $ 5.2 $ 5.4
LIABILITIES Current maturities of long-term debt--Utilities (note 5) 25.5 53.2
Current maturities of long-term debt--other (note 5) .4 .3
Bank loans--Propane (note 5) 15.0 -
Bank loans--Utilities (note 5) 50.5 42.0
Accounts payable 94.7 69.1
Employee compensation and benefits accrued 32.4 29.1
Dividends and interest accrued 44.8 44.5
Income taxes accrued 14.4 13.1
Insured property and casualty liability 19.0 -
Refunds and deposits 17.7 16.3
Other accrued liabilities 49.6 56.3
-----------------------------------------------------------------------------------------------------------------
Total current liabilities 369.2 329.3
- -----------------------------------------------------------------------------------------------------------------------------------
DEBT AND Long-term debt--Propane (note 5) 687.3 653.1
OTHER Long-term debt--Utilities (note 5) 149.3 153.1
LIABILITIES Long-term debt--other (note 5) 8.6 9.0
Deferred income taxes (notes 1 and 6) 148.6 169.5
Deferred investment tax credits (notes 1 and 6) 10.8 11.2
Other noncurrent liabilities 73.9 104.2
Commitments and contingencies (note 12)
- -----------------------------------------------------------------------------------------------------------------------------------
MINORITY
INTEREST Minority interest in AmeriGas Partners (notes 1 and 2) 284.4 318.9
- -----------------------------------------------------------------------------------------------------------------------------------
PREFERRED AND UGI Utilities Series Preferred Stock Subject to
PREFERENCE Mandatory Redemption, without par value (note 9) 35.2 35.2
STOCK Preference Stock, without par value (note 10)
(authorized--5,000,000 shares) - -
- -----------------------------------------------------------------------------------------------------------------------------------
COMMON Common Stock, without par value (notes 10 and 11)
STOCKHOLDERS' (authorized--100,000,000 shares; issued--33,198,731
EQUITY and 32,921,830 shares, respectively) 391.9 386.1
Accumulated deficit (12.8) (5.5)
-----------------------------------------------------------------------------------------------------------------
379.1 380.6
Less treasury stock, at cost (note 11) 1.5 .1
-----------------------------------------------------------------------------------------------------------------
Total common stockholders' equity 377.6 380.5
- -----------------------------------------------------------------------------------------------------------------------------------
Total liabilities and stockholders' equity $2,144.9 $2,164.0
===================================================================================================================================
</TABLE>
23
<PAGE> 15
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Millions of dollars)
UGI CORPORATION AND SUBSIDIARIES
<TABLE>
<CAPTION>
Year Ended
September 30,
--------------------------------------------------
1996 1995 1994
=================================================================================================================================
<S> <C>
CASH FLOWS Net income (loss) $ 39.5 $ (8.4) $ 45.0
FROM Reconcile to net cash provided by operating activities:
OPERATING Depreciation and amortization 86.0 60.9 41.8
ACTIVITIES Minority interest in AmeriGas Partners 4.3 (19.7) -
Deferred income taxes, net 12.0 5.1 (6.6)
Extraordinary loss - 13.2 -
Change in accounting - 3.1 -
Equity in Petrolane - 5.3 1.0
Income from discontinued operations - - (7.6)
Other, net (3.5) 7.4 4.7
---------------------------------------------------------------------------------------------------------------
138.3 66.9 78.3
Net change in:
Receivables and accrued utility revenues (37.1) 7.1 (15.0)
Inventories (10.2) (14.3) (4.6)
Deferred fuel adjustments (10.7) (.1) 4.6
Pipeline transition recoveries (costs), net 1.0 1.9 (2.1)
Producer settlement (payments) recoveries, net .1 (9.5) 13.1
Accounts payable 25.1 2.6 (4.0)
Other current assets and liabilities 4.7 22.2 11.2
---------------------------------------------------------------------------------------------------------------
Net cash provided by operating activities 111.2 76.8 81.5
- ---------------------------------------------------------------------------------------------------------------------------------
CASH FLOWS Expenditures for property, plant and equipment (62.7) (68.8) (48.6)
FROM Acquisitions of businesses, net of cash acquired (28.0) (4.1) (4.6)
INVESTING Short-term investments increase (12.1) (11.0) -
ACTIVITIES Investment in Petrolane - - (59.2)
Proceeds from sale of UTI - - 21.6
Other, net 3.9 2.6 3.4
---------------------------------------------------------------------------------------------------------------
Net cash used by investing activities (98.9) (81.3) (87.4)
- ---------------------------------------------------------------------------------------------------------------------------------
CASH FLOWS Dividends on Common Stock (46.4) (45.2) (42.8)
FROM Distributions on Partnership public Common Units (38.7) (7.9) -
FINANCING Issuance of long-term debt 57.1 48.0 -
ACTIVITIES Repayment of long-term debt (59.7) (20.0) (26.8)
Propane bank loans increase 15.0 - -
Utilities bank loans increase 8.5 25.0 17.0
Issuance of UGI Utilities Series Preferred Stock - - 19.9
Redemption of UGI Utilities Series Preferred Stock - - (18.8)
Issuances of Common Stock 11.3 10.1 9.5
Repurchases of Common Stock (7.1) - -
---------------------------------------------------------------------------------------------------------------
Net cash provided (used) by financing activities (60.0) 10.0 (42.0)
- ---------------------------------------------------------------------------------------------------------------------------------
AMERIGAS Acquisition of Petrolane Class B shares,
PARTNERS net of $18.7 of cash acquired - (90.9) -
FORMATION Issuance of AmeriGas Partners Common Units - 349.7 -
TRANSACTIONS Issuance of long-term debt - 208.5 -
Repayment of long-term debt and related interest - (408.9) -
Other fees and expenses - (19.6) -
- ---------------------------------------------------------------------------------------------------------------------------------
Net cash provided by AmeriGas Partners
formation transactions - 38.8
- ---------------------------------------------------------------------------------------------------------------------------------
Cash and cash equivalents increase (decrease) $(47.7) $ 44.3 $ (47.9)
=================================================================================================================================
CASH AND End of period $ 74.0 $ 121.7 $ 77.4
CASH Beginning of period 121.7 77.4 125.3
EQUIVALENTS ---------------------------------------------------------------------------------------------------------------
Increase (decrease) $(47.7) $ 44.3 $ (47.9)
=================================================================================================================================
</TABLE>
The accompanying notes are an integral part of these financial
statements.
24 UGI Corporation 1996 Annual Report
<PAGE> 16
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
(Millions of dollars, except per share amounts)
UGI CORPORATION AND SUBSIDIARIES
<TABLE>
<CAPTION>
UGI Utilities Series
Preferred Stock Retained
Subject to Earnings
Mandatory Common (Accumulated Treasury
Redemption Stock Deficit) Stock
===================================================================================================================================
<S> <C> <C> <C> <C> <C>
YEAR ENDED Balance September 30, 1993 $ 33.2 $366.5 $ 48.1 $ (.1)
SEPTEMBER 30, Net income 45.0
1994 Cash dividends on Common Stock
($1.36 per share) (43.8)
Common Stock issued (note 11):
Employee and director plans .6
Dividend reinvestment plan 8.9
Issuance of UGI Utilities Series
Preferred Stock 20.0 (.1)
Redemption of UGI Utilities Series
Preferred Stock (18.0) (.8)
- -----------------------------------------------------------------------------------------------------------------------------------
YEAR ENDED Balance September 30, 1994 35.2 376.0 48.4 (.1)
SEPTEMBER 30, Net loss (8.4)
1995 Cash dividends on Common Stock
($1.39 per share) (45.5)
Common Stock issued (note 11):
Employee and director plans .8
Dividend reinvestment plan 9.3
- -----------------------------------------------------------------------------------------------------------------------------------
YEAR ENDED Balance September 30, 1995 35.2 386.1 (5.5) (.1)
SEPTEMBER 30, Net income 39.5
1996 Cash dividends on Common Stock
($1.41 per share) (46.7)
Common Stock issued (note 11):
Employee and director plans 3.6 (.1) 3.1
Dividend reinvestment plan 2.2 2.6
Common Stock repurchased (7.1)
- -----------------------------------------------------------------------------------------------------------------------------------
Balance September 30, 1996 $ 35.2 $391.9 $(12.8) $(1.5)
===================================================================================================================================
</TABLE>
The accompanying notes are an integral part of these
financial statements.
25
<PAGE> 17
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Millions of dollars, except per share amounts and where indicated otherwise)
UGI CORPORATION AND SUBSIDIARIES
<TABLE>
<S> <C> <C>
NOTE 1. ORGANIZATION AND SIGNIFICANT
ACCOUNTING POLICIES . . . . . . . . . . . 26
NOTE 2. ACQUISITION OF 100% OF PETROLANE
AND FORMATION OF AMERIGAS
PARTNERS . . . . . . . . . . . . . . . . 28
NOTE 3. INVESTMENT IN PETROLANE . . . . . . . . . 29
NOTE 4. UTILITY REGULATORY MATTERS . . . . . . . 29
NOTE 5. DEBT . . . . . . . . . . . . . . . . . . 30
NOTE 6. INCOME TAXES . . . . . . . . . . . . . . 32
NOTE 7. PENSION PLANS AND OTHER
POSTEMPLOYMENT BENEFITS . . . . . . . . . 33
NOTE 8. INVENTORIES . . . . . . . . . . . . . . . 34
NOTE 9. SERIES PREFERRED STOCK . . . . . . . . . 34
NOTE 10. PREFERENCE STOCK PURCHASE
RIGHTS . . . . . . . . . . . . . . . . . 35
NOTE 11. COMMON STOCK AND INCENTIVE
STOCK AWARD PLANS . . . . . . . . . . . . 35
NOTE 12. COMMITMENTS AND CONTINGENCIES . . . . . . 36
NOTE 13. FINANCIAL INSTRUMENTS . . . . . . . . . . 37
NOTE 14. MISCELLANEOUS INCOME . . . . . . . . . . 38
NOTE 15. SEGMENT INFORMATION . . . . . . . . . . . 38
NOTE 16. DISCONTINUED OPERATIONS . . . . . . . . . 38
NOTE 17. QUARTERLY DATA (UNAUDITED) . . . . . . . 38
</TABLE>
1. ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES
ORGANIZATION. UGI Corporation (UGI) is a holding company with two principal
lines of business. UGI's utility business is conducted through a wholly owned
subsidiary, UGI Utilities, Inc. (UGI Utilities), which owns and operates a
natural gas distribution utility (Gas Utility) in parts of eastern and
southeastern Pennsylvania and an electric utility (Electric Utility) in
northeastern Pennsylvania (together referred to herein as "Utilities").
Commencing with the April 19, 1995 Partnership Formation described below, UGI
conducts a national propane distribution business through AmeriGas Partners,
L.P. (AmeriGas Partners) and its operating subsidiary, AmeriGas Propane, L.P.
(the "Operating Partnership"), both of which are Delaware limited partnerships.
The Operating Partnership is the largest retail propane distributor in the
United States serving residential, commercial, industrial, motor fuel and
agricultural customers from locations in 44 states, including Alaska and
Hawaii. UGI also conducts an energy marketing business principally through its
wholly owned subsidiary, UGI Energy Services, Inc. (UGI Energy Services).
At September 30, 1996, UGI, through wholly owned subsidiaries, held an
effective 2% general partner interest and a 56.7% limited partnership interest
in the Operating Partnership. This limited partner interest is evidenced by
Common Units and Subordinated Units representing limited partner interests in
AmeriGas Partners. The remaining 41.3% effective interest in the Operating
Partnership comprises publicly held Common Units. AmeriGas Partners and the
Operating Partnership are collectively referred to herein as the Partnership.
Although operating income of the Partnership comprised approximately one-half
of UGI's fiscal 1996 consolidated operating income, its impact on consolidated
net income was considerably less due to the Partnership's significant minority
interest, higher relative interest charges and a higher effective income tax
rate.
Prior to the Partnership Formation, UGI's AmeriGas, Inc. subsidiary
(AmeriGas) conducted a national propane distribution business principally
through its wholly owned subsidiaries AmeriGas Propane, Inc. (AmeriGas Propane)
and AmeriGas Propane-2, Inc. (AGP-2) and its equity investee Petrolane
Incorporated (Petrolane). On April 19, 1995, a wholly owned subsidiary of
AmeriGas acquired by merger (the "Petrolane Merger") the approximately 65% of
Petrolane common shares outstanding not already owned by UGI or AmeriGas and
combined the propane distribution businesses of Petrolane, AmeriGas Propane and
AGP-2 (the "Partnership Formation") into the Operating Partnership, which was
formed to acquire these propane businesses and assets. A wholly owned
subsidiary of AmeriGas (the "General Partner") serves as the general partner of
AmeriGas Partners and the Operating Partnership. The Company does not receive
management fees or other compensation in connection with its management of the
Partnership but is reimbursed at cost for all direct and indirect expenses
incurred on behalf of the Partnership, including a portion of UGI employee
compensation and overhead costs.
UGI is exempt from registration as a holding company and is not
otherwise subject to regulation under the Public Utility Holding Company Act of
1935 except for acquisitions under Section 9 (a) (2). UGI is not subject to
regulation by the Pennsylvania Public Utility Commission (PUC).
CONSOLIDATION PRINCIPLES. The consolidated financial statements
include the accounts of UGI and its majority-owned subsidiaries (collectively,
the "Company"). All significant intercompany accounts and transactions have
been eliminated in consolidation. The public unitholders' interest in AmeriGas
Partners is reflected as minority interest in the consolidated statements of
income and balance sheets. The Company's investment in Petrolane through April
19, 1995 was accounted for by the equity method under which the investment was
recorded at cost and adjusted by the Company's share of Petrolane's
undistributed income or loss. The Company's consolidated propane operations are
hereinafter referred to as Propane.
USE OF ESTIMATES. The preparation of financial statements in
conformity with generally accepted accounting principles requires management to
make estimates and assumptions that affect the reported amounts of assets and
liabilities, the disclosure of contingent assets and liabilities at the date of
the financial statements, and revenues and expenses during the reporting
period. Actual results could differ from these estimates.
REGULATED UTILITY OPERATIONS. Gas Utility and Electric Utility are
subject to regulation by the PUC. Gas Utility and Electric Utility account for
their regulated operations in accordance with Statement of Financial Accounting
Standards (SFAS) No. 71, "Accounting for the Effects of Certain Types of
Regulation" (SFAS 71), as amended and supplemented by subsequently issued
standards. SFAS 71, as amended and supplemented, requires, among other things,
that financial statements of a regulated enterprise reflect the actions of
regulators, where appropriate. The economic effects of regulation can result in
regulated enterprises recording costs that have been or are expected to be
allowed in the ratesetting process in a period different from the period in
which the costs would be charged to expense by an unregulated enterprise. When
this occurs, costs are deferred
26 UGI Corporation 1996 Annual Report
<PAGE> 18
as assets in the balance sheet (regulatory assets) and recorded as expenses as
those amounts are reflected in rates. Additionally, regulators can impose
liabilities upon a regulated enterprise for amounts previously collected from
customers and for recovery of costs that are expected to be incurred in the
future (regulatory liabilities). The Company continually monitors the
regulatory and competitive environments in which it operates to determine that
its regulatory assets are probable of recovery.
CONSOLIDATED STATEMENTS OF CASH FLOWS. Cash equivalents include all
highly liquid investments with maturities of three months or less when
purchased and are recorded at cost plus accrued interest which approximates
market value.
Interest paid during 1996, 1995 and 1994 was $79.8 million, $39.4
million and $44.3 million, respectively. Income taxes paid during 1996, 1995
and 1994 were $20.3 million, $22.0 million and $33.1 million, respectively. On
April 19, 1995, the Company acquired the approximately 65% of Petrolane common
shares it did not already own for $109.6 million which was financed with the
proceeds of a private placement of $110 million of First Mortgage Notes of the
Operating Partnership. In conjunction with this acquisition, proportionate
liabilities in the amount of $535.1 million were assumed.
REVENUE RECOGNITION. Revenues from the sale of propane are recognized
principally as product is shipped or delivered to customers. Utilities'
revenues are recorded for service provided to the end of each month but not
yet billed. Rate increases or decreases are reflected in revenues from
effective dates permitted by the PUC. Subsequent to July 31, 1995, the
Company's energy marketing business is conducted by UGI Energy Services which
records separately the revenues and related cost of sales associated with its
billed volumes. Prior to August 1, 1995, net margin from energy marketing
activities, which were conducted by a subsidiary of UGI Utilities, were
reflected as miscellaneous income.
INVENTORIES. Inventories are stated at the lower of cost or market.
Cost is determined principally on an average or first-in, first-out (FIFO)
method except for appliances for which the specific identification method is
used.
INCOME TAXES. AmeriGas Partners and the Operating Partnership are not
directly subject to federal and state income taxes. Instead, their taxable
income or loss is allocated to the individual partners, including the Company.
The Operating Partnership does, however, have certain subsidiaries which
operate in corporate form and are subject to federal and state income taxes.
Deferred income tax provisions of UGI Utilities resulting from the use
of accelerated depreciation methods are recorded in the Consolidated Statements
of Income based upon amounts recognized for ratemaking purposes. UGI Utilities
also recognizes a deferred tax liability for tax benefits that are flowed
through to ratepayers when temporary differences originate and establishes a
corresponding regulatory asset (regulatory income tax asset) for the probable
increase in future revenues that will result when the temporary differences
reverse.
Investment tax credits related to UGI Utilities' plant additions have
been deferred and are being amortized over the service lives of the related
property. UGI Utilities reduces its deferred tax liability for the future tax
benefits that will occur when the deferred investment tax credits, which are
not taxable, are amortized, and also reduces the regulatory asset for the
probable reduction in future revenues that will result when such deferred
investment tax credits amortize.
EARNINGS (LOSS) PER COMMON SHARE. Primary earnings (loss) per common
share are computed by dividing net income (loss) by the weighted average number
of common and dilutive common equivalent shares outstanding during each period.
Common equivalent shares included in the computations represent shares issuable
upon assumed exercise of stock options. Shares used in the earnings (loss) per
common share computations were 33,142,000, 32,710,000 and 32,274,000 for 1996,
1995 and 1994, respectively. Fully diluted earnings (loss) per share are not
materially different from primary earnings (loss) per share and therefore are
not presented.
PROPERTY, PLANT AND EQUIPMENT AND RELATED DEPRECIATION. Property,
plant and equipment is stated at cost. Amounts assigned to property, plant and
equipment of acquired businesses are based upon estimated fair value at date of
acquisition. The original cost of UGI Utilities' retired plant, together with
the net cost of removal, is charged to accumulated depreciation for financial
accounting purposes. Removal costs of UGI Utilities' plant and equipment are
deducted currently for income tax purposes. When plant and equipment other than
UGI Utilities' plant and equipment are retired or otherwise disposed of, the
cost and accumulated depreciation are removed from the accounts and any gains
or losses are reflected in current operations.
Depreciation of Utilities' plant and equipment is computed using the
straight-line method over the estimated average remaining lives of the various
classes of depreciable property. Depreciation as a percentage of the related
average depreciable base for 1996, 1995 and 1994 was 2.9%, 2.8% and 2.8%; and
3.6%, 3.4% and 3.4%, for Gas Utility and Electric Utility, respectively.
Depreciation of Propane plant and equipment is computed using the straight-line
method over estimated service lives ranging from two to 40 years. Depreciation
expense during 1996, 1995 and 1994 was $59.4 million, $43.1 million and $31.9
million, respectively.
INTANGIBLE ASSETS. Intangible assets comprise the following at
September 30:
<TABLE>
<CAPTION>
- --------------------------------------------------------------------------------
1996 1995
================================================================================
<S> <C> <C>
Goodwill (less accumulated amortization of
$64.1 million and $48.6 million, respectively) $546.2 $586.2
Excess reorganization value (less accumulated
amortization of $27.4 million and $18.9 million,
respectively) 143.4 152.0
Other, principally noncompete agreements
(less accumulated amortization of $3.4 million
and $6.8 million, respectively) 2.9 2.5
- --------------------------------------------------------------------------------
Total intangible assets $692.5 $740.7
- --------------------------------------------------------------------------------
</TABLE>
Goodwill recognized as a result of business combinations accounted for
as purchases (including goodwill resulting from the Petrolane Merger) is being
amortized on a straight-line basis over 40 years. Excess reorganization value
(which represents reorganization value in excess of amounts allocable to
identifiable assets of Petrolane resulting from Petrolane's July 15, 1993
reorganization under Chapter 11 of the United States Bankruptcy Code) is being
amortized on a straight-line basis over the 20-year period commencing July 15,
1993. Other intangible assets, consisting principally of covenants not to
compete, are being amortized over the estimated periods of benefit which do not
exceed ten years. Amortization expense of intangible assets during 1996, 1995
and 1994 was $24.6 million, $16.1 million and $8.3 million, respectively.
RECOVERABILITY OF LONG-LIVED ASSETS. The Company adopted SFAS No. 121,
"Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets
to Be Disposed Of" (SFAS 121) in 1996. SFAS 121 establishes accounting
standards for the impairment of long-lived assets, certain identifiable
intangibles, and goodwill related to those assets to be held and used and for
long-lived assets and certain identifiable intangibles to be disposed of.
27
<PAGE> 19
The Company evaluates the impairment of long-lived assets to be held
and used, including associated intangibles, whenever events or changes in
circumstances indicate that the carrying amount of such assets may not be
recoverable. Under SFAS 121, such assets are grouped and evaluated for
impairment at the lowest level for which there are identifiable cash flows that
are largely independent of the cash flows of other groups of assets. Under the
Company's prior policy for determining the recoverability of long-lived assets,
the aggregation of cash flows and the related test for impairment were
performed on a business enterprise or acquisition-level basis. If an asset is
determined to be impaired, the loss is measured as the amount by which the
carrying amount of the asset exceeds its fair value. The test for impairment is
performed by comparing estimated net future cash flows expected to result from
the use of such assets and their eventual disposition to their carrying amount.
The adoption of SFAS 121 did not impact the Company's 1996 results of
operations or financial condition.
OTHER ASSETS. Included in other assets at September 30, 1996 and 1995
are net deferred financing costs of $15.0 million and $16.3 million,
respectively. These costs are being amortized, using the interest method, over
the term of the related debt.
DEFERRED FUEL ADJUSTMENTS. Utilities' tariffs contain clauses which
permit recovery of certain gas, fuel and purchased power costs in excess of the
level of such costs included in base rates. The clauses provide for a periodic
adjustment for any difference between the total amount collected under each
clause and the recoverable costs incurred. Accordingly, Utilities defer the
difference between amounts recognized in revenues and the applicable gas, fuel
and purchased power costs incurred until subsequently billed or refunded to
customers.
2. ACQUISITION OF 100% OF PETROLANE AND FORMATION OF AMERIGAS PARTNERS
On April 19, 1995, immediately after the Petrolane Merger, the Company combined
the propane distribution businesses of Petrolane, AmeriGas Propane and AGP-2
into the Operating Partnership. On April 19, 1995 and May 17, 1995, as part of
an initial public offering (IPO), AmeriGas Partners sold a total of 17,602,000
Common Units at a price to the public of $21.25 a unit. AmeriGas Partners'
capital consists of 21,949,272 Common Units and 19,782,146 Subordinated Units
representing limited partner interests, and a 1% general partner interest. The
Company owns 4,347,272 Common Units, all 19,782,146 Subordinated Units, and an
aggregate 2% general partner interest in the Partnership.
Under the terms of the Petrolane Merger approved by Petrolane's Class
B Common Stock (Class B Stock) shareholders (other than UGI) on April 12, 1995,
the 6,850,562 shares of Petrolane's Class B Stock not held by UGI were
converted into the right to receive $16 per share in cash and all other rights
associated with such shares expired. The Petrolane Merger consideration of
approximately $109.6 million was financed with the proceeds of a private
placement of $110 million of First Mortgage Notes of the Operating Partnership.
The net proceeds of approximately $307.0 million from the sale on
April 19, 1995 of 15,452,000 Common Units and the net proceeds from the
issuance of $100 million face value of AmeriGas Partners' Senior Notes, along
with existing cash balances of AmeriGas Propane and Petrolane, were used to
repay Petrolane's revolving credit loan, term loans and accrued interest and
fees which were assumed by the Operating Partnership. In addition, certain
senior indebtedness of Petrolane and AmeriGas Propane with a combined face
value of $408 million was assumed by the Operating Partnership and immediately
exchanged for First Mortgage Notes. As a result of this exchange, in April 1995
the Company recorded an extraordinary loss of $21.8 million pre-tax ($13.2
million after-tax). In addition, the Company expensed $5.9 million of net
deferred tax benefits of AmeriGas Propane and $5.8 million of net deferred tax
benefits of Petrolane (which amount is reflected in "Equity in Petrolane" in
the 1995 Consolidated Statement of Income) representing the Company's share of
such tax benefits no longer realizable by the Company as a result of the sale
of Common Units to the public. The write-off of tax benefits reduced 1995
income from continuing operations by $11.7 million or $.36 per share.
The Partnership makes distributions to its partners with respect to
each fiscal quarter of the Partnership in an aggregate amount equal to its
Available Cash for such quarter. Available Cash generally means, with respect
to any fiscal quarter of the Partnership, all cash on hand at the end of such
quarter plus all additional cash on hand as of the date of determination
resulting from borrowings subsequent to the end of such quarter less the amount
of cash reserves established by the General Partner in its reasonable
discretion for future cash requirements. These reserves may be retained for the
proper conduct of the Partnership's business and for distributions during the
next four quarters. In addition, reserves for the payment of debt principal and
interest are required under the provisions of certain of the Partnership's debt
agreements.
Distributions by the Partnership in an amount equal to 100% of its
Available Cash will generally be made 98% to the Common and Subordinated
unitholders, including such units held by the Company, and 2% to the General
Partner, subject to the payment of incentive distributions in the event
Available Cash exceeds the Minimum Quarterly Distribution (MQD) of $.55 on all
units. To the extent there is sufficient Available Cash, the holders of Common
Units have the right to receive the MQD, plus any arrearages, prior to the
distribution of Available Cash to holders of Subordinated Units. Common Units
will not accrue arrearages for any quarter after the Subordination Period (as
defined below) and Subordinated Units will not accrue any arrearages with
respect to distributions for any quarter. The Partnership makes distributions
of its Available Cash approximately 45 days after the end of each fiscal
quarter.
The Subordination Period will generally extend until the first day of
any quarter beginning on or after April 1, 2000 in respect of which (a)
distributions of Available Cash from Operating Surplus (generally defined as
$40 million plus $42.9 million of cash on hand as of April 19, 1995 plus all
operating cash receipts less all operating cash expenditures and cash reserves)
equal or exceed the MQD on each of the outstanding Common and Subordinated
units for each of the four consecutive four-quarter periods immediately
preceding such date; (b) the Adjusted Operating Surplus (generally defined as
Operating Surplus adjusted to exclude working capital borrowings, reductions in
cash reserves and $40 million plus $42.9 million of cash on hand as of April
19, 1995 and to include increases in reserves to provide for distributions
resulting from Operating Surplus generated during such period) generated during
both (i) each of the two immediately preceding four-quarter periods and (ii)
the immediately preceding sixteen-quarter period, equals or exceeds the MQD on
each of the Common and Subordinated units outstanding during those periods; and
(c) there are no arrearages on the Common Units.
Prior to the end of the Subordination Period but not prior to March
31, 1998, 4,945,537 Subordinated Units will convert into Common Units for any
quarter ending on or after March 31, 1998, and an additional 4,945,537
Subordinated Units will convert into Common Units for any quarter ending on or
after March 31, 1999, if (a) distributions of Available Cash from Operating
Surplus on each of the outstanding Common and Subordinated units equal or
exceed the MQD for each of the three consecutive four-quarter periods
immediately preceding such date; (b) the Adjusted Operating Surplus generated
during the immediately preceding twelve-quarter period equals or exceeds the
MQD on all of the Common and Subordinated units outstanding during that period;
(c) the General Partner makes a good faith determination that the Partnership
will, with respect to the four-quarter period commencing with such date,
generate Adjusted
28 UGI Corporation 1996 Annual Report
<PAGE> 20
Operating Surplus in an amount equal to or exceeding the MQD on all of the
outstanding Common and Subordinated units; and (d) there are no arrearages on
the Common Units.
The following unaudited pro forma condensed consolidated financial
information of the Company for 1995 and 1994 was derived from the historical
financial information of the Company and Petrolane and was prepared to reflect
the effects of the Petrolane Merger (which merger is treated as a purchase
acquisition by the Company in the form of a treasury stock acquisition by
Petrolane) and the Partnership Formation as if these transactions had taken
place at the beginning of the periods presented. The following unaudited pro
forma condensed consolidated financial information does not purport to present
the results of operations of the Company had the transactions described above
actually been completed as of the beginning of the periods presented nor does
it necessarily indicate results to be expected in the future.
<TABLE>
<CAPTION>
- ---------------------------------------------------------------
1995 1994
===============================================================
(Unaudited)
<S> <C> <C>
Revenues $1,244.5 $1,344.2
Cost of sales (636.7) (693.7)
Depreciation and amortization (84.4) (81.1)
Other costs and expenses (400.0) (389.9)
- ---------------------------------------------------------------
Operating income 123.4 179.5
Interest expense (80.3) (78.2)
Minority interest in AmeriGas Partners (.3) (24.1)
Income taxes (19.5) (37.1)
Dividends on UGI Utilities Series
Preferred Stock (2.8) (1.3)
- ---------------------------------------------------------------
Income from continuing operations $ 20.5 $ 38.8
- ---------------------------------------------------------------
Earnings per share from
continuing operations $ .63 $ 1.20
- ---------------------------------------------------------------
</TABLE>
Significant pro forma adjustments reflected in the data above include
(a) the consolidation of the operations of Petrolane for periods prior to April
19, 1995 and the elimination of intercompany revenues and expenses; (b) a net
reduction in amortization expense resulting from the longer-term (40-year)
amortization of the excess purchase price over fair value of 65% of the net
identifiable assets of Petrolane, compared with the amortization of 65% of
Petrolane's excess reorganization value over 20 years; (c) an adjustment to
interest expense resulting from the retirement of approximately $377 million of
Petrolane term loans, the restructuring of Petrolane and AmeriGas Propane
senior debt, and the issuance of an aggregate $210 million face value of notes
of AmeriGas Partners and the Operating Partnership; (d) an adjustment to income
taxes to reflect income taxes on the Company's share of the Partnership's
taxable income; and (e) an adjustment to reflect the public unitholders'
interest in the results of the Partnership as minority interest.
3. INVESTMENT IN PETROLANE
The following table includes summarized condensed consolidated financial
information of Petrolane from September 24, 1993 through April 19, 1995:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------
September 24, 1994 Year Ended
to April 19, September 23,
1995 1994
===============================================================
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS DATA
<S> <C> <C>
Revenues $ 372.1 $ 589.7
Cost of sales (203.2) (319.0)
Depreciation and amortization (27.4) (46.0)
Other costs and expenses (100.0) (167.8)
- ---------------------------------------------------------------
Operating income 41.5 56.9
Interest expense (30.0) (45.8)
Income taxes (10.1) (13.4)
- ---------------------------------------------------------------
Income (loss) before change
in accounting 1.4 (2.3)
Change in accounting for
postemployment benefits (.9) -
- ---------------------------------------------------------------
Net income (loss) $ .5 $ (2.3)
- ---------------------------------------------------------------
</TABLE>
Prior to the Partnership Formation, AmeriGas Propane and Petrolane
were parties to a customer services agreement (Customer Services Agreement)
pursuant to which AmeriGas Propane served customers of closed Petrolane
districts and Petrolane served customers of closed AmeriGas Propane districts.
These districts were closed in order to achieve cost reductions and operational
efficiencies in overlapping geographical markets served by AmeriGas Propane and
Petrolane. The Customer Services Agreement terminated on April 19, 1995. Fees
billed by Petrolane to AmeriGas Propane under the Customer Services Agreement
totaled $6.9 million and $9.1 million in 1995 and 1994, respectively, and are
included in operating and administrative expenses. Fees billed to Petrolane
totaled $5.3 million and $7.7 million in 1995 and 1994, respectively, and are
included in Petrolane fee income.
Prior to the Partnership Formation, UGI provided Petrolane with
certain financial, accounting, human resources, risk management, insurance,
legal, corporate communications, investor relations, treasury and corporate
development services. For such services, UGI received quarterly fees from
Petrolane. During 1995 and 1994, UGI recorded management fee income of $6.8
million and $11.7 million, respectively, which amounts are included in
Petrolane fee income.
Prior to the Partnership Formation, AmeriGas Management Company (AMC)
and AmeriGas Transportation Management Company (ATMC), first-tier subsidiaries
of UGI, provided general management, supervisory, administrative and
transportation services to Petrolane, AmeriGas Propane and AGP-2. For such
services, AMC and ATMC each received monthly fees from Petrolane in amounts
which, together with fees received from AmeriGas Propane and AGP-2, effectively
reimbursed AMC and ATMC for costs incurred to provide such services. During
1995 and 1994, the Company recorded fee income under these agreements of $8.4
million and $13.9 million, respectively, which amounts are included in
Petrolane fee income.
4. UTILITY REGULATORY MATTERS
GAS UTILITY RATE CASE. On January 27, 1995, Gas Utility filed with the PUC for
a $41.3 million increase in base rates to be effective March 28, 1995. In
accordance with normal PUC practice, the effective date was suspended pending
further investigation. On August 31, 1995, the PUC approved a settlement of
this proceeding (Gas Utility Base Rate Settlement) authorizing a $19.5 million
increase in annual revenues. The increase in base rates became effective on
August 31, 1995. Under the terms of the Gas Utility Base Rate Settlement, Gas
Utility agreed not to file for another base rate increase before January 25,
1997.
29
<PAGE> 21
ELECTRIC UTILITY RATE CASES. On January 26, 1996, Electric Utility
filed with the PUC for a $6.2 million increase in base rates. On July 18, 1996,
the PUC approved a settlement of this proceeding authorizing a $3.1 million
increase in annual revenues, effective July 19, 1996. Under the terms of the
settlement, Electric Utility agreed not to file for another base rate increase
before July 1, 1997. On November 1, 1993, Electric Utility filed with the PUC
for a $4.2 million increase in base rates. On July 27, 1994, the PUC granted
Electric Utility a $1.3 million increase in annual revenues effective on that
date.
PRODUCER SETTLEMENT LIABILITIES. On April 21, 1994, Gas Utility
received approximately $16.4 million in producer settlement refunds (including
approximately $4.3 million in interest) from Columbia Gas Transmission
Corporation (Columbia). On April 15, 1994, in anticipation of this refund, Gas
Utility filed a tariff supplement with the PUC which proposed to refund $11.6
million of the Columbia refund to Gas Utility customers. This amount
represented 90% of the noninterest portion of the Columbia refund, and
approximately $1.8 million of similar refunds previously received by Gas
Utility. Gas Utility proposed to retain, however, the entire interest component
of the Columbia refund to reflect the carrying costs incurred by Gas Utility
when it paid producer settlement liability charges prior to receiving recovery
of such charges from its customers, and to recover legal costs associated with
the recovery of the refunds. On June 2, 1994, the PUC directed Gas Utility to
refund 90% of the principal and interest associated with the producer
settlement refunds less approximately $.5 million for reimbursement of
associated legal costs. In June 1994, Gas Utility recorded income of $2.3
million pre-tax ($1.3 million after-tax) representing the retained portion of
the producer settlement refunds.
Gas Utility and the Pennsylvania Office of Consumer Advocate (OCA)
subsequently filed complaints with the PUC challenging the June 2, 1994
decision. On February 27, 1995, the PUC issued a final Order reaffirming its
June 2, 1994 decision, but permitted Gas Utility to retain $.8 million of the
producer settlement refund for reimbursement of associated legal costs.
Gas Utility and the OCA appealed this decision to the Commonwealth
Court of Pennsylvania (Commonwealth Court), which affirmed the February 27,
1995 PUC final Order in its entirety. Neither Gas Utility nor the OCA appealed
the Commonwealth Court's decision.
REGULATORY ASSETS (LIABILITIES). The following regulatory assets
(liabilities) are included in the accompanying balance sheets at September 30:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------
1996 1995
=================================================================================
<S> <C> <C>
Regulatory income tax asset $42.9 $36.9
Pipeline transition costs (recoveries) (.5) .5
Other postretirement benefits 4.3 4.4
Refundable state taxes (4.2) (5.2)
Deferred fuel costs (recoveries) 1.1 (9.7)
Refundable producer settlement costs (5.4) (5.3)
Deferred environmental costs .7 -
- ---------------------------------------------------------------------------------
$38.9 $21.6
- ---------------------------------------------------------------------------------
</TABLE>
5. DEBT
Long-term debt comprises the following at September 30:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------
1996 1995
=================================================================================
<S> <C> <C>
Propane:
First Mortgage Notes:
Series A, 9.34%-11.71%, due April 2000
through April 2009 (including unamortized
premium of $16.0 and $17.0, respectively,
calculated at an 8.91% effective rate) $224.0 $225.0
Series B, 10.07%, due April 2001 through
April 2005 (including unamortized premium
of $13.1 and $14.6, respectively, calculated
at an 8.74% effective rate) 213.1 214.6
Series C, 8.83%, due April 2003
through April 2010 110.0 110.0
AmeriGas Partners Senior Notes, 10.125%,
due April 2007 100.0 100.0
Acquisition Facility 30.0 --
Special Purpose Facility 7.0 --
Other 8.4 8.9
- ---------------------------------------------------------------------------------
Total Propane 692.5 658.5
- ---------------------------------------------------------------------------------
Utilities:
First Mortgage Bonds:
7.85% Series due November 1996 8.4 8.6
9% Series due June 2019 (less unamortized
discount of $.8) -- 22.0
9% Series B due June 2019 (less unamortized
discount of $.8) -- 22.2
- ---------------------------------------------------------------------------------
8.4 52.8
Other long-term debt:
7.37% Medium-Term Notes, due October 2015 22.0 22.0
6.73% Medium-Term Notes, due October 2002 26.0 26.0
6.62% Medium-Term Notes, due May 2005 20.0 --
6.50% Senior Notes, due August 2003 (less
unamortized discount of $.2) 49.8 49.8
8.70% Notes, due March 1997 and
1998 in annual installments of $10.0 20.0 20.0
9.71% Notes, due through September 2000
in annual installments of $7.1 28.6 35.7
- ---------------------------------------------------------------------------------
Total Utilities 174.8 206.3
- ---------------------------------------------------------------------------------
Other:
7.83% Senior Secured Notes,
due through March 2008 9.0 9.3
- ---------------------------------------------------------------------------------
Total long-term debt 876.3 874.1
Current maturities included in current
liabilities:
Propane (5.2) (5.4)
Utilities (25.5) (53.2)
Other (.4) (.3)
Long-term debt due after one year:
Propane 687.3 653.1
Utilities 149.3 153.1
Other 8.6 9.0
- ---------------------------------------------------------------------------------
Total long-term debt due after one year $845.2 $815.2
- ---------------------------------------------------------------------------------
</TABLE>
Long-term debt maturities and mandatory sinking fund requirements
during the fiscal years 1997 to 2001 follow:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------
1997 1998 1999 2000 2001
================================================================
<S> <C> <C> <C> <C> <C>
Propane $ 5.2 $11.8 $11.3 $27.6 $68.2
Utilities 25.5 17.1 7.1 7.1 -
Other .4 .4 .4 .4 .5
- ----------------------------------------------------------------
Total $31.1 $29.3 $18.8 $35.1 $68.7
- ----------------------------------------------------------------
</TABLE>
30 UGI Corporation 1996 Annual Report
<PAGE> 22
PROPANE. The Operating Partnership's obligations under the First
Mortgage Notes are collateralized by substantially all of the assets of the
Operating Partnership. The General Partner and Petrolane are co-obligors of the
First Mortgage Notes. The Operating Partnership may, at its option, and under
certain circumstances following the disposition of assets be required to, offer
to prepay the First Mortgage Notes, in whole or in part. Certain of these
prepayments will be at a premium. The First Mortgage Note Agreement contains
restrictive covenants applicable to the Operating Partnership, including (a)
restrictions on the incurrence of additional indebtedness; (b) restrictions on
the ratio of each of the Operating Partnership's and the General Partner's
total debt to consolidated gross worth, as defined; and (c) restrictions on
certain liens, guarantees, loans and advances, payments, mergers,
consolidations, sales of assets and other transactions. Generally, as long as
no default exists or would result, the Operating Partnership is 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.
The 10.125% Senior Notes of AmeriGas Partners contain covenants which
restrict the ability of the Partnership to, among other things, incur
additional indebtedness, incur liens, issue preferred interests, and effect
mergers, consolidations and sales of assets. The Senior Notes are not
redeemable prior to April 15, 2000. Thereafter, AmeriGas Partners has the
option to redeem the Senior Notes, in whole or in part, at a premium. In
addition, AmeriGas Partners may, under certain circumstances following the
disposition of assets, be required to prepay the Senior Notes. Pursuant to the
Indenture under which the Senior Notes were issued, AmeriGas Partners is
generally permitted to make cash distributions in an amount equal to available
cash, as defined, as of the end of the immediately preceding quarter, as long
as no event of default exists or would exist upon making such distributions and
if the Partnership's consolidated fixed charge coverage ratio, as defined, is
at least 1.75-to-1. If such ratio is not met, cash distributions may be made in
an aggregate amount not to exceed $24 million less the aggregate of all
distributions made during the immediately preceding 16 fiscal quarters. At
September 30, 1996, such ratio was 2.19-to-1.
The Operating Partnership has Bank Credit Facilities with a group of
commercial banks. The Bank Credit Facilities consist of a Revolving Credit
Facility, an Acquisition Facility and a Special Purpose Facility, each governed
by the Bank Credit Agreement. The Operating Partnership's obligations under
the Bank Credit Facilities are collateralized by substantially all of its
assets. The General Partner and Petrolane are co-obligors of the Bank Credit
Facilities.
The Revolving Credit Facility provides for borrowings of up to $70
million (including a $35 million sublimit for letters of credit). The Revolving
Credit Facility expires April 12, 1998, but may be extended, upon timely
notice, for additional one-year periods with the consent of the participating
banks representing at least 80% of the commitments thereunder. The Revolving
Credit Facility permits the Operating Partnership to borrow at the Base Rate,
defined as the higher of the Federal Funds Rate plus .50% per annum or the
agent bank's reference rate (6.59% and 8.25%, respectively, at September 30,
1996), or at prevailing one-, two-, three-, or six-month offshore interbank
borrowing rates, plus a margin (.525% per annum as of September 30, 1996). The
applicable margin on such offshore interbank borrowing rates, and the Revolving
Credit Facility commitment fee rate (.275% per annum as of September 30, 1996),
are dependent upon the Operating Partnership's ratio of funded debt to earnings
before interest, income taxes, depreciation and amortization (EBITDA), each as
defined in the Bank Credit Agreement. The Operating Partnership is also
required to pay letter of credit fees on the undrawn amount of outstanding
letters of credit equal to the applicable margin on offshore interbank
borrowings under the Revolving Credit Facility and on the face amount of
outstanding letters of credit equal to .2% per annum. At September 30, 1996,
borrowings under the Revolving Credit Facility totaled $15 million and are
classified as bank loans. There were no borrowings under the Revolving Credit
Facility at September 30, 1995. The weighted-average interest rate on the
Operating Partnership's bank loans outstanding as of September 30, 1996 was
6.00%. Issued outstanding letters of credit under the Revolving Credit Facility
totaled $2.3 million and $16.3 million at September 30, 1996 and 1995,
respectively.
The Acquisition Facility provides the Operating Partnership with the
ability to borrow up to $75 million to finance propane business acquisitions.
The Acquisition Facility operates as a revolving facility through October 12,
1997 at which time any amount then outstanding will convert to a quarterly
amortizing 4 1/2-year term loan. The Special Purpose Facility is a $30 million
nonrevolving line of credit which can be used for the payment of certain
liabilities of Petrolane assumed by the Operating Partnership as a result of
the Partnership Formation that relate to potential liabilities for tax,
insurance and environmental matters. The Special Purpose Facility expires April
12, 2000 at which time all amounts then outstanding will become immediately due
and payable. Effective October 28, 1996, the Bank Credit Agreement was amended
to include a revolving $15 million sublimit under the Special Purpose Facility
which can be used to fund working capital, capital expenditures, and interest
and distribution payments. This sublimit is scheduled to expire April 12,
1998.
The Acquisition Facility and the Special Purpose Facility permit the
Operating Partnership to borrow at the Base Rate or prevailing one-, two-,
three-, or six-month offshore interbank borrowing rates, plus a margin (.65% as
of September 30, 1996). The applicable margin on such offshore interbank
borrowing rates, and the Acquisition Facility and Special Purpose Facility
commitment fee rate (.35% per annum at September 30, 1996), are dependent upon
the Operating Partnership's ratio of funded debt to EBITDA, as defined. The
weighted-average interest rate on the Operating Partnership's Acquisition and
Special Purpose loans outstanding as of September 30, 1996 was 6.34%.
The Bank Credit Facilities contain restrictive covenants which include
(a) restrictions on the incurrence of additional indebtedness; (b) restrictions
on the ratio of each of the Operating Partnership's and the General Partner's
total debt to consolidated gross worth, as defined; and (c) restrictions on
certain liens, guarantees, loans and advances, payments, mergers,
consolidations, sales of assets and other transactions. They also require that
the Operating Partnership maintain a ratio of EBITDA to interest expense, as
defined, of at least 2.25-to-1 on a rolling four-quarter basis. At September
30, 1996, such ratio was 2.57-to-1. Generally, as long as no default exists or
would result, the Operating Partnership is 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.
Effective October 28, 1996, the Operating Partnership also has a
revolving credit agreement with the General Partner under which it may borrow
up to $20 million to fund working capital, capital expenditures, and interest
and distribution payments. This agreement is coterminous with the Operating
Partnership's Revolving Credit Facility. Borrowings under the General Partner
Facility will be unsecured and subordinated to all senior debt of the
Partnership. Interest rates on borrowings and facility fees will be determined
generally on the same basis as the Revolving Credit Facility's interest rates
and fees. UGI has agreed to contribute on an as needed basis through its
subsidiaries up to $20 million to the General Partner to fund such borrowings.
UTILITIES. On October 16, 1995, UGI Utilities voluntarily redeemed all
of its outstanding 9% Series and 9% Series B First Mortgage Bonds at a
redemption price of 104% of the principal amount plus accrued interest. The
redemption was funded with the proceeds received from the issuance on September
29, 1995 of $22 million of UGI Utilities 7.37%
31
<PAGE> 23
Medium-Term Notes and $26 million of UGI Utilities 6.73% Medium-Term Notes. The
mortgage collateralizing UGI Utilities First Mortgage Bonds constitutes a first
lien on UGI Utilities' plant.
At September 30, 1996, UGI Utilities had revolving credit agreements
with five domestic banks providing for borrowings of up to $67 million under
committed lines and an additional $35 million under uncommitted lines.
Generally, the commitments expire June 30, 1999, but are renewable, upon timely
notice, for additional one-year periods unless the banks elect not to renew.
The agreements provide UGI Utilities with the option to borrow at various
prevailing interest rates, including the prime rate. A commitment fee at an
annual rate of 3/16 of 1% is payable quarterly on the unused available
committed credit lines. At September 30, 1996 and 1995, borrowings under these
agreements totaled $50.5 million and $42 million, respectively, and are
classified as bank loans. The weighted-average interest rates on UGI Utilities'
bank loans at September 30, 1996 and 1995, were 5.9% and 6.4%, respectively.
Certain of UGI Utilities' debt agreements contain limitations with
respect to incurring additional debt, require the maintenance of consolidated
tangible net worth of at least $125 million, and restrict the amount of
payments for investments, redemptions of capital stock, prepayments of
subordinated indebtedness and dividends.
6. INCOME TAXES
The provisions for income taxes consist of the following:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------
1996 1995 1994
===============================================================
<S> <C> <C> <C>
Current:
Federal $16.6 $14.0 $30.4
State 5.0 3.6 9.6
- ---------------------------------------------------------------
21.6 17.6 40.0
Deferred 12.4 5.5 (6.2)
Investment credit amortization (.4) (.4) (.4)
- ---------------------------------------------------------------
$33.6 $22.7 $33.4
- ---------------------------------------------------------------
</TABLE>
A reconciliation from the statutory federal tax rate to the effective
tax rate is as follows:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------
1996 1995 1994
===============================================================
<S> <C> <C> <C>
Statutory federal tax rate 35.0% 35.0% 35.0%
Difference in tax rate due to:
State income taxes, net of
federal benefit 6.6 8.8 7.3
Nondeductible amortization of
goodwill 6.5 9.7 3.4
Adjustment to Utilities
deferred state income taxes - (11.0) -
Adjustment to deferred tax
benefits resulting from
Partnership Formation - 15.3 -
Other, net (3.8) .9 -
- ---------------------------------------------------------------
Effective tax rate 44.3% 58.7% 45.7%
- ---------------------------------------------------------------
</TABLE>
Deferred tax liabilities (assets) comprise the following at September
30:
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------
1996 1995
=========================================================================
<S> <C> <C>
Excess book basis over tax basis of property,
plant and equipment $154.6 $186.0
Regulatory income tax asset 17.8 15.3
Other 9.8 5.7
- -------------------------------------------------------------------------
Gross deferred tax liabilities 182.2 207.0
- -------------------------------------------------------------------------
Self-insured property and casualty liability (8.2) (11.6)
Employee-related benefits (10.6) (11.1)
Premium on long-term debt (6.7) (7.3)
Deferred investment tax credits (4.5) (4.6)
Deferred fuel refunds - (4.0)
Producer settlement liabilities (2.2) (2.2)
Other (19.1) (19.0)
- -------------------------------------------------------------------------
Gross deferred tax assets (51.3) (59.8)
- -------------------------------------------------------------------------
Deferred tax assets valuation allowance .3 .2
- -------------------------------------------------------------------------
Net deferred tax liabilities $131.2 $147.4
- -------------------------------------------------------------------------
</TABLE>
In February 1996, the General Partner completed AmeriGas Partners' and
the Operating Partnership's federal income tax returns for the Partnership's
initial period of operation. As a part of this process, a final determination
was made as to how to allocate the tax basis of certain of the assets
contributed to the Partnership by the General Partner and Petrolane pursuant to
the Partnership Formation. The completion of the allocation process resulted in
reductions in the deferred income tax liabilities of the General Partner and
Petrolane existing at the date of the Partnership Formation which had been
recorded in connection with the Petrolane Merger and the Partnership Formation.
As a result, the Company recorded a $37.0 million reduction in deferred income
tax liabilities and a corresponding reduction in goodwill which adjustments are
reflected in the accompanying Consolidated Balance Sheet at September 30, 1996.
During 1995, UGI Utilities recorded a regulatory income tax asset of
$12.6 million related to $11.3 million of existing deferred state income taxes
expected to be recovered in the future through the ratemaking process. Pursuant
to the Gas Utility Base Rate Settlement, UGI Utilities recorded a regulatory
liability of $5.3 million associated with a five-year flowback to ratepayers of
approximately $4.8 million in previously recovered deferred state income taxes.
The net effect of these adjustments increased 1995 income from continuing
operations by $4.3 million or $.13 per share.
As of September 30, 1996 and 1995, UGI Utilities had recorded
approximately $29.6 million and $26.2 million, respectively, of deferred tax
liabilities pertaining to utility temporary differences, principally a result
of accelerated tax depreciation, the tax benefits of which previously were or
will be flowed through to ratepayers. These deferred tax liabilities have been
reduced by deferred tax assets of $4.5 million and $4.6 million at September
30, 1996 and 1995, respectively, pertaining to utility deferred investment tax
credits. As of September 30, 1996 and 1995, UGI Utilities had recorded a
regulatory income tax asset related to these net deferred taxes of $42.9
million and $36.9 million, respectively, representing future revenues expected
to be recovered through the ratemaking process. This regulatory income tax
asset will be recognized in deferred tax expense as the corresponding temporary
differences reverse and additional income taxes are incurred.
32 UGI Corporation 1996 Annual Report
<PAGE> 24
7. PENSION PLANS AND OTHER
POSTEMPLOYMENT BENEFITS
The Retirement Income Plan for Employees of UGI Utilities, Inc. (UGI Utilities
Plan) is a noncontributory defined benefit pension plan covering substantially
all employees of UGI and UGI Utilities. UGI Utilities Plan's benefits are
generally based on years of service and employee compensation during the last
years of employment.
The components of net pension income for the UGI Utilities Plan
include the following:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------
1996 1995 1994
===============================================================
<S> <C> <C> <C>
Service cost--benefits earned
during the period $ 3.1 $ 2.4 $ 3.0
Interest cost on projected
benefit obligation 10.2 10.0 9.4
Actual return on plan assets (16.3) (28.1) (1.0)
Net amortization and deferral 2.5 15.3 (11.5)
- ---------------------------------------------------------------
Net pension income $ (.5) $ (.4) $ (.1)
- ---------------------------------------------------------------
</TABLE>
The following table sets forth UGI Utilities Plan's actuarial present
value of benefit obligations and funded status at September 30:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------
1996 1995
===============================================================
<S> <C> <C>
Projected benefit obligation:
Vested benefits $(106.9) $(109.7)
Nonvested benefits (5.9) (5.9)
- ---------------------------------------------------------------
Accumulated benefit obligation (112.8) (115.6)
Effect of projected future salary levels (21.4) (22.3)
- ---------------------------------------------------------------
Projected benefit obligation (134.2) (137.9)
Plan assets at fair value 157.3 149.1
- ---------------------------------------------------------------
Excess of plan assets over projected
benefit obligation 23.1 11.2
Unrecognized net (gain) loss (9.6) 2.9
Unrecognized prior service cost 6.7 7.1
Unrecognized transition asset (12.8) (14.4)
- ---------------------------------------------------------------
Prepaid pension cost $ 7.4 $ 6.8
- ---------------------------------------------------------------
</TABLE>
The major actuarial assumptions used in determining UGI Utilities
Plan's funded status as of September 30, 1996, 1995 and 1994, and net pension
income for each of the years then ended, are as follows:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------
1996 1995 1994
=================================================================================
<S> <C> <C> <C>
Funded status at September 30:
Discount rate 8.0 % 7.5% 8.7%
Rate of increase in salary levels 4.75 4.5 5.0
Net pension income for the year:
Discount rate 7.5 8.7 7.0
Rate of increase in salary levels 4.5 5.0 4.5
Expected return on plan assets 9.5 9.5 9.5
- ---------------------------------------------------------------------------------
</TABLE>
UGI Utilities Plan's assets at September 30, 1996 consist principally
of equity and fixed income mutual funds and investment-grade corporate and U.S.
Government obligations.
The Company also has unfunded nonqualified retirement benefit plans
for certain key employees and directors. At September 30, 1996 and 1995, the
projected benefit obligations of these nonqualified plans were not material.
During 1996, 1995 and 1994, the Company recorded expense for these plans of
$1.1 million, $1.2 million and $1.2 million, respectively.
During 1996, 1995 and 1994, substantially all employees of Propane
participated in noncontributory defined contribution pension plans and 401(k)
savings plans. Company contributions to the Propane pension plans represented a
percentage of each covered employee's salary. Participants in the savings plans
could contribute up to 6% of their compensation on a before-tax basis. The
General Partner could, in its sole discretion, match a portion of employees'
contributions to these savings plans. Effective October 1, 1996, the Propane
pension plan was frozen and the plan's assets were merged into the savings
plan. In addition, effective October 1, 1996, the provisions of the savings
plan were changed to provide for, among other things, a dollar-for-dollar match
on participants' contributions up to 5% of eligible compensation. UGI Utilities
sponsors a 401(k) savings plan for eligible employees of UGI Utilities and UGI.
Generally, participants in the UGI Utilities savings plan may contribute up to
a combined 10% of their compensation on a before-tax and after-tax basis. The
Company may, at its discretion, match a portion of participants' contributions
to the UGI Utilities savings plan. The cost of benefits under the Propane
pension plans and the Propane and UGI Utilities savings plans totaled $5.9
million, $5.2 million and $2.6 million in 1996, 1995 and 1994, respectively.
The Company provides postretirement health care benefits to certain
retirees and a limited number of active employees meeting certain age and
service requirements as of January 1, 1989 and also provides limited
postretirement life insurance benefits to substantially all active and retired
employees.
The components of net periodic postretirement benefit cost are as
follows:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------
1996 1995 1994
=================================================================================
<S> <C> <C> <C>
Service cost--benefits earned
during the period $ .1 $ .1 $ .1
Interest cost on accumulated
postretirement benefit obligation 2.2 2.1 2.4
Net amortization and deferral 1.6 1.2 1.7
- ---------------------------------------------------------------------------------
Net periodic postretirement
benefit cost 3.9 3.4 4.2
Decrease (increase) in regulatory asset .3 (1.0) (2.2)
- ---------------------------------------------------------------------------------
Net expense $4.2 $ 2.4 $ 2.0
- ---------------------------------------------------------------------------------
</TABLE>
The following table sets forth the actuarial present value and funded
status of the Company's postretirement health care and life insurance benefit
plans at September 30:
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------
1996 1995
=========================================================================
<S> <C> <C>
Accumulated postretirement benefit obligation:
Retirees $(22.7) $(21.7)
Fully eligible active participants (5.0) (5.1)
Other active participants (1.6) (1.5)
- -------------------------------------------------------------------------
(29.3) (28.3)
Plan assets at fair value 1.9 -
Unrecognized net (gain) loss (4.3) (2.9)
Unrecognized prior service cost 2.2 -
Unrecognized transition obligation 23.1 24.6
- -------------------------------------------------------------------------
Accrued postretirement benefit cost $ (6.4) $ (6.6)
- -------------------------------------------------------------------------
</TABLE>
33
<PAGE> 25
The major actuarial assumptions used in determining the funded status
of the Company's postretirement health care and life insurance benefit plans at
September 30, 1996, 1995 and 1994, and net periodic postretirement benefit
costs for the years then ended, are as follows:
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------
1996 1995 1994
=========================================================================
<S> <C> <C> <C>
Funded status at September 30:
Discount rate 8.0% 7.5% 8.7%
Health care cost trend rate 6.5-5.5 7.0-5.5 10.0-5.5
Net periodic postretirement benefit
cost for the year:
Discount rate 7.5 8.7 7.0
Health care cost trend rate 7.0-5.5 10.0-5.5 12.0-5.5
- -------------------------------------------------------------------------
</TABLE>
The ultimate health care cost trend rate of 5.5% in the table above is
assumed for all years after 2007. Increasing the health care cost trend rate
one percent increases the September 30, 1996 and 1995 accumulated
postretirement benefit obligations by $2.4 million and $2.1 million,
respectively, and increases the net periodic postretirement benefit costs for
1996, 1995 and 1994 by $.2 million, $.1 million and $.2 million, respectively.
UGI Utilities has established an Employee Benefit Trust (VEBA) to pay
retiree health care and life insurance benefits and to fund the UGI Utilities'
postretirement benefit liability. At September 30, 1996, the VEBA balance
totaled $1.9 million and was primarily invested in money market funds.
On June 22, 1993, the PUC entered an order permitting Gas Utility to
record a regulatory asset for the difference between the costs incurred under
SFAS No. 106, "Employers Accounting for Postretirement Benefits Other Than
Pensions" (SFAS 106) and costs incurred on a pay-as-you-go basis. Under the
terms of the order, the regulatory asset resulting from the deferral of SFAS
106 costs was allowable for ratemaking purposes subject to prior review in a
base rate proceeding. As part of the Gas Utility Base Rate Settlement, Gas
Utility was permitted the recovery over 17.25 years of the approximately $4.0
million in deferred excess SFAS 106 costs, comprising principally deferred
transition obligation amortization, for the period January 1, 1993 (the date
Gas Utility adopted SFAS 106) through August 31, 1995. The Gas Utility Base
Rate Settlement, however, reserved the right of any party to challenge the
prospective recovery of these deferred excess SFAS 106 costs in future rate
proceedings. Under the terms of Electric Utility's July 18, 1996 base rate
order, Electric Utility was permitted the recovery of its deferred SFAS 106
transition obligation amortization.
In a proceeding involving an unaffiliated Pennsylvania utility,
Pennsylvania Power & Light Company (PP&L), the Commonwealth Court reversed a
PUC declaratory order outside a full base rate proceeding permitting PP&L to
defer excess SFAS 106 costs pending its next base rate order. PP&L and the PUC
appealed the Commonwealth Court decision to the Pennsylvania Supreme Court
which, on March 12, 1996, declined to review the matter. The Company will
continue to monitor administrative and judicial proceedings involving deferred
excess SFAS 106 costs and recognizes that, based on applicable law, it is
possible that in future base rate proceedings Utilities could prospectively be
denied recovery of some or all of its deferred excess SFAS 106 costs.
Also as part of the Gas Utility Base Rate Settlement, Gas Utility was
permitted to recover in its rates approximately $2.4 million in ongoing annual
costs incurred under the provisions of SFAS 106. Gas Utility is required to
defer the difference between the amount of SFAS 106 costs included in rates and
the actuarially determined annual SFAS 106 costs for recovery or refund to
ratepayers in future rate proceedings. The ultimate recovery of SFAS 106 costs
in excess of pay-as-you-go costs was subject to the outcome of a legal
challenge brought by the OCA against an unaffiliated Pennsylvania utility,
Pennsylvania-American Water Company (PAWC). In Irwin Popowsky v. PA P.U.C.
(1994), the Commonwealth Court rejected the claim of the OCA that principles of
ratemaking prohibit the PUC from permitting PAWC to recover excess SFAS 106
costs. The OCA filed a petition for allowance of appeal with the Pennsylvania
Supreme Court with respect to this decision and the Pennsylvania Supreme Court,
on March 12, 1996, denied this petition.
Effective October 1, 1994, the Company adopted the provisions of SFAS
No. 112, "Employers' Accounting for Postemployment Benefits" (SFAS 112). SFAS
112 requires, among other things, the accrual of benefits provided to former or
inactive employees (who are not retirees) and to their beneficiaries and
covered dependents. Prior to the adoption of SFAS 112, the Company accounted
for these postemployment benefits on a pay-as-you-go basis. The cumulative
effect of SFAS 112 on the Company's results of operations for periods prior to
October 1, 1994 of $4.7 million pre-tax ($2.8 million after-tax) has been
reflected in the 1995 Consolidated Statement of Income as "Change in accounting
for postemployment benefits." Petrolane adopted the provisions of SFAS 112
effective September 24, 1994. The Company's equity share of the cumulative
effect of SFAS 112 on Petrolane's results of operations of $.3 million has also
been included in the caption "Change in accounting for postemployment
benefits." The effect of the change in accounting for postemployment benefits
on results of operations for 1995 was not material.
8. INVENTORIES
Inventories comprise the following at September 30:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------
1996 1995
- ----------------------------------------------------------------
<S> <C> <C>
Propane gas $ 61.1 $ 54.4
Utility fuel and gases 26.0 19.0
Materials, supplies and other 18.4 21.1
Appliances for sale 7.7 7.7
- ----------------------------------------------------------------
$113.2 $102.2
- ----------------------------------------------------------------
</TABLE>
9. SERIES PREFERRED STOCK
The UGI Series Preferred Stock, including both series subject to and series not
subject to mandatory redemption, has 5,000,000 shares authorized for issuance.
There were no shares of UGI Series Preferred Stock outstanding at September 30,
1996 or 1995.
UGI Utilities Series Preferred Stock, including both series subject to
and series not subject to mandatory redemption, has 2,000,000 shares authorized
for issuance. The holders of shares of UGI Utilities Series Preferred Stock
have the right to elect a majority of UGI Utilities' Board of Directors
(without cumulative voting) if dividend payments on any series are in arrears
in an amount equal to four quarterly dividends. This election right continues
until the arrearage has been cured. Cash dividends have been paid at the
specified annual rates on all outstanding UGI Utilities Series Preferred Stock.
34 UGI Corporation 1996 Annual Report
<PAGE> 26
UGI Utilities Series Preferred Stock subject to mandatory redemption
comprises the following at September 30:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------
1996 1995
================================================================
<S> <C> <C>
$1.80 Series, stated at involuntary
liquidation value of $23.50 per share,
cumulative (issued and outstanding--
7,963 and 8,583 shares, respectively) $ .2 $ .2
$8.00 Series, stated at involuntary
liquidation value of $100 per share,
cumulative (issued and outstanding--
150,000 shares) 15.0 15.0
$7.75 Series, stated at involuntary
liquidation value of $100 per share,
cumulative (issued and outstanding--
200,000 shares) 20.0 20.0
- ----------------------------------------------------------------
Total UGI Utilities Series Preferred
Stock subject to mandatory redemption $35.2 $35.2
- ----------------------------------------------------------------
</TABLE>
UGI Utilities is required to purchase shares of its $1.80 Series
Preferred Stock tendered at a purchase price of $23.50 per share. After January
1, 1998, UGI Utilities may call any untendered $1.80 Series shares at a
redemption price of $23.50 per share.
UGI Utilities is required to establish a sinking fund to redeem on
April 1 in each year, commencing April 1, 1998, 30,000 shares of its $8.00
Series Preferred Stock at a price of $100 per share. The $8.00 Series is
redeemable, in whole or in part, at the option of UGI Utilities at a price of
$103.56 per share commencing April 2, 1997 decreasing by equal amounts on April
2 of each subsequent year through 2001.
UGI Utilities is required to establish a sinking fund to redeem on
October 1 in each year, commencing October 1, 2004, 10,000 shares of its $7.75
Series Preferred Stock at a price of $100 per share. The $7.75 Series Preferred
Stock is redeemable, in whole or in part, at the option of UGI Utilities on or
after October 1, 2004, at a price of $100 per share. All outstanding shares of
$7.75 Series Preferred Stock are subject to mandatory redemption on October 1,
2009 at a price of $100 per share.
10. PREFERENCE STOCK PURCHASE RIGHTS
Holders of UGI Common Stock own one-half of one right, as further described,
for each outstanding share of Common Stock. As amended on April 17, 1996, each
right entitles the holder to purchase one one-hundredth of a share of First
Series Preference Stock, without par value, at an exercise price of $120 per
one one-hundredth of a share, subject to adjustment or, under the circumstances
summarized below, to purchase the common stock described in the following
paragraph. The rights are exercisable only if a person or group, other than
certain underwriters, acquires 20% or more of the Company's Common Stock
(Acquiring Person) or announces or commences a tender offer for 30% or more of
the Common Stock. The Company is entitled to redeem the rights at five cents
per right at any time before the earlier of the expiration of the rights in
April 2006 or, subject to the concurrence of a majority of continuing
directors, ten days after a person or group has acquired 20% of the Common
Stock and in certain circumstances thereafter.
If an Acquiring Person merges with the Company or engages in certain
other transactions with the Company, or, if a person acquires 40% or more of
the Common Stock, each holder of a right, other than the acquirer, is entitled
to purchase, at the exercise price of the right, Common Stock having a market
value of twice the exercise price of the right. In addition, after the first
date of public announcement by the Company or an Acquiring Person that an
Acquiring Person has become such, if the Company engages in a merger or other
business combination transaction in which the Company is not the surviving
corporation, or in which the Company is the surviving corporation, but in which
its Common Shares are changed or exchanged, or if 50% or more of the Company's
assets or earning power are sold or transferred, each holder of a right is
entitled to purchase, at the exercise price of the right, common stock of the
acquiring company having a market value of twice the exercise price of the
right. The rights have no voting or dividend rights and, until exercisable,
have no dilutive effect on the earnings of the Company.
11. COMMON STOCK AND INCENTIVE STOCK AWARD PLANS
Common Stock share activity for 1994, 1995, and 1996 follows:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------
Issued Treasury Outstanding
===========================================================================
<S> <C> <C> <C>
Balance September 30, 1993 31,942,700 (4,566) 31,938,134
Issued:
Employee and director plans 28,896 200 29,096
Dividend reinvestment plan 426,144 - 426,144
- ---------------------------------------------------------------------------
Balance September 30, 1994 32,397,740 (4,366) 32,393,374
Issued:
Employee and director plans 41,918 - 41,918
Dividend reinvestment plan 482,172 - 482,172
- ---------------------------------------------------------------------------
Balance September 30, 1995 32,921,830 (4,366) 32,917,464
Issued:
Employee and director plans 164,961 143,385 308,346
Dividend reinvestment plan 111,940 120,175 232,115
Reacquired - (321,700) (321,700)
- ---------------------------------------------------------------------------
Balance September 30, 1996 33,198,731 (62,506) 33,136,225
- ---------------------------------------------------------------------------
</TABLE>
Under the 1992 Stock Option and Dividend Equivalent Plan (1992 Plan),
the Company may grant options to acquire shares of Common Stock to key
executives. The number of shares of Common Stock which may be made the subject
of options under the 1992 Plan may not exceed 1,500,000. Upon the completion of
one year of service after the date of grant and on each anniversary of that
date, the options are exercisable in proportion to the number of years expired
after the date of grant within a specified five-year period. Options can be
exercised no later than ten years from the date of grant. The exercise price
for options granted under the 1992 Plan may be more or less than the fair
market value of the Common Stock on the date of grant. The 1992 Plan will
remain in effect until all stock subject to it has been purchased pursuant to
the exercise of options or until the options expire. No options may be granted
after January 1, 2002. At September 30, 1996, 589,041 shares under the 1992
Plan were available for future option grants. In addition, the 1992 Plan
provides for the crediting of dividend equivalents to optionees' accounts
during the specified five-year period. Actual payment of the dividend
equivalents is determined based upon the total return realizable by the
Company's shareholders relative to the performance of comparable companies
during the specified five-year period.
Under the 1992 Directors' Stock Plan (Directors' Plan), an option to
purchase 1,000 shares of Common Stock was granted to each of the Company's
nonemployee Board Directors on each of their election or reelection dates
during the years 1992 to 1996. The exercise price for options granted under the
Directors' Plan is the fair market value of the Common Stock on the date of
grant. Options expire no later than ten years from the date of grant and may,
in certain circumstances, expire earlier. One-fifth of each Director's options
are exercisable for each full year of
35
<PAGE> 27
service as a Director, whether before, at or after the date of grant. In
addition, under certain circumstances, Common Stock may be paid to nonemployee
Directors in lieu of increases in retainer fees during the five-year period
ending December 31, 1996. The number of shares of Common Stock reserved and
available for issuance under the Directors' Plan is 100,000. At September 30,
1996, 60,883 shares of Common Stock were available for future issuance under
the Directors' Plan.
Under the 1992 Non-Qualified Stock Option Plan (1992 Non-Qualified
Plan), the Company may grant options to acquire shares of Common Stock to key
employees who do not participate in the 1992 Plan. The number of shares of
Common Stock which may be made the subject of options under the 1992
Non-Qualified Plan may not exceed 500,000. The exercise price for options
granted under the 1992 Non-Qualified Plan is the fair market value of the
Common Stock on the date of grant. One-fifth of an optionee's options are
exercisable for each full year of service completed after the date of grant.
Options can be exercised no later than ten years from the date of grant. At
September 30, 1996, 272,575 shares of Common Stock were available for future
option grants under the 1992 Non-Qualified Plan.
Stock option transactions under all plans for 1994, 1995 and 1996
follow:
<TABLE>
<CAPTION>
- ------------------------------------------------------------------
Shares Option price per share
==================================================================
<S> <C> <C> <C>
Shares under option--
September 30, 1993 1,110,917 $18.625 to $25.00
- ------------------------------------------------------------------
Granted 72,292 19.00 to 23.50
Exercised (4,600) 18.625 to 22.25
Forfeited (6,075) 20.125
- ------------------------------------------------------------------
Shares under option--
September 30, 1994 1,172,534 18.625 to 25.00
- ------------------------------------------------------------------
Granted 62,667 20.00 to 21.125
Exercised (16,200) 21.00 to 21.375
Forfeited (8,000) 21.125
- ------------------------------------------------------------------
Shares under option--
September 30, 1995 1,211,001 18.625 to 25.00
- ------------------------------------------------------------------
Granted 31,000 20.125 to 22.375
Exercised (274,700) 18.625 to 24.25
Forfeited (90,000) 20.125
- ------------------------------------------------------------------
Shares under option--
September 30, 1996 877,301 18.625 to 25.00
- ------------------------------------------------------------------
</TABLE>
At September 30, 1996, 1995 and 1994, options for 647,868, 677,980 and
448,608 shares, respectively, were exercisable.
12. COMMITMENTS AND CONTINGENCIES
The Company leases various buildings and transportation, data processing and
office equipment under operating leases. Certain of the leases contain renewal
and purchase options and also contain escalation clauses. The aggregate rental
expense for such leases was $27.1 million, $21.9 million and $18.3 million
during 1996, 1995 and 1994, respectively.
Minimum future payments under operating leases having initial or
remaining noncancelable terms in excess of one year are as follows:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------
After
1997 1998 1999 2000 2001 2001
================================================================
<S> <C> <C> <C> <C> <C> <C>
Propane $19.6 $16.0 $13.2 $ 9.9 $7.3 $11.2
Utilities 4.6 3.5 2.8 2.4 2.0 3.6
- ----------------------------------------------------------------
$24.2 $19.5 $16.0 $12.3 $9.3 $14.8
- ----------------------------------------------------------------
</TABLE>
At September 30, 1996, the Partnership had entered into fixed price
propane supply contracts totaling approximately $26.0 million which expire at
various dates through March 1997.
Gas Utility has gas supply agreements with producers and marketers
that expire at various dates through 1999 and has agreements for pipeline
transportation and storage capacity that expire at various dates through 2015
and 2012, respectively. In addition, Gas Utility has short-term gas supply
agreements which permit it to purchase certain of its gas supply needs at spot
prices.
UGI Energy Services has entered into firm contracts to purchase
natural gas to supply the contractual needs of certain of its customers. At
September 30, 1996, the total amount of these firm purchase commitments, which
expire at various dates through December 1997, was approximately $13.6 million.
In addition, UGI Energy Services has entered into contracts to purchase gas at
spot prices to meet the needs of its small firm and interruptible customers.
The Partnership has succeeded to the lease guarantee obligations of
Petrolane relating to Petrolane's divestiture of nonpropane operations prior to
its 1989 acquisition by QFB Partners. These leases are currently estimated to
aggregate approximately $91.0 million (subject to reduction in certain
circumstances). The leases expire through 2010 and some of them are currently
in default, as discussed below. Under certain circumstances such lease
obligations may be reduced by the earnings of such divested operations. The
Partnership has succeeded to the indemnity agreement of Petrolane by which
Texas Eastern Corporation (Texas Eastern), a prior owner of Petrolane, agreed
to indemnify Petrolane against any liabilities arising out of the conduct of
businesses that do not relate to, and are not a part of, the propane business,
including lease guarantees. The Consolidated Balance Sheets at September 30,
1996 and 1995 include current and noncurrent liabilities of $.9 million and
$11.0 million; and $.7 million and $11.0 million, respectively, related to
leases guaranteed by the Partnership and currently in default and equal
corresponding current and noncurrent assets related to Texas Eastern's
indemnification agreement with respect thereto. To date, Texas Eastern has
directly satisfied its obligations without the Partnership's having to honor
its guarantee.
In addition, the Partnership has succeeded to Petrolane's agreement to
indemnify Shell Petroleum N.V. (Shell) for various scheduled claims that were
pending against Tropigas de Puerto Rico (Tropigas). This indemnification
agreement had been entered into by Petrolane in conjunction with Petrolane's
sale of the international operations of Tropigas to Shell in 1989. The
Partnership also succeeded to Petrolane's right to seek indemnity on these
claims first from International Controls Corp., which sold Tropigas to
Petrolane, and then from Texas Eastern. To date, neither the Partnership nor
Petrolane has paid any sums under this indemnity, but several claims by Shell,
including claims related to certain antitrust actions aggregating at least $68
million, remain pending.
The Company, along with other companies, has been named as a
potentially responsible party in several administrative proceedings for the
cleanup of various waste sites, including some Superfund sites. Also, certain
private parties have filed, or threatened to file, suit against the Company to
recover costs of investigation and, as appropriate, remediation of several
36 UGI Corporation 1996 Annual Report
<PAGE> 28
waste sites. In addition, the Company has identified environmental
contamination at several of its properties and has voluntarily undertaken
investigation and, as appropriate, remediation of these sites in cooperation
with appropriate environmental agencies or private parties.
At a manufactured gas plant site in Burlington, Vermont, the United
States Environmental Protection Agency (EPA) has named 19 parties, including
UGI Utilities, as potentially responsible parties for gas plant contamination
that resulted from the operations of a former subsidiary of UGI Utilities. In
May 1993, after receiving and reviewing extensive public comment, EPA withdrew
a proposed plan of remediation that would have cost an estimated $50 million.
EPA is now working with community groups and potentially responsible parties to
develop a revised remediation plan. These groups continue to study the site and
evaluate the effect of the contamination on the environment. UGI Utilities
cannot estimate the cost associated with any revised plan, but it does not
believe such cost will exceed the estimated cost of the originally proposed
plan.
With respect to a manufactured gas plant site in Concord, New
Hampshire, EnergyNorth Natural Gas, Inc. (EnergyNorth) has filed suit against
UGI Utilities alone seeking UGI Utilities' allocable share of response costs
associated with remediating gas plant related contaminants at that site.
EnergyNorth alleges that to date it has spent $3.5 million to remediate part of
the site and that it will be required to spend an unknown amount in the future
to complete remediation.
At Burlington, Concord and other sites, management believes that UGI
Utilities should not have significant liability in those instances in which a
former subsidiary operated a manufactured gas plant because UGI Utilities
generally is not legally liable for the obligations of its subsidiaries. Under
certain circumstances, however, courts have found parent companies liable for
environmental damage caused by subsidiary companies when the parent company
exercised such substantial control over the subsidiary that the court concluded
that the parent company either (i) itself operated the facility causing the
environmental damage or (ii) otherwise so controlled the subsidiary that the
subsidiary's separate corporate form should be disregarded. There could be,
therefore, significant future costs of an uncertain amount associated with
environmental damage caused by manufactured gas plants that UGI Utilities owned
or directly operated, or that were owned or operated by former subsidiaries of
UGI Utilities, if a court were to conclude that the level of control exercised
by UGI Utilities over the subsidiary satisfies the standard described above. In
many circumstances where UGI Utilities may be liable, expenditures may not be
reasonably quantifiable because of a number of factors, including various costs
associated with potential remedial alternatives, the unknown number of other
potentially responsible parties involved and their ability to contribute to the
costs of investigation and remediation, and changing environmental laws and
regulations.
The Company's policy is to accrue environmental investigation and
cleanup costs when it is probable that a liability exists and the amount or
range of amounts is reasonably estimable. The Company intends to pursue
recovery of any incurred costs through all appropriate means, including
regulatory relief, although such recovery cannot be assured. Under the terms of
the Gas Utility Base Rate Settlement, Gas Utility will be permitted to amortize
as removal costs site-specific environmental investigation and remediation
costs, net of related third-party payments, associated with Pennsylvania sites.
Gas Utility will be permitted to include in rates, through future base rate
proceedings, a five-year average of such prudently incurred removal costs.
In addition to these environmental matters, there are various other
pending claims and legal actions arising out of the normal conduct of the
Company's businesses. The final results of environmental and other matters
cannot be predicted with certainty. However, it is reasonably possible that
some of them could be resolved unfavorably to the Company. Management believes,
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 the Company's financial position but could be material to 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.
13. FINANCIAL INSTRUMENTS
The carrying amounts reported in the consolidated balance sheets for cash and
cash equivalents, short-term investments, accounts receivable, accounts payable
and bank loans approximate fair value because of the immediate or short-term
maturity of these financial instruments. The estimated fair values and related
carrying amounts of the Company's long-term debt and UGI Utilities Series
Preferred Stock at September 30 are as follows:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------
Carrying Estimated
Amount Fair Value
================================================================
<S> <C> <C>
1996:
Long-term debt:
Propane $692.5 $720.0
Utilities 174.8 174.0
Other 9.0 9.0
UGI Utilities Series Preferred Stock 35.2 37.0
1995:
Long-term debt:
Propane $658.5 $701.0
Utilities 206.3 213.0
Other 9.3 10.0
UGI Utilities Series Preferred Stock 35.2 36.0
- ----------------------------------------------------------------
</TABLE>
The estimated fair values of long-term debt included in the table
above are based upon current market prices and discounted present value methods
calculated using borrowing rates available for debt with similar credit
ratings, terms and maturities. The estimated fair values of UGI Utilities
Series Preferred Stock are based upon the fair values of redeemable preferred
stock with similar credit ratings and redemption features.
Financial instruments which potentially subject the Company to
concentrations of credit risk consist principally of short-term investments and
trade accounts receivable. The Company invests available cash in
investment-grade commercial paper of industrial and other companies and in
obligations of the U.S. Government. The risk associated with trade accounts
receivable is limited due to the Company's large customer base and its
dispersion across many different U.S. markets. At September 30, 1996 and 1995,
the Company had no significant concentrations of credit risk.
The Partnership from time to time holds certain option contracts to
manage price risk associated with a portion of its anticipated propane
procurement during the heating season. The unrealized gains on such contracts
at September 30, 1996 and 1995 were not material.
37
<PAGE> 29
14. MISCELLANEOUS INCOME
Miscellaneous income comprises the following:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------
1996 1995 1994
================================================================
<S> <C> <C> <C>
Interest income $ 4.0 $ 5.2 $3.4
Gain on sale of fixed assets 1.9 .7 1.8
Gas brokerage income - 1.4 .8
Finance charges 2.2 1.0 .8
Other 4.6 3.1 2.3
- ----------------------------------------------------------------
$12.7 $11.4 $9.1
- ----------------------------------------------------------------
</TABLE>
15. SEGMENT INFORMATION
Reference is made to the schedule on page 20 for information on revenues,
operating income, identifiable assets, depreciation and amortization, and
capital expenditures for the Company's business segments for 1996, 1995 and
1994.
16. DISCONTINUED OPERATIONS
On December 14, 1993, as part of an IPO of UTI Energy Corp. (UTI) Common Stock,
UTI redeemed its preferred stock held by the Company for $14.1 million in cash,
warrants to buy 162,000 shares of UTI Common Stock at the offering price of $8
a share, and a $3.5 million promissory note bearing interest at 5 3/4%. In
addition, as part of the IPO, the Company sold all of its UTI Common Stock,
including shares underlying warrants received in 1986, as well as 140,625
shares received from other UTI shareholders, for $5.1 million and received
preferred stock dividends through the date of redemption of $2.3 million. UTI
is the entity which owns and operates a significant portion of the Company's
former oil field service businesses which were sold to UTI on December 31,
1986. Although the December 31, 1986 transaction was treated as a sale for
legal and income tax purposes, it was not treated as a sale for financial
accounting purposes because the Company had not realized substantial cash
consideration and because the ultimate realization of the sales price was
dependent upon the future operating results of the companies sold. As a result
of the December 14, 1993 transaction described above, the Company recorded the
sale of UTI for financial accounting purposes. The gain from the sale of $7.6
million, which is net of income taxes of $.2 million, has been classified as
discontinued operations in the 1994 Consolidated Statement of Income.
17. QUARTERLY DATA (UNAUDITED)
The following quarterly information includes all adjustments (consisting only
of normal recurring adjustments with the exception of those indicated below)
which the Company considers necessary for a fair presentation of such
information. Quarterly results fluctuate because of the seasonal nature of the
Company's businesses.
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------------------------
December 31, March 31, June 30, September 30,
1995(a) 1994 1996(a)(b) 1995 1996(a) 1995(c) 1996(d) 1995(e)(f)
==============================================================================================================================
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Revenues $426.9 $194.9 $582.6 $258.8 $283.9 $205.6 $264.2 $218.3
Operating income (loss) $ 62.7 $ 32.4 $111.7 $ 56.1 $ 3.8 $ 1.1 $(18.5) $(11.3)
Income (loss) before extraordinary
loss and accounting change $ 18.2 $ 11.0 $ 37.6 $ 27.0 $ (3.7) $(19.5) $(12.6) $(10.6)
Extraordinary loss--
propane debt restructuring - - - - - (13.2) - -
Change in accounting for
postemployment benefits - (3.1) - - - - - -
- ------------------------------------------------------------------------------------------------------------------------------
Net income (loss) $ 18.2 $ 7.9 $ 37.6 $ 27.0 $ (3.7) $(32.7) $(12.6) $(10.6)
- ------------------------------------------------------------------------------------------------------------------------------
Earnings (loss) per common share:
Earnings (loss) before extraordinary
loss and accounting change $ .55 $ .34 $ 1.13 $ .83 $ (.11) $ (.60) $ (.38) $ (.32)
Extraordinary loss--propane
debt restructuring - - - - - (.40) - -
Change in accounting for
postemployment benefits - (.10) - - - - - -
- ------------------------------------------------------------------------------------------------------------------------------
Net earnings (loss) $ .55 $ .24 $ 1.13 $ .83 $ (.11) $(1.00) $ (.38) $ (.32)
- ------------------------------------------------------------------------------------------------------------------------------
</TABLE>
(a) Revenues (and related cost of sales) have been reclassified to reflect
revenues from certain Gas Utility sales on a total, rather than net,
basis.
(b) Includes reductions in operating expenses of $4.4 million from the refund
of insurance premium deposits and $3.3 million from a reduction in
accrued environmental costs which increased net income by $2.7 million or
$.08 per share.
(c) Reflects the write-off of net deferred tax benefits of AmeriGas Propane
and Petrolane representing the Company's share of such tax benefits no
longer realizable as a result of the public unitholders' interest in the
Partnership which increased loss before extraordinary loss and accounting
change by $11.7 million or $.36 per share.
(d) Includes income from adjustments to incentive compensation accruals of
$4.0 million which decreased net loss by $2.1 million or $.06 per share.
(e) Reflects effect of adjustments to Utilities' deferred income taxes which
decreased loss before extraordinary loss and accounting change by $4.3
million or $.13 per share.
(f) Reflects accrual for expenses of Partnership management organizational
changes of $4.3 million which increased net loss by $1.5 million or $.05
per share.
38 UGI Corporation 1996 Annual Report
<PAGE> 30
REPORT OF MANAGEMENT
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
generally accepted accounting principles and include amounts that are based on
management's best judgments and estimates.
The Company maintains a system of internal controls. Management
believes the system provides 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. There are limits in all systems of internal control,
based on the recognition that the cost of the system should not exceed the
benefits to be derived. We believe that the Company's internal control system
is cost effective and provides reasonable assurance that material errors or
irregularities will be prevented or detected within a timely period. The
internal control system and compliance therewith are monitored by the Company's
internal audit staff.
The Audit Committee of the Board of Directors is composed of four
members, none of whom is an employee of the Company. This Committee is
responsible for reviewing the adequacy of corporate financial reporting and
accounting systems and controls, for overseeing the external and internal
auditing functions and for recommending to the Board of Directors the
independent accountants to conduct the annual audit of the Company's
consolidated financial statements. The Committee maintains direct channels of
communication between the Board of Directors and both the independent
accountants and internal auditors.
The independent accountants, who are appointed by the Board of
Directors and ratified by the shareholders, perform certain procedures,
including an evaluation of internal controls to the extent required by
generally accepted auditing standards, in order to express an opinion on the
consolidated financial statements and to obtain reasonable assurance that such
financial statements are free of material misstatement.
/s/ LON R. GREENBERG /s/ CHARLES L. LADNER /s/ MICHAEL J. CUZZOLINA
Lon R. Greenberg Charles L. Ladner Michael J. Cuzzolina
Chief Executive Officer Chief Financial Officer Chief Accounting Officer
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors and Stockholders
UGI Corporation
Valley Forge, Pennsylvania
We have audited the accompanying consolidated balance sheets of UGI Corporation
and subsidiaries as of September 30, 1996 and 1995 and the related consolidated
statements of income, stockholders' equity, and cash flows for the years ended
September 30, 1996, 1995 and 1994. These financial statements are the
responsibility of the Company's management. Our responsibility is to express an
opinion on these financial statements based on our audits. We did not audit the
consolidated financial statements of AmeriGas Propane, Inc. and subsidiaries,
as of September 30, 1996 and 1995 and for the year ended September 30, 1996 and
the period from April 19, 1995 to September 30, 1995, which statements reflect
total assets and revenues constituting 65 and 68 percent, and 65 and 31
percent, respectively, of the related consolidated totals. Those statements
were audited by other auditors whose report has been furnished to us, and our
opinion, insofar as it relates to the amounts included for AmeriGas Propane,
Inc. and subsidiaries for those periods, is based solely on the report of the
other auditors.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audits to
obtain reasonable assurance about whether the financial statements are free of
material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial
statement presentation. We believe that our audits and the report of the other
auditors provide a reasonable basis for our opinion.
In our opinion, based on our audits and the report of the other
auditors, the consolidated financial statements referred to above present
fairly, in all material respects, the consolidated financial position of UGI
Corporation and subsidiaries as of September 30, 1996 and 1995 and the
consolidated results of their operations and their cash flows for the years
ended September 30, 1996, 1995 and 1994, in conformity with generally accepted
accounting principles.
As discussed in Note 7 to the consolidated financial statements, the
Company changed its method of accounting for postemployment benefits in 1995.
/s/ COOPERS & LYBRAND L.L.P.
2400 Eleven Penn Center
Philadelphia, Pennsylvania
November 22, 1996
39
<PAGE> 31
Appendix to Exhibit 13 - Description of Graphic Material
Financial Review - page 10
Organizational Chart of UGI Corporation and subsidiaries representing UGI
Corporation and its three wholly owned subsidiaries AmeriGas, Inc. (AmeriGas),
UGI Enterprises, Inc. (Enterprises), and UGI Utilities, Inc. (which is
comprised of Gas Utility and Electric Utility).
The chart also reflects AmeriGas's wholly owned subsidiary, AmeriGas Propane,
Inc. (General Partner) and the General Partner's 58% ownership interest in
AmeriGas Partners, L.P. (AmeriGas Partners) the remaining 42% of which is
publicly owned. The General Partner serves as general partner for AmeriGas
Partners.
AmeriGas Partners has a 99% limited partner interest in AmeriGas Propane, L.P.
(Operating Partnership) and the General Partner holds a 1% general partner
interest in the Operating Partnership.
Financial Review - page 11
Photograph
Photograph of Mr. Charles L. Ladner, Senior Vice President Finance, UGI
Corporation, in front of the New York Stock Exchange, New York, New York.
Financial Review - page 15
Pie Chart of AmeriGas Partners capitalization reflecting the following
proportions:
long-term debt - 59.9% of total capitalization;
partners' capital - 38.8% of total capitalization;
bank loans - 1.3% of total capitalization.
Financial Review - page 16
Pie Chart of UGI Utilities capitalization reflecting the following proportions:
long-term debt - 39.1% of total capitalization;
common equity - 41.9% of total capitalization;
bank loans - 11.2% of total capitalization;
preferred stock - 7.8% of total capitalization.
40
<PAGE> 32
Financial Review - pge 16
Pie chart of sources of cash for UGI Corporation reflecting in millions:
cash provided by operations of $111.2;
cash provided by debt issued of $80.6;
cash provided by common stock issued of $11.3;
cash provided by other sources of $3.9.
Financial Review - page 16
Pie chart of uses of cash for UGI Corporation reflecting in millions:
cash used for dividends and distributions of $85.1;
cash used for capital expenditures of $62.7;
cash used for debt repayments of $59.7;
cash used for acquisitions of $28.0;
cash used for short-term investments of $12.1;
cash used for common stock repurchases of $7.1.
41
<PAGE> 1
EXHIBIT 21
<TABLE>
<CAPTION>
- ----------------------------------------------------------------------------------------------------------------------
UGI CORPORATION SUBSIDIARIES
- ----------------------------------------------------------------------------------------------------------------------
STATE OF
SUBSIDIARY INCORPORATION OWNERSHIP
- ----------------------------------------------------------------------------------------------------------------------
<S> <C> <C>
AMERIGAS, INC. PA 100%
FOUR FLAGS DRILLING COMPANY, INC. PA 100%
AMERIGAS PROPANE, INC.(1) PA 100%
AmeriGas Partners, L.P. DE (2)
AmeriGas Finance Corp. DE 100%
AmeriGas Propane, L.P. DE (3)
AmeriGas Propane Parts & PA 100%
Service, Inc.
Northwest LPG Supply Ltd. Canada 100%
Petrolane Offshore Limited Bermuda 100%
Petrolane Incorporated PA 100%
Atlantic Energy, Inc. DE 50%
AmeriGas Technology Group, Inc. PA 100%
Diamond Acquisition, Inc. HI 100%
- ----------------------------------------------------------------------------------------------------------------------
ASHTOLA PRODUCTION COMPANY PA 100%
CRYOTEX, INCORPORATED DE 100%
KEYSTONE OILFIELD SUPPLY CO. PA 100%
UGI ETHANOL DEVELOPMENT CORPORATION PA 100%
- ----------------------------------------------------------------------------------------------------------------------
UGI ENTERPRISES, INC. PA 100%
UGI ENERGY SERVICES, INC. PA 100%
UGI BLACK SEA ENTERPRISES, INC. PA 100%
UGI ENERGY SUPPLY, INC. PA 100%
UGI INTERNATIONAL (CHINA), INC. DE 100%
UGI INTERNATIONAL (ROMANIA), INC. PA 100%
- ----------------------------------------------------------------------------------------------------------------------
</TABLE>
<PAGE> 2
<TABLE>
<S> <C> <C>
- -----------------------------------------------------------------------------------------------------------------------
UGI PROPERTIES, INC. PA 100%
- -----------------------------------------------------------------------------------------------------------------------
UGI UTILITIES, INC. PA 100%
UGI DEVELOPMENT COMPANY PA 100%
- -----------------------------------------------------------------------------------------------------------------------
UNITED VALLEY INSURANCE COMPANY VT 100%
- -----------------------------------------------------------------------------------------------------------------------
</TABLE>
(1) General Partner of AmeriGas Partners, L.P. and AmeriGas Propane, L.P.,
Delaware limited partnerships.
(2) AmeriGas Propane, Inc. owns 100% of general partnership interest and
38.4% of limited partnership interest in AmeriGas Partners, L.P.;
Petrolane Incorporated owns 18.6% of limited partnership interest in
AmeriGas Partners, L.P.; and Diamond Acquisition, Inc. owns 0.3% of the
limited partnership interest in AmeriGas Partners, L.P.
(3) AmeriGas Propane, Inc. owns 100% of general partnership interest in
AmeriGas Propane, L.P.; AmeriGas Partners, L.P. owns 100% of limited
partnership interest in AmeriGas Propane, L.P.
<PAGE> 1
Exhibit (23)
CONSENT OF INDEPENDENT ACCOUNTANTS
We consent to the incorporation by reference in the registration statements of
UGI Corporation on Form S-8 (File No. 33-47319), Form S-3 (File No. 33-78776)
and Form S-8 (File No. 33-61722) of our reports dated November 22, 1996 on our
audits of the consolidated financial statements and financial statement
schedules of UGI Corporation and subsidiaries for the year ended September 30,
1996, which reports are included (or incorporated by reference) in UGI
Corporation's Annual Report on Form 10-K for the year ended September 30, 1996.
COOPERS & LYBRAND L.L.P
2400 Eleven Penn Center
Philadelphia, Pennsylvania
December 26, 1996
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM THE
CONSOLIDATED BALANCE SHEET AND INCOME STATEMENT OF UGI CORPORATION AND
SUBSIDIARIES AS OF AND FOR THE YEAR ENDED SEPTEMBER 30, 1996 AND IS QUALIFIED IN
ITS ENTIRETY BY REFERENCE TO SUCH FINANCIAL STATEMENTS INCLUDED IN UGI
CORPORATION'S ANNUAL REPORT ON FORM 10-K FOR THE YEAR ENDED SEPTEMBER 30, 1996.
</LEGEND>
<CIK> 0000884614
<NAME> UGI CORPORATION
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> SEP-30-1996
<PERIOD-START> OCT-01-1995
<PERIOD-END> SEP-30-1996
<CASH> 74,000
<SECURITIES> 23,100
<RECEIVABLES> 132,500
<ALLOWANCES> 10,600
<INVENTORY> 113,200
<CURRENT-ASSETS> 381,600
<PP&E> 1,342,800
<DEPRECIATION> 368,200
<TOTAL-ASSETS> 2,144,900
<CURRENT-LIABILITIES> 369,200
<BONDS> 845,200
35,200
0
<COMMON> 391,900
<OTHER-SE> (14,300)
<TOTAL-LIABILITY-AND-EQUITY> 2,144,900
<SALES> 1,557,600
<TOTAL-REVENUES> 1,557,600
<CGS> 887,100
<TOTAL-COSTS> 887,100
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 79,500
<INCOME-PRETAX> 75,900
<INCOME-TAX> 33,600
<INCOME-CONTINUING> 39,500
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 39,500
<EPS-PRIMARY> 1.19
<EPS-DILUTED> 1.19
</TABLE>
<PAGE> 1
EXHIBIT 99
FORWARD-LOOKING STATEMENTS
In connection with the "safe harbor" provisions of the Private
Securities Litigation Reform Act of 1995, UGI Corporation ("UGI" or the
"Company") is hereby filing cautionary statements identifying important factors
that could cause the Company's actual results to differ materially from those
projected in forward-looking statements of the Company made by or on behalf of
the Company.
RISK FACTORS
The financial and operating performance of UGI Corporation is subject
to risks and uncertainties, all of which are difficult to predict, and many of
which are beyond the control of the Company's management. Forward-looking
statements concerning the Company's performance may differ materially from
actual results because of these risks and uncertainties. They include, but are
not limited to:
1. Weather conditions;
2. price and availability of all energy products,
including natural gas, propane and oil, and the
capacity to transport to market areas;
3. governmental legislation and regulations;
4. local economic conditions;
5. labor relations;
6. environmental claims;
7. competition from the same and alternative energy
sources;
8. operating hazards and other risks incidental to
generating and distributing electricity and
transporting, storing, and distributing natural gas
and propane;
9. energy efficiency and technology trends;
10. distributions from subsidiaries;
11. interest rates; and
12. large customer defaults.
