PART I
ITEM l. BUSINESS
GENERAL
Pennsylvania Enterprises, Inc. (the "Company") is a holding company formed
in 1974 whose principal subsidiary, PG Energy Inc. ("PGE"), a regulated public
utility formerly known as Pennsylvania Gas and Water Company, is engaged in the
distribution of natural gas. In 1996, PGE accounted for approximately 87% of
the Company's operating revenues. On February 14, 1997, PGE acquired all of the
outstanding capital stock of Honesdale Gas Company ("Honesdale"), a regulated
public utility engaged in distributing natural gas in portions of Wayne and Pike
Counties, in an area adjacent to PGE's service territory. Until February 16,
1996, when its water utility operations were sold, PGE was also engaged in the
distribution of water (See "-Sale of Water Utility Operations.")
The Company's other subsidiaries, each of which is engaged in nonregulated
activities, consist of Pennsylvania Energy Resources, Inc. ("PERI") and its
wholly-owned subsidiary Keystone Pipeline Services, Inc. ("Keystone"), which was
acquired effective December 4, 1995, and Theta Land Corporation ("THETA").
Pennsylvania Energy Marketing Company, previously a subsidiary of the Company,
was merged into PERI on May 31, 1996. Prior to 1996, these other subsidiaries
did not constitute a significant portion of either the Company's assets or
operations. However, it is anticipated that in 1997 the revenues of these
subsidiaries will account for 15-20% of the Company's operating revenues and
35-40% of its capital expenditures.
Both PGE, incorporated in Pennsylvania in 1867 as Dunmore Gas & Water
Company, and Honesdale are regulated by the Pennsylvania Public Utility
Commission ("PPUC"). As of December 31, 1996, PGE provided service to
approximately 144,200 natural gas customers and Honesdale provided service to
approximately 3,200 customers.
The Company and its subsidiaries employed approximately 760 persons as of
December 31, 1996.
Restructuring of Natural Gas Industry
The natural gas industry, which historically has included producers,
interstate pipelines and local distribution companies ("LDCs"), is continuing to
undergo significant restructuring. The industry is rapidly progressing from a
highly regulated environment to one in which there is competition, customer
choice and only partial regulation. The same change is also beginning to occur
in the electric industry which competes with the natural gas industry for many
of the same energy uses.
The restructuring of the natural gas industry has already involved the
decontrol of the wellhead price of natural gas, and interstate pipelines have
been required by the Federal Energy Regulatory Commission ("FERC") to separate
the merchant function of selling natural gas from the transportation and storage
services they provide (frequently referred to as "unbundling") and to make those
services available to end users on the same terms as LDCs. These changes in the
operations of the interstate pipelines were designed to enhance competition and
maximize the benefits of wellhead price decontrol.
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As a result of actions by FERC, the interstate pipelines now primarily
provide transportation and storage services, and LDCs, such as PGE, are
presently responsible for the procurement of competitively-priced gas supplies
and arranging for the appropriate transportation capacity and storage services
with the interstate pipelines. Additionally, in accordance with regulations
promulgated by the PPUC, PGE currently offers transportation service to certain
customers.
Prior to the unbundling of services by the interstate pipelines and those
services being made available to end users as well as LDCs, and until the PPUC
adopted regulations providing for the transportation of natural gas, PGE charged
all its customers bundled rates. These rates included a commodity charge based
on the cost, as approved by FERC, which PGE paid the pipelines for natural gas
delivered to the entry point on its distribution system. Except for the
approximately 500 customers currently receiving transportation service, PGE's
customers continue to be charged bundled rates as approved by the PPUC, which
include a commodity charge based on the costs prudently incurred by PGE for the
purchase of natural gas and for interstate pipeline transportation capacity and
storage services. Customers receiving transportation service, which accounted
for approximately 43% of PGE's total gas deliveries in 1996, are charged rates
approved by the PPUC, which exclude the commodity cost that is reflected in the
bundled rates charged to other customers.
In December, 1996, legislation was enacted in Pennsylvania which provides
all customers of electric utilities in the state with the right to choose the
generator of their electricity. This customer choice, which is intended to
increase competition and to lower costs for electricity, will be phased in over
a three-year period ending on January 1, 2001. Under this legislation, the
electric utilities in Pennsylvania will be required to unbundle generation
charges from the other charges included in their currently bundled rates and
customers will contract with qualified suppliers of their choosing, including
the utility currently serving them, to purchase electric energy at nonregulated
rates. The electric utilities will continue to utilize their transmission
networks to distribute electricity to their customers regardless of supplier, a
function which will remain subject to rate regulation by the PPUC.
The Company and PGE believe that Pennsylvania may consider similar
legislation with respect to the natural gas industry in 1997. Such legislation
may require that PGE provide all of its customers with unbundled service over a
period of several years. While the rates for the transportation of natural gas
through PGE's distribution system and the storage services offered by PGE may
continue to be price regulated by the PPUC, the commodity cost of gas may not be
so regulated. Essentially, the transportation service which is now available to
a limited number of PGE's customers would be extended to all its customers.
Customers would choose the supplier of their natural gas, which could be PGE,
based on nonregulated market prices and other considerations.
If Pennsylvania enacts legislation which permits all customers of LDCs to
choose their supplier of natural gas, PGE will be faced with significant
competition from other gas utilities and marketers for the sale of natural gas
to its customers. However, under current regulations of the PPUC, PGE does not
realize a profit or incur any loss with respect to the commodity cost of natural
gas. Moreover, PGE would not expect the legislation to result in the bypass of
its distribution system by any significant number of customers because of the
nature of its customer base and the cost of any such bypass. Additionally,
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based on the recently-enacted electric industry legislation, PGE anticipates
that any transition costs (such as the negotiated buyout of contracts with
interstate pipelines, the recovery of deferred purchased gas costs or the
recovery of regulated assets) it has or might incur as a result of legislation
providing for customer choice of natural gas suppliers would be recovered
through a nonbypassable customer charge. Accordingly, although it cannot be
certain, because the terms of such legislation have not been finalized and the
ultimate effect on PGE cannot be determined, PGE does not believe that the
enactment of legislation providing for customers to purchase their natural gas
from third parties would have any material adverse impact on its earnings or
financial condition despite the increased competition to which PGE would be
subject regarding the sale of natural gas to its customers.
Expansion of Nonregulated Activities
The Company intends that PGE, along with its affiliates, will remain a
leading supplier of energy and energy-related products and services even if the
sale of natural gas to its customers is deregulated. PGE will actively market
the sale of natural gas, and possibly other forms of energy, to its customers on
a competitive, nonregulated basis and will continue to aggressively add
customers to its distribution system. Additionally, the Company plans to
further expand the activities of PERI, which presently provides a broad array of
energy supply and energy management services, including the marketing and sale
of natural gas to commercial and industrial users in northeastern United States
(and in connection therewith enters into forward contracts for the purchase and
sale of natural gas at variable and fixed prices for terms up to one year); the
sale of propane on both a retail and wholesale level in central and northeastern
Pennsylvania; the inspection, maintenance and servicing of residential and small
commercial gas-fired equipment; and through its subsidiary Keystone, specialized
pipeline distribution services for utilities, including keyhole vacuum
excavation, camera inspection and bridge pipeline rehabilitation, as well as the
installation of mains and services for the natural gas, water and sewer
industries. In addition, the Company, through its subsidiary Theta, is
presently initiating several residential and commercial development projects,
including a residential development located at the Montage Mountain Ski Resort
in Lackawanna County, known as "White Cliff at Montage," which will consist of
townhomes and single family dwellings and a development near Wilkes-Barre in
Luzerne County, known as "Laurel Run," which will consist of a motel,
restaurant, small strip shopping center and townhomes on Company-owned land.
Theta is also developing plans to conduct timber, sand and gravel operations on
the Company's land and to increase the value being realized from the Company's
extensive land holdings through a more active management of those resources.
Sale of Water Utility Operations
On February 16, 1996, PGE sold its regulated water operations and certain
related assets to Pennsylvania-American Water Company ("Pennsylvania-American"),
a wholly-owned subsidiary of American Water Works Company, Inc. ("American"),
for $414.3 million, consisting of $262.1 million in cash and the assumption of
$152.2 million of PGE's liabilities, including $141.0 million of its long-term
debt. (See Note 2, Discontinued Operations, of the Notes to Consolidated
Financial Statements in Item 8 of this Form 10-K).
The cash proceeds from the sale of approximately $203.3 million, net of an
estimated $58.8 million of income taxes, were used by the Company and PGE to
retire debt, to repurchase stock, for construction expenditures and for working
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capital purposes. (See "Management's Discussion and Analysis of Financial
Condition and Results of Operations-Liquidity and Capital Resources-Sale of
Water Utility Operations" in Item 7 of this Form 10-K).
GAS BUSINESS
PGE distributes natural gas to an area in northeastern Pennsylvania lying
within the Counties of Lackawanna, Luzerne, Wyoming, Susquehanna, Columbia,
Montour, Northumberland, Lycoming, Union and Snyder, a territory that includes
116 municipalities, in addition to the cities of Scranton, Wilkes-Barre and
Williamsport. The total estimated population of PGE's natural gas service area,
based on the 1990 U.S. Census, is 561,000.
Number and Type of Customers. At December 31, 1996, PGE had approximately
144,200 natural gas customers, from which it derived total natural gas revenues
of $160.6 million during 1996. The following chart shows a breakdown of the
types of customers and the percentages of gas revenues generated by each type of
customer in 1996:
[CAPTION]
Type of Customer % of Customers % of Revenues
[S] [C] [C]
Residential 91.2% 61.7%
Commercial 8.4 24.1*
Industrial 0.2 12.9*
Other Users 0.2 1.3
Total 100.0% 100.0%
* Includes the 4.5% of total gas revenues derived from interruptible
customers.
During 1996, PGE delivered an estimated total of 47,600,000 thousand cubic
feet ("MCF") of natural gas to its customers, of which 56.1% was sold at normal
tariff rates, 42.9% represented gas transported for customers and 1.0% was sold
under the Alternate Fuel Rate (as described below).
PGE sells gas to "firm" customers with the understanding that it will not
interrupt their supply except during periods of supply deficiency or emergency
conditions. "Interruptible" gas customers are required to have equipment
installed capable of using an alternate energy form. Interruptible customers,
therefore, do not require a continuous supply of gas and their supply can be
interrupted by PGE at any time under the conditions set forth in their contracts
for gas service. In 1996, a total of 1,321,000 MCF of natural gas was sold by
PGE to interruptible customers and 3,681,000 MCF was transported for such
customers, which together represented 10.5% of the total deliveries of natural
gas by PGE to its customers during 1996.
PGE's largest natural gas customer accounted for approximately 2.5% of PGE's
operating revenues in 1996. No other customer accounted for as much as 2.0% of
such revenues in 1996.
Transportation and Storage Service. In accordance with current regulations
of the PPUC, PGE provides transportation service to natural gas customers who
consume at least 5,000 MCF of natural gas per year, meet certain other
conditions and execute a transportation agreement. In addition, groups of up to
ten customers, with a combined consumption of at least 5,000 MCF per year, are
eligible for transportation service. Transportation service is provided on both
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a firm and an interruptible basis and includes provisions regarding over and
under deliveries of gas on behalf of the respective customer. In addition, PGE
offers firm transportation customers a "storage service" pursuant to which such
customers may have gas delivered to PGE during the period from April through
October for storage and redelivery during the winter period. PGE also offers
firm transportation customers a "standby service" under the terms of which PGE
will supply the customer with gas in the event the customer's transportation
service is interrupted or curtailed by its broker, supplier or other third
party.
Set forth below is a summary of the gas transported by PGE and the number of
its customers using transportation service from 1994 to 1996:
[CAPTION]
Number Volume of Gas Transported (MCF)
of Interstate Pennsylvania
Year Customers Gas Gas Total
[S] [C] [C] [C] [C]
1996 503 15,959,000 4,459,000 20,418,000
1995 480 14,543,000 5,054,000 19,597,000
1994 574 13,411,000 4,744,000 18,155,000
During 1997, PGE expects to transport approximately 22,000,000 MCF of
natural gas.
The decrease in the number of customers using transportation service in 1995
was the result of PGE requiring such customers to install telemetering equipment
so that PGE could monitor the usage by those customers on a daily basis and
thereby determine if the appropriate quantities of natural gas were being
delivered for them. This requirement for telemetering equipment caused a number
of customers, for whom relatively small quantities of natural gas were being
transported, to revert to sales service.
The rates charged by PGE for the transportation of interstate gas are
essentially equal to its tariff rates for the sale of gas with all gas costs
removed. Accordingly, the transportation of interstate gas has had no
significant adverse effect on earnings. Prior to January 15, 1997, the rates
charged for the transportation of Pennsylvania-produced natural gas
("Pennsylvania gas") were lower than those charged for the transportation of
interstate gas. As a result, the rates charged for the transportation of
Pennsylvania gas yielded considerably less revenue than the gross margin (gas
operating revenues less the cost of gas) that would be realized from sales under
normal tariff rates. However, as of January 15, 1997, in connection with the
rate increase which was effective on such date (see "-Rates"), the lower rates
charged for the transportation of Pennsylvania gas were eliminated and those
rates were conformed with the rates charged for the transportation of interstate
gas.
Alternate Fuel Sales. In order to be more competitive in terms of price
with certain alternate fuels, PGE offers an Alternate Fuel Rate for eligible
customers. This rate applies to large commercial and industrial accounts that
have the capability of using No. 2, 4 or 6 fuel oil or propane as an alternate
source of energy. Whenever the cost of such alternate fuel drops below the cost
of natural gas at PGE's normal tariff rates, PGE is permitted by the PPUC to
lower its price to these customers so that PGE can remain competitive with the
alternate fuel. However, in no instance may PGE sell gas under this special
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arrangement for less than its average commodity cost of gas purchased during the
month. PGE's revenues under the Alternate Fuel Rate amounted to $1.8 million in
1996, $2.0 million in 1995 and $3.7 million in 1994. These revenues reflected
the sale of 491,000 MCF, 603,000 MCF and 1,223,000 MCF in 1996, 1995 and 1994,
respectively. It is anticipated that approximately 426,000 MCF will be sold
under the Alternate Fuel Rate in 1997. The change in volumes sold under the
Alternate Fuel Rate reflects the switching by certain customers between
alternate fuel service and transportation service as a result of periodic
changes in the relative cost of natural gas and alternate fuels.
FERC Order 636. On April 8, 1992, FERC issued Order No. 636 ("Order 636"),
requiring interstate pipelines to restructure their services and operations in
order to enhance competition and maximize the benefits of wellhead price
decontrol. The objectives of Order 636 were to be accomplished primarily by
unbundling the services provided by the interstate pipelines and by making those
services available to end users on the same terms as LDCs.
Pursuant to Order 636, the interstate pipelines have been required to: (1)
unbundle transportation service from sales service; (2) allocate sufficient
storage capacity, together with firm transportation, to replicate previous sales
services; (3) provide a no-notice transportation service; (4) provide open
access storage service; (5) reallocate upstream pipeline capacity and upstream
storage for the benefit of downstream interstate pipeline suppliers; and (6)
implement a straight fixed-variable rate design to replace all modified fixed-
variable rate designs. The interstate pipelines have been granted a blanket
sales certificate to make unbundled sales in competition with non-pipeline
merchants and are being permitted recovery of all reasonable and prudent
transition costs incurred in order to comply with Order 636. Such transition
costs include: (1) the cost of renegotiating existing gas supply contracts with
producers ("Gas Supply Realignment Costs"); (2) recovery of gas costs included
in the interstate pipelines' purchased gas adjustment accounts at the time they
adopted market-based pricing for gas sales ("Account 191 Costs"); (3)
unrecovered costs of assets that cannot be assigned to customers of unbundled
services ("Stranded Costs"); and (4) costs of new facilities to physically
implement Order 636 ("New Facility Costs"). Additionally, the interstate
pipelines have been allowed pre-granted abandonment of sales and transportation
services to customers upon expiration of applicable contracts, subject to
customers' rights of first refusal.
On October 15, 1993, the PPUC adopted an annual purchased gas cost ("PGC")
order (the "PGC Order") regarding the recovery of Order 636 transition costs.
The PGC Order stated that Account 191 and New Facility Costs (the "Gas
Transition Costs") are subject to recovery through the annual PGC rate filing
made with the PPUC by PGE and other larger LDCs.
As of February 1, 1994, PGE began to recover the Gas Transition Costs that
are being billed to PGE by its interstate pipelines through an increase in its
PGC rate. As of December 31, 1996, PGE had been billed a total of $1.3 million
of Gas Transition Costs by its interstate pipelines, which is the entire amount
of such billings that PGE expects. Of this amount, $857,000 was recovered by
PGE over a twelve-month period ended January 31, 1995, through an increase in
its PGC rate, $252,000 was recovered by PGE in its annual PGC rate that the PPUC
approved effective December 1, 1995, and the remaining $213,000 is being
recovered by PGE in its PGC rate that was effective December 1, 1996.
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The PGC Order also indicated that while Gas Supply Realignment and Stranded
Costs (the "Non-Gas Transition Costs") are not natural gas costs eligible for
recovery under the PGC rate filing mechanism, such costs are subject to full
recovery by LDCs through the filing of a tariff pursuant to either the existing
surcharge or base rate provisions of the Pennsylvania Public Utility Code (the
"Code"). By Order of the PPUC entered August 26, 1994, PGE began recovering the
Non-Gas Transition Costs that it estimates it will ultimately be billed pursuant
to Order 636 through the billing of a surcharge to its customers effective
September 12, 1994. It is currently estimated that $10.1 million of Non-Gas
Transition Costs will be billed to PGE, generally over a six-year period
extending through January 1, 1999, of which $8.0 million had been billed to PGE
and $7.5 million had been recovered from its customers as of December 31, 1996.
PGE has recorded the estimated transition costs that remained to be billed to it
and the amounts remaining to be recovered from its customers.
Sources of Supply. PGE purchases natural gas from marketers, producers, and
integrated energy companies, generally under the terms of supply arrangements
that extend for the heating season (i.e., November through March) or for periods
of one year or longer. These contracts typically provide for an adjustment each
month in the cost of gas purchased pursuant thereto based on the then current
market prices for natural gas. The largest individual supplier, an integrated
energy company, accounted for 22.5% of PGE's total purchases of natural gas in
1996. Three other suppliers accounted for 18.7%, 17.9% and 16.2% of PGE's total
purchases of natural gas in 1996. No other suppliers accounted for more than 3%
of PGE's purchases during 1996.
The purchases of natural gas by PGE during each of the years 1996, 1995 and
1994 are summarized below:
[CAPTION]
Volume Average
Year Purchased (MCF) Cost per MCF
[S] [C] [C]
1996 27,955,000 $3.35
1995 24,173,000 $2.62
1994 28,364,000 $2.82
The higher average cost for 1996 reflected the increase in the wellhead
price of natural gas during much of the year that resulted from the unusually
cold weather experienced in the northeastern United States during the winter of
1995/96 and the associated reduction in the volumes of gas held in storage to
abnormally low levels in the spring of 1996.
During 1997, PGE expects to purchase a total of approximately 28,750,000 MCF
of natural gas under seasonal or longer-term contracts at a currently projected
average cost of $2.89 per MCF.
PGE presently has adequate supplies of natural gas to meet the demands of
existing customers through October, 1997, and the Company believes that PGE will
be able to obtain sufficient supplies to meet the demands of its existing
customers beyond October, 1997, and to serve new customers (of which
approximately 4,000 are expected to be added in 1997).
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Pipeline Transportation and Storage Entitlements. Pursuant to the terms of
Order 636, PGE has entered into agreements with its former interstate pipeline
suppliers providing for the firm transportation by those pipelines on a daily
basis of the following quantities of gas:
[CAPTION]
Daily Percentage of Total
Expiration Transportation Transportation
Pipeline Date (a) Entitlement (MCF) Entitlement
[S] [C] [C] [C]
Transco Various through 2015 74,100 (b) 55.5%
Tennessee 1999 and 2000 48,252 36.2
Columbia 2004 11,016 8.3
133,368 100.0%
(a) Agreements are automatically extended from month-to-month or year-
to-year after their expiration unless notice of termination is given
by one of the parties and PGE agrees to such termination. In no
event may any of the agreements be unilaterally terminated by the
pipelines without the approval of the FERC.
(b) Includes 3,300 MCF per day that PGE can transport during the period
December through February pursuant to an agreement with Transco that
extends through 2011.
PGE has also contracted with its former interstate pipeline suppliers for
the following volumes of gas storage and storage withdrawals:
[CAPTION]
Maximum
Expiration Total Storage Daily Withdrawal
Pipeline Date (a) (MCF) (b) From Storage (MCF)
[S] [C] [C] [C]
Transco Various through 2013 6,500,000 131,044
Tennessee November 1, 2000 3,500,000 23,031
Columbia October 31, 2004 1,100,000 16,036
11,100,000 170,111
(a) Agreements are automatically extended from month-to-month or year-
to-year after their expiration unless notice of termination is given
by one of the parties and PGE agrees to such termination. In no
event may any of the agreements be unilaterally terminated by the
pipelines without the approval of the FERC.
(b) Storage is utilized in order to meet peak day and seasonal demands.
Based on its present pipeline transportation and storage entitlements, PGE
is entitled to a maximum daily delivery of the following quantities of gas:
[CAPTION]
Firm Pipeline Withdrawals
Transportation From Storage Percentage
Pipeline (MCF) (MCF) Total (MCF) of Total
[S] [C] [C] [C] [C]
Transco 74,100 (a) 131,044 205,144 67.6%
Tennessee 48,252 23,031 71,283 23.5
Columbia 11,016 16,036 27,052 8.9
133,368 170,111 303,479 100.0%
(a) Includes 3,300 MCF that may be transported during the period
December through February.
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In accordance with the provisions of Order 636, PGE may release to its
customers and other parties the portions of its firm pipeline transportation and
storage entitlements which are in excess of its requirements. Such releases may
be made upon notice in accordance with the provisions of Order 636 and for a
consideration not in excess of PGE's cost of the respective entitlement.
Releases may be made for periods ranging from one day to the remaining term of
the entitlement.
Since September 1, 1993, PGE has released portions of its firm pipeline
transportation capacity to certain of its customers and third parties for
varying periods extending up to three years. During 1996, the average daily
capacity so released was 40,689 MCF, and the maximum capacity released on any
one day in 1996 was 52,095 MCF. Through December 31, 1996, PGE had not,
however, released any of its storage capacity.
The Company believes that PGE has sufficient firm pipeline transportation
and storage entitlements to meet the demands of its existing customers and to
supply new customers.
Peak Day Requirements. PGE plans for peak day demand on the basis of a
daily mean temperature of 0 degrees Fahrenheit. Requirements for such a design
peak day, assuming the curtailment of service to interruptible customers, are
currently estimated to be 337,956 MCF, of which 252,550 MCF would be required
for customers to whom PGE sells gas and 85,406 MCF would be required for
customers for whom PGE provides transportation service. PGE's historic maximum
daily sendout is 307,237 MCF, which occurred on January 17, 1997, when service
to interruptible customers and select industrial users was curtailed. The mean
temperature in its gas service area on that day was 5 degrees Fahrenheit.
Capital Expenditures. Capital expenditures totaled $30.5 million during
1996, including $29.2 million for the construction of utility plant, and are
estimated to be $45.4 million during 1997, consisting of $27.9 million relative
to utility plant and $17.5 million with respect to the Company's nonregulated
activities, including $13.1 million for residential and commercial real estate
development.
Regulation. PGE's natural gas utility operations are regulated by the PPUC,
particularly as to utility rates, service and facilities, accounts, issuance of
certain securities, the encumbering or disposition of public utility properties,
the design, installation, testing, construction, and maintenance of PGE's
pipeline facilities and various other matters associated with broad regulatory
authority.
In addition to those regulations promulgated by the PPUC, PGE must also
comply with federal, state and local regulations relating generally to the
discharge of materials into the environment or otherwise relating to the
protection of the environment. Compliance with such regulations has not had any
material effect upon the capital expenditures, earnings or competitive position
of PGE's gas business. Although it cannot predict the future impact of these
regulations, the Company believes that any additional expenditures and costs
made necessary by them would be fully recoverable by PGE through rates.
PGE, like many gas distribution companies, once utilized manufactured gas
plants in connection with providing gas service to its customers. None of these
plants have been in operation since 1960, and several of the plant sites are no
longer owned by PGE. Pursuant to the Comprehensive Environmental Response,
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Compensation and Liability Act of 1980 ("CERCLA"), PGE filed notices with the
Environmental Protection Agency (the "EPA") with respect to the former plant
sites. None of the sites is or was formerly on the proposed or final National
Priorities List. The EPA has conducted site inspections and made preliminary
assessments of each site and has concluded that no further remedial action is
planned. While this conclusion does not constitute a legal prohibition against
further regulatory action under CERCLA or other applicable federal or state
laws, PGE does not believe that additional costs, if any, related to these
manufactured gas plant sites will be material to its financial position or
results of operations.
The Company is a "holding company" within the meaning of the Public Utility
Holding Company Act of 1935, as amended ("PUHCA"), but it is exempt, pursuant to
Section 3(a) of the PUHCA, from all the provisions of the PUHCA (except Section
9(a)(2) thereof) and the rules and regulations promulgated thereunder. The
Company files an annual exemption statement on Form U-3A-2 pursuant to Rule U-2
promulgated under the PUHCA. Pursuant to the PUHCA, certain acquisitions by the
Company or its subsidiaries of the stock or assets of gas or electric public
utilities are subject to prior approval by the Securities and Exchange
Commission.
PGE's gas distribution and transportation activities are not subject to the
Natural Gas Act, as amended.
Rates. On May 24, 1996, PGE filed an application with the PPUC seeking an
increase in its base gas rates, designed to produce $14.1 million in additional
annual revenue, to be effective July 23, 1996. On June 20, 1996, the PPUC
suspended this rate increase for seven months (until February 23, 1997) in order
to investigate the reasonableness of the proposed rates. On November 7, 1996,
PGE and certain parties filing objections to the rate increase request filed a
Settlement Agreement and Joint Petition for Settlement of Rate Investigation
(the "Settlement Petition") with the Administrative Law Judge assigned to
conduct the investigation of the rate increase request. This Settlement
Petition provided for an overall 5.3% rate increase that was designed to produce
$7.5 million of additional annual revenue. By Order adopted December 19, 1996,
the PPUC approved the Settlement Petition effective January 15, 1997. Under the
terms of the Settlement Petition, the billing for the impact of the rate
increase relative to PGE's residential heating customers (which it is estimated
will total $6.6 million on an annual basis) is being deferred, without carrying
charges, until July, 1997.
The provisions of the Code require that the tariffs of LDCs such as PGE, be
adjusted on an annual basis, and on an interim basis when circumstances dictate,
to reflect changes in their purchased gas costs. The procedure includes a
process for the reconciliation of actual gas costs incurred and actual revenues
received and also provides for the refund of any overcollections, plus interest
thereon, or the recoupment of any undercollections of gas costs. The procedure
is limited to purchased gas costs, to the exclusion of other rate matters, and
requires a formal evidentiary proceeding conducted by the PPUC, the submission
of specific information regarding gas procurement practices and specific
findings of fact by the PPUC regarding the "least cost fuel procurement"
policies of the utility.
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Effective September 14, 1995, the PPUC adopted regulations that provide for
the quarterly adjustment of the annual purchased gas cost rate of larger LDCs,
including PGE. Such quarterly adjustments are allowed when the actual costs
vary from the costs reflected in the respective company's tariffs by 2% or more.
Except for reducing the amount of any over or undercollections of gas costs,
these regulations will not have any material effect on PGE's financial position
or results of operations, and PGE is still required to file an annual purchased
gas cost rate.
In accordance with these annual and quarterly procedures, PGE has been
permitted to make the following changes since January 1, 1994, to the gas costs
contained in its gas tariff rates:
[CAPTION]
Change in Calculated
Effective Rate per MCF Increase (Decrease)
Date From To in Annual Revenue
[S] [C] [C] [C]
March 1, 1997 $4.18 $4.49 $ 8,300,000
December 1, 1996 3.01 4.18 32,400,000
September 1, 1996 2.88 3.01 3,600,000
June 1, 1996 2.75 2.88 3,400,000
December 1, 1995 2.42 2.75 9,600,000
May 15, 1995 3.68 2.42 (8,200,000)*
December 1, 1994 3.74 3.68 (1,800,000)
* Represents estimated reduction in revenue for the period May 15, 1995,
through November 30, 1995.
The changes in gas rates on account of purchased gas costs have no effect on
PGE's earnings since the change in revenue is offset by a corresponding change
in the cost of gas.
FERC Order 636, among other matters, requires that PGE contract for
sufficient gas supplies, pipeline capacity and storage for its annual needs.
These added responsibilities have resulted in increased scrutiny by the PPUC as
to the prudence of PGE's gas procurement and supply activities. However, to
date, the PPUC has permitted PGE to recover all of its gas supply costs in the
rates charged to customers. Additionally, although it cannot be certain, the
Company believes that PGE will be able to continue demonstrating to the PPUC the
prudence of its gas supply costs and, therefore, will be allowed to recover all
such costs in its future purchased gas cost rates.
Tax Surcharge Adjustments. Regulations of the PPUC provide for PGE to apply
a state tax adjustment surcharge tariff to its bills for gas service to recoup
any increased taxes or passthrough any decreased taxes resulting from changes in
the law with respect to the Pennsylvania Capital Stock Tax, Corporate Net Income
Tax, Gross Receipts Tax or Public Utility Realty Tax. Currently, no state tax
adjustment surcharge is being applied to PGE's bills for gas service.
WATER BUSINESS
Prior to the sale of its water operations to Pennsylvania-American on
February 16, 1996, PGE distributed water to an area lying within the Counties of
Lackawanna, Luzerne, Susquehanna and Wayne, which included the Cities of
Scranton and Wilkes-Barre and 63 other municipalities. The total estimated
population of the water service area, based on the 1990 U.S. Census, was
373,000.
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<PAGE>
Number and Type of Customers. At December 31, 1995, PGE had approximately
133,400 water customers from which it derived total water revenues of $66.3
million during 1995 and $7.5 million during the period January 1 through
February 15, 1996.
Filtration of Water Supplies. All of PGE's water customers were supplied
with filtered water (except for several hundred who were supplied with ground
water from wells). The filtration of PGE's water supplies was performed at ten
water treatment plants, located throughout PGE's water service area, which had
an aggregate daily capacity of 101.1 million gallons.
Construction Expenditures. PGE's construction expenditures for water
utility plant totaled $15.3 million in 1995 and $815,000 during the period
January 1 through February 15, 1996.
EXECUTIVE OFFICERS OF THE COMPANY
<TABLE>
<CAPTION>
Positions and
Officer Offices with the
Name Age Since Company
<S> <C> <C> <C>
Kenneth L. Pollock 76 1987 Chairman of the Board of
Directors
Thomas F. Karam 38 1995 President and Chief Executive
Officer
Vincent A. Bonaddio 47 1995 Vice President, Operations and
Engineering Services
Harry E. Dowling 47 1984 Vice President, Customer
Services
John F. Kell, Jr. 59 1978 Vice President, Financial
Services
Joseph F. Perugino 58 1988 Vice President
Thomas J. Ward 46 1988 Vice President, Administrative
Services, and Secretary
Richard N. Marshall 39 1993 Treasurer and Assistant
Secretary
Thomas J. Koval 44 1992 Controller and Assistant
Treasurer
Each of the Executive Officers has been elected to serve until the first
meeting of the Board of Directors of the Company following the 1997 Annual
Meeting and until his successor has been duly elected. Also, each of these
Officers holds the same position with PGE, except for Mr. Perugino, who is not
an officer of PGE, but who is the President of PERI. Other than with respect to
Mr. Karam, who has an employment agreement with the Company as President and
Chief Executive Officer for a five-year period ending September 1, 2001, and Mr.
Pollock, who has an employment agreement with the Company as Chairman of the
Board of Directors for a three-year period ending June 26, 1999, subject to his
re-election by the Company's shareholders, there are no arrangements or
understandings between any officer and any other person pursuant to which he was
selected as an officer.
</TABLE>
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<PAGE>
ITEM 2. PROPERTIES
Gas. PGE's gas system consists of approximately 2,265 miles of distribution
lines, nine city gate and 75 major regulating stations and miscellaneous related
and additional property. PGE believes that its gas utility properties are
adequately maintained and in good operating condition in all material respects.
Most of PGE's gas utility properties are subject to a first mortgage lien
pursuant to the Indenture of Mortgage and Deed of Trust dated as of March 15,
1946, as supplemented by thirty supplemental indentures (collectively, the
"Indenture") from PGE to First Trust of New York, National Association, as
Trustee.
Land. As of March 1, 1997, PGE owned approximately 46,000 acres of
undeveloped land situated in northeastern Pennsylvania.
ITEM 3. LEGAL PROCEEDINGS
There are no legal proceedings other than ordinary routine litigation
incidental to the business of the Company or its subsidiaries.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
During the fourth quarter of 1996, there were no matters submitted to a vote
of security holders of the registrant through the solicitation of proxies or
otherwise.
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<PAGE>
PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER
MATTERS
The Company's common stock is traded on the New York Stock Exchange under
the symbol "PNT." Quotations are shown in the Wall Street Journal as "PennEntr"
and in The New York Times as "PennEnt." As of March 1, 1997, there were
approximately 6,627 holders of record of the Company's common stock.
Listed below are the price ranges of the Company's common stock and the
dividends per share of common stock paid during the years ended December 31,
1996 and 1995. The prices shown represent the high and low transaction prices
for the respective quarters without retail mark-up, mark-down or commission.
[CAPTION]
Price Range(1) Cash
High Low Dividends(1)
1996
[S] [C] [C] [C]
First quarter $20.000 $18.313 $ .275
Second quarter 21.313 18.813 .275
Third quarter 21.438 19.875 .275
Fourth quarter 22.938 20.500 .275
Total $ 1.100
1995
[CAPTION]
[S] [C] [C] [C]
First quarter $15.688 $13.563 $ .275
Second quarter 17.000 15.313 .275
Third quarter 17.313 15.375 .275
Fourth quarter 19.063 17.125 .275
Total $ 1.100
(1) After restatement for the two-for-one split of the Company's common
stock effective March 20, 1997, as more fully discussed in Note 5 of
the Notes to Consolidated Financial Statements in Item 8 of this Form
10-K.
Information relating to restrictions on the payment of dividends by the
Company is set forth in Note 8 of the Notes to Consolidated Financial Statements
in Item 8 of this Form 10-K.
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<PAGE>
ITEM 6. SELECTED FINANCIAL DATA
Selected consolidated financial data for the Company and its subsidiaries
for each of the five years in the period ended December 31, 1996, is set forth
below. This data should be read in conjunction with the Consolidated Financial
Statements contained in Item 8 of this Form 10-K:
<TABLE>
<CAPTION>
Year Ended December 31,
1996 1995 1994 1993 1992
(Thousands of Dollars, Except Per Share Amounts)
<S> <C> <C> <C> <C> <C>
OPERATING REVENUES:
Gas sales and services $173,622 $160,850 $176,830 $159,541 $149,055
Pipeline construction
and services 10,733 826 44 38 74
Other 125 259 223 194 223
Total operating
revenues 184,480 161,935 177,097 159,773 149,352
OPERATING EXPENSES:
Cost of gas 98,475 90,478 105,832 91,252 81,996
Other operation expenses 37,417 24,584 24,133 23,204 23,114
Maintenance 5,513 4,967 4,436 3,695 3,405
Depreciation 7,833 7,018 6,671 6,389 6,088
Income taxes 5,800 3,955 4,541 5,159 5,296
Taxes other than income
taxes 11,182 9,982 10,852 10,110 9,740
Total operating
expenses 166,220 140,984 156,465 139,809 129,639
OPERATING INCOME 18,260 20,951 20,632 19,964 19,713
OTHER INCOME (DEDUCTIONS),
NET 1,726 355 111 (540) (173)
INTEREST CHARGES (1) (10,192) (15,422) (13,791) (12,886) (12,927)
INCOME FROM CONTINUING
OPERATIONS 9,794 5,884 6,952 6,538 6,613
INCOME (LOSS) WITH RESPECT
TO DISCONTINUED
OPERATIONS, NET OF
RELATED INCOME TAXES (2) (363) (3,834) 10,504 7,909 4,915
INCOME BEFORE SUBSIDIARY'S
PREFERRED STOCK
DIVIDENDS AND
EXTRAORDINARY LOSS 9,431 2,050 17,456 14,447 11,528
SUBSIDIARY'S PREFERRED
STOCK DIVIDENDS (1) 1,730 2,763 4,639 6,462 5,065
INCOME (LOSS) BEFORE
EXTRAORDINARY LOSS 7,701 (713) 12,817 7,985 6,463
EXTRAORDINARY LOSS (NET OF
RELATED TAX BENEFIT) (1,117) - - - -
NET INCOME (LOSS) $ 6,584 $ (713) $ 12,817 $ 7,985 $ 6,463
</TABLE>
See page 17 for an explanation of footnotes.
-15-
<PAGE>
<TABLE>
<CAPTION>
Year Ended December 31,
1996 1995 1994 1993 1992
(Thousands of Dollars, Except Per Share Amounts)
<S> <C> <C> <C> <C> <C>
COMMON STOCK INFORMATION:
Weighted average number
of shares outstanding in
thousands (3) 10,222 11,459 10,913 8,790 8,022
Earnings (loss) per share
of common stock: (3)
Continuing operations (1)$ .79 $ .27 $ .21 $ .01 $ .20
Discontinued operations (.04) (.33) .96 .90 .61
Net income (loss) before
premium on repurchase/
redemption of
subsidiary's preferred
stock and extraordinary
loss .75 (.06) 1.17 .91 .81
Premium on repurchase/
redemption of
subsidiary's preferred
stock (.13) - (.09) - -
Extraordinary loss (.11) - - - -
Earnings (loss) per share
of common stock $ .51 $ (.06) $ 1.08 $ .91 $ .81
Cash dividends per share
of common stock $ 1.10 $ 1.10 $ 1.10 $ 1.10 $ 1.10
CAPITALIZATION AT END
OF PERIOD:
Amounts -
Common shareholders'
investment $117,651 $162,739 $172,012 $165,775 $135,144
Preferred stock of PGE -
Not subject to mandatory
redemption, net 18,851 33,615 33,615 33,615 33,615
Subject to mandatory
redemption 739 1,680 1,760 31,840 41,920
Long-term debt 75,000 106,706 220,705 155,388 148,866
Total capitalization $212,241 $304,740 $428,092 $386,618 $359,545
Ratios -
Common shareholders'
investment 55.4% 53.4% 40.2% 42.9% 37.6%
Preferred stock of PGE -
Not subject to mandatory
redemption, net 8.9 11.0 7.8 8.7 9.3
Subject to mandatory
redemption 0.4 0.6 0.4 8.2 11.7
Long-term debt 35.3 35.0 51.6 40.2 41.4
Total 100.0% 100.0% 100.0% 100.0% 100.0%
See page 17 for an explanation of footnotes.
-16-
</TABLE>
<PAGE>
<TABLE>
<CAPTION>
<S> <C> <C> <C> <C> <C>
UTILITY PLANT AT END OF
PERIOD:
Total utility plant $319,205 $295,895 $284,080 $269,819 $256,663
Accumulated depreciation 79,783 76,882 74,408 70,954 65,318
Net utility plant $239,422 $219,013 $209,672 $198,865 $191,345
TOTAL ASSETS AT END OF
PERIOD:
Continuing operations $366,810 $319,968 $321,236 $318,057 $257,458
Discontinued operations,
net (4) - 204,250 203,196 193,002 183,702
Total $366,810 $524,218 $524,432 $511,059 $441,160
(1) None of the Company's interest charges and none of PGE's Preferred Stock
dividends was allocated to the discontinued operations through the February
15, 1996, date of disposition. Prior to that time interest charges
relating to indebtedness of PGE were allocated to the discontinued
operations based on the relationship of the gross water utility plant of
the discontinued operations to the total of PGE's gross gas and water
utility plant. This was the same method as was utilized by PGE and the
PPUC in establishing the revenue requirements of its utility operations.
(2) See Note 2 of the Notes to Consolidated Financial Statements in Item 8 of
this Form 10-K.
(3) Reflects a two-for-one stock split of the Company's common stock effective
March 20, 1997, as more fully discussed in Note 5 of the Notes to
Consolidated Financial Statements in Item 8 of this Form 10-K.
(4) Net of (i) liabilities assumed by Pennsylvania-American (ii) estimated
liability for income taxes on sale of discontinued operations, (iii) with
respect to the year ended December 31, 1995, the anticipated income from
the discontinued operations during the phase-out period for financial
statement purposes of April 1, 1995, through February 15, 1996, and (iv)
with respect to periods ended in 1994 and earlier years, other net assets
of the discontinued operations (which were written off as of March 31,
1995). See Note 2 of Notes to Consolidated Financial Statements included
in Item 8 of this Form 10-K.
-17-
</TABLE>
<PAGE>
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
RESTRUCTURING OF NATURAL GAS INDUSTRY
The Company's principal operating subsidiary, PG Energy Inc. ("PGE"), is a
regulated public utility engaged in the sale and distribution of natural gas
which accounted for approximately 87% of the Company's operating revenues in
1996. The natural gas industry, which historically has included producers,
interstate pipelines and local distribution companies ("LDCs"), is continuing to
undergo significant restructuring. The industry is rapidly progressing from a
highly regulated environment to one in which there is competition, customer
choice and only partial regulation. The same change is also beginning to occur
in the electric industry which competes with the natural gas industry for many
of the same energy uses.
The restructuring of the natural gas industry has already involved the
decontrol of the wellhead price of natural gas, and interstate pipelines have
been required by the Federal Energy Regulatory Commission ("FERC") to separate
the merchant function of selling natural gas from the transportation and storage
services they provide (frequently referred to as "unbundling") and to make those
services available to end users on the same terms as LDCs. These changes in the
operations of the interstate pipelines were designed to enhance competition and
maximize the benefits of wellhead price decontrol.
As a result of actions by FERC, the interstate pipelines now primarily
provide transportation and storage services, and LDCs, such as PGE, are
presently responsible for the procurement of competitively-priced gas supplies
and arranging for the appropriate transportation capacity and storage services
with the interstate pipelines. Additionally, in accordance with regulations
promulgated by the Pennsylvania Public Utility Commission ("PPUC"), PGE
currently offers transportation service to certain customers.
Prior to the unbundling of services by the interstate pipelines and those
services being made available to end users as well as LDCs, and until the PPUC
adopted regulations providing for the transportation of natural gas, PGE charged
all its customers bundled rates. These rates included a commodity charge based
on the cost, as approved by FERC, which PGE paid the pipelines for natural gas
delivered to the entry point on its distribution system. Except for the
approximately 500 customers currently receiving transportation service, PGE's
customers continue to be charged bundled rates as approved by the PPUC, which
include a commodity charge based on the costs prudently incurred by PGE for the
purchase of natural gas and for interstate pipeline transportation capacity and
storage services. Customers receiving transportation service, which accounted
for approximately 43% of PGE's total gas deliveries in 1996, are charged rates
approved by the PPUC, which exclude the commodity cost that is reflected in the
bundled rates charged to other customers.
In December, 1996, legislation was enacted in Pennsylvania which provides
all customers of electric utilities in the state with the right to choose the
generator of their electricity. This customer choice, which is intended to
increase competition and to lower costs for electricity, will be phased in over
a three-year period ending on January 1, 2001. Under this legislation, the
electric utilities in Pennsylvania will be required to unbundle generation
charges from the other charges included in their currently bundled rates and
customers will contract with qualified suppliers of their choosing, including
-18-
<PAGE>
the utility currently serving them, to purchase electric energy at nonregulated
rates. The electric utilities will continue to utilize their transmission
networks to distribute electricity to their customers regardless of supplier, a
function which will remain subject to rate regulation by the PPUC.
The Company and PGE believe that Pennsylvania may consider similar
legislation with respect to the natural gas industry in 1997. Such legislation
may require that PGE provide all of its customers with unbundled service over a
period of several years. While the rates for the transportation of natural gas
through PGE's distribution system and the storage services offered by PGE may
continue to be price regulated by the PPUC, the commodity cost of gas may not be
so regulated. Essentially, the transportation service which is now available to
a limited number of PGE's customers, would be extended to all its customers.
Customers would choose the supplier of their natural gas, which could be PGE,
based on nonregulated market prices and other considerations.
If Pennsylvania enacts legislation which permits all customers of LDCs to
choose their supplier of natural gas, PGE will be faced with significant
competition from other gas utilities and marketers for the sale of natural gas
to its customers. However, under current regulations of the PPUC, PGE does not
realize a profit or incur any loss with respect to the commodity cost of natural
gas. Moreover, PGE would not expect the legislation to result in the bypass of
its distribution system by any significant number of customers because of the
nature of its customer base and the cost of any such bypass. Additionally,
based on the recently-enacted electric industry legislation, PGE anticipates
that any transition costs (such as the negotiated buyout of contracts with
interstate pipelines, the recovery of deferred purchased gas costs or the
recovery of regulatory assets) it might incur as a result of legislation
providing for customer choice of natural gas suppliers would be recovered
through a nonbypassable customer charge. Accordingly, although it cannot be
certain, because the terms of such legislation have not been finalized and the
ultimate effect on PGE cannot be determined, PGE does not believe that the
enactment of legislation providing for customers to purchase their natural gas
from third parties would have any material adverse impact on its earnings or
financial condition despite the increased competition to which PGE would be
subject regarding the sale of natural gas to its customers.
EXPANSION OF NONREGULATED ACTIVITIES
The Company intends that PGE, along with its affiliates, will remain a
leading supplier of energy and energy-related products and services even if the
sale of natural gas to its customers is deregulated. PGE will actively market
the sale of natural gas, and possibly other forms of energy, to its customers on
a competitive, nonregulated basis and will continue to aggressively add
customers to its distribution system. Additionally, the Company plans to
further expand the activities of Pennsylvania Energy Resources, Inc. ("PERI"), a
nonregulated affiliate of PGE, which presently provides a broad array of energy
supply and energy management services, including the marketing and sale of
natural gas to commercial and industrial users in northeastern United States;
the sale of propane on both a retail and wholesale level in central and
northeastern Pennsylvania; the inspection, maintenance and servicing of
residential and small commercial gas-fired equipment; and through its
subsidiary, Keystone Pipeline Services, Inc. ("Keystone"), specialized pipeline
distribution services for utilities, including keyhole vacuum excavation, camera
inspection and bridge pipeline rehabilitation, as well as the installation of
mains and services for the natural gas, water and sewer industries. In
-19-
<PAGE>
addition, the Company, through its subsidiary Theta Land Corporation ("Theta"),
is presently initiating several residential and commercial development projects,
including a residential development located at the Montage Mountain Ski Resort
in Lackawanna County, known as "White Cliff at Montage," which will consist of
townhomes and single family dwellings and a development near Wilkes-Barre in
Luzerne County, known as "Laurel Run," which will consist of a motel,
restaurant, small strip shopping center and townhomes on Company-owned land.
Theta is also developing plans to conduct timber, sand and gravel operations on
the Company's land and to increase the value being realized from the Company's
extensive land holdings through a more active management of those resources.
DISCONTINUED OPERATIONS
Pursuant to an Asset Purchase Agreement dated April 26, 1995, as amended
(the "Agreement"), among the Company, PGE, American Water Works Company, Inc.
("American") and Pennsylvania-American Water Company ("Pennsylvania-American"),
a wholly-owned subsidiary of American, the Company and PGE sold substantially
all of the assets, properties and rights of PGE's water utility operations to
Pennsylvania-American on February 16, 1996. Under the terms of the Agreement,
Pennsylvania-American paid PGE $414.3 million consisting of $262.1 million in
cash and the assumption of $152.2 million of PGE's liabilities, including $141.0
million of its long-term debt. PGE continued to operate the water utility
business until February 16, 1996. The cash proceeds from the sale of
approximately $203.3 million, net of an estimated $58.8 million of income taxes,
were used by the Company and PGE to retire debt, to repurchase stock, for
construction expenditures and for other working capital purposes.
The sale price reflected a $6.5 million premium over the book value of the
assets being sold. However, after transaction costs and the net effect of other
items, the sale resulted in an after tax loss of approximately $6.2 million, net
of the income from the water operations during the phase-out period (which for
financial reporting purposes was April 1, 1995, through February 15, 1996).
In accordance with generally accepted accounting principles, the Company's
consolidated financial statements reflect PGE's water utility operations as
"discontinued operations" effective March 31, 1995, and the following sections
of Management's Discussion and Analysis generally relate only to the Company's
continuing operations. For additional information regarding the discontinued
operations, see Note 2 of the accompanying Notes to Consolidated Financial
Statements.
STOCK SPLIT
On February 19, 1997, the Board of Directors of the Company declared a two-
for-one split of the Company's Common Stock effective March 20, 1997, as more
fully discussed in Note 5 of the accompanying Notes to Consolidated Financial
Statements. All per share data included in this Item 7 has been restated to
reflect this two-for-one split.
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<PAGE>
RESULTS OF CONTINUING OPERATIONS
The following table expresses certain items in the Company's consolidated
statements of income as percentages of operating revenues for each of the
calendar years ended December 31, 1996, 1995 and 1994:
<TABLE>
<CAPTION>
Percentage of Operating Revenues
Year Ended December 31,
1996 1995 1994
<S> <C> <C> <C>
OPERATING REVENUES:
Gas sales and services..................... 94.1% 99.3% 99.9%
Pipeline construction and services......... 5.8 0.5 -
Other...................................... 0.1 0.2 0.1
Total operating revenues................. 100.0% 100.0% 100.0%
OPERATING EXPENSES:
Cost of gas................................ 53.4 55.9 59.8
Other operation expenses................... 20.3 15.2 13.6
Maintenance................................ 3.0 3.1 2.5
Depreciation............................... 4.2 4.3 3.8
Income taxes............................... 3.6 2.4 2.5
Taxes other than income taxes.............. 6.1 6.2 6.1
Total operating expenses................. 90.6 87.1 88.3
OPERATING INCOME............................. 9.4 12.9 11.7
OTHER INCOME, NET............................ 1.4 0.2 -
INTEREST CHARGES(1).......................... (5.5) (9.5) (7.8)
INCOME FROM CONTINUING OPERATIONS............ 5.3 3.6 3.9
INCOME (LOSS) WITH RESPECT TO DISCONTINUED
OPERATIONS................................. (0.2) (2.3) 5.9
INCOME BEFORE SUBSIDIARY'S PREFERRED
STOCK DIVIDENDS AND EXTRAORDINARY LOSS..... 5.1 1.3 9.8
SUBSIDIARY'S PREFERRED STOCK DIVIDENDS(1).... (0.9) (1.7) (2.6)
INCOME (LOSS) BEFORE EXTRAORDINARY LOSS...... 4.2 (0.4) 7.2
EXTRAORDINARY LOSS........................... (0.6) - -
NET INCOME (LOSS)............................ 3.6% (0.4)% 7.2%
(1) None of the Company's interest expense and none of the subsidiary's
preferred stock dividends was allocated to the discontinued operations.
o Year Ended December 31, 1996, Compared With Year Ended December 31, 1995
Operating Revenues. Operating revenues increased $22.5 million (13.9%) from
$161.9 million for 1995 to $184.5 million for 1996 largely as a result of $10.7
million of operating revenues relative to the pipeline construction and services
activities of Keystone, which was acquired in December, 1995, and a $4.9 million
increase in operating revenues relative to energy sales and services by PERI.
Also contributing to the increase in operating revenues was a higher level of
revenues attributable to PGE's gas sales and services which increased by $7.8
-21-
</TABLE>
<PAGE>
million, primarily as a result of a 1.5 billion cubic feet (6.8%) increase in
sales to residential and commercial heating customers. There was a 598 (9.9%)
increase in heating degree days from 6,029 (95.8% of normal) during 1995 to
6,627 (105.3% of normal) during 1996. The effects of the increased sales to
heating customers were partially offset by lower levels in the purchased gas
cost component of PGE's tariffs (the "gas cost rate"). See "-Rate Matters."
Operating Expenses. Operating expenses, including depreciation and income
taxes, increased $25.2 million (17.9%) from $141.0 million for 1995 to $166.2
million for 1996. As a percentage of operating revenues, total operating
expenses increased from 87.1% during 1995 to 90.6% during 1996.
The cost of gas increased $8.0 million (8.8%) from $90.5 million for 1995 to
$98.5 million for 1996 primarily because of a $4.1 million increase in the cost
of gas relative to PERI's gas sales and services and a $3.9 million increase
resulting from the aforementioned increase in sales by PGE to residential and
commercial heating customers, the effects of which were partially offset by
lower levels in PGE's gas cost rate (see "-Rate Matters").
Other than the cost of gas and income taxes, operating expenses increased by
$15.4 million (33.1%) from $46.6 million for 1995 to $61.9 million for 1996.
This increase was largely attributable to a $12.8 million (52.2%) increase in
other operation expenses, primarily as a result of $9.5 million of expenses
relative to Keystone's pipeline construction and services activities, and a $2.6
million (11.7%) increase in expenses with respect to PGE's operations, which was
principally the result of higher payroll and payroll-related costs. Payroll and
payroll-related costs increased largely because of charges, which had formerly
been allocated to PGE's discontinued operations, now being absorbed by its
continuing operations. Also contributing to the higher operating expenses was
an $815,000 (11.6%) increase in depreciation expense as a result of $170,000 of
depreciation relative to Keystone and $641,000 of depreciation attributable to
additions to PGE's utility plant.
Income taxes increased $1.8 million from $4.0 million in 1995 to $5.8
million in 1996 due to an increase in income before income taxes (for this
purpose, operating income net of interest charges).
Operating Income. As a result of the above, operating income decreased by
$2.7 million (12.9%) from $21.0 million for 1995 to $18.3 million for 1996 and
decreased as a percentage of total operating revenues for such periods from
12.9% in 1995 to 9.4% in 1996, primarily because of the higher level of
operating expenses.
Other Income, Net. Other income, net increased $1.4 million from $355,000
for 1995 to $1.7 million for 1996 largely as a result of investment income
totaling $2.5 million relative to the temporary investment of a portion of the
proceeds from the sale of PGE's regulated water utility operations. The effects
of this increase were partially offset by charges of $548,000 relative to the
sale and abandonment of PGE's interest in certain gas rights and properties in
western Pennsylvania.
Interest Charges. Interest charges decreased by $5.2 million (33.9%) from
$15.4 million for 1995 to $10.2 million for 1996. This decrease was largely
attributable to the lower level of indebtedness resulting from the repayment of
PGE's $50.0 million term loan and all of its then outstanding bank borrowings on
February 16, 1996, with proceeds from the sale of its regulated water utility
-22-
<PAGE>
operations on such date and the Company's defeasance of its 10.125% Senior Notes
on September 30, 1996.
Income From Continuing Operations. Income from continuing operations
increased $3.9 million (66.5%) from $5.9 million for 1995 to $9.8 million for
1996. This increase was largely the result of the matters discussed above,
principally the increase in operating revenues and other income, net and the
decrease in interest charges, the effects of which were partially offset by
increased operating expenses.
Subsidiary's Preferred Stock Dividends. Dividends on preferred stock
decreased $1.0 million (37.4%) from $2.8 million for 1995 to $1.7 million for
1996, primarily as a result of the repurchase by PGE in 1996 of 134,359 shares
of its 9% cumulative preferred stock, 9,408 shares of its 5.75% cumulative
preferred stock and 20,330 shares of its 4.10% cumulative preferred stock,
largely during the second quarter of the year.
Income (Loss) Before Extraordinary Loss. The increase in income before
extraordinary loss of $8.4 million from a loss of $713,000 for 1995 to income of
$7.7 million for 1996 was largely the result of the increase in income from
continuing operations and the lower level of dividends on subsidiary's preferred
stock, as discussed above, and the reduction of $3.5 million, from $3.8 million
to $363,000, in the loss with respect to discontinued operations.
Extraordinary Loss. On September 30, 1996, the Company defeased the $28.7
million outstanding principal amount of its 10.125% Senior Notes, due June 15,
1999, and recorded an extraordinary loss of $1.1 million ($1.6 million, net of
$575,000 of related income tax benefit). The loss on the defeasance represents
the interest expense on the Senior Notes from the date of defeasance through
June 15, 1997, the date on which the Senior Notes will be redeemed, plus the
writeoff of the unamortized balance of issuance expenses related to the Senior
Notes, less (i) the interest income that will be earned on the funds that were
deposited with the Trustee for the Senior Notes in connection with their
defeasance and (ii) the related income tax benefit.
Net Income (Loss). The increase in net income of $7.3 million from a loss
of $713,000 for 1995, to income of $6.6 million for 1996, as well as the
increase in earnings per share of common stock of $.57 from a loss of $.06 per
share for 1995 to earnings of $.51 per share for 1996 (after a $.13 per share
charge for the premium on repurchase of subsidiary's preferred stock and an $.11
per share charge relative to the extraordinary loss), were the result of the
higher income from continuing operations and the reduced dividends on
subsidiary's preferred stock, as discussed above, and the decrease of $.29 per
share, from $.33 per share for 1995 to $.04 per share for 1996, in the loss with
respect to discontinued operations.
o Year Ended December 31, 1995, Compared With Year Ended December 31, 1994
Operating Revenues. Operating revenues decreased $15.2 million (8.6%) from
$177.1 million for 1994 to $161.9 million for 1995. This decrease was primarily
the result of a reduction in PGE's gas cost rate effective May 16, 1995. See "-
Rate Matters." Also contributing to the decrease in revenues was the switching
of certain of PGE's commercial and industrial customers from sales to
transportation service and a 179 million cubic feet (0.8%) decrease in sales by
PGE to residential and commercial heating customers, caused by a 133 (2.2%)
decrease in heating degree days. There were 6,029 heating degree days (95.8% of
normal) during 1995 compared to 6,162 (97.9% of normal) during 1994.
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<PAGE>
Operating Expenses. Operating expenses, including depreciation and income
taxes, decreased $15.5 million (9.9%) from $156.5 million for 1994 to $141.0
million for 1995. As a percentage of operating revenues, total operating
expenses decreased from 88.3% during 1994 to 87.1% during 1995.
The cost of gas decreased $15.4 million (14.5%) from $105.8 million for 1994
to $90.5 million for 1995, primarily because of the aforementioned reduction in
PGE's gas cost rate effective May 16, 1995. See "-Rate Matters." Also
contributing to the decrease was the reduced consumption by residential and
commercial heating customers.
Other than the cost of gas and income taxes, operating expenses increased
$459,000 (1.0%) from $46.1 million for 1994 to $46.6 million for 1995. This
increase was attributable to a $531,000 (12.0%) increase in maintenance
expenses, principally as a result of charges relative to the maintenance of gas
valves, a $451,000 (1.9%) increase in other operation expenses and a $347,000
(5.2%) increase in depreciation expense as a result of additions to utility
plant. The effect of the increase was partially offset by an $870,000 (8.0%)
decrease in taxes other than income taxes, primarily because of a decrease in
gross receipts tax as a result of the lower level of operating revenues.
Income taxes decreased $586,000 (12.9%) from $4.5 million in 1994 to $4.0
million in 1995 due to a decrease in income before income taxes (for this
purpose, operating income net of interest charges) and a reduction in the
Pennsylvania corporate net income tax rate.
Operating Income. As a result of the above, total operating income
increased $319,000 (1.5%) from $20.6 million in 1994 to $21.0 million in 1995
and increased as a percentage of total operating revenues for such periods from
11.7% in 1994 to 12.9% in 1995.
Other Income, Net. Other income, net increased $244,000 from $111,000 in
1994 to $355,000 in 1995, primarily as a result of a $227,000 write-off of
expired advances related to income taxes and a $226,000 decrease in amortization
of preferred stock issuance costs.
Interest Charges. Interest charges increased by $1.6 million (11.8%) from
$13.8 million for 1994 to $15.4 million for 1995. This increase was largely
attributable to interest on overcollections of purchased gas costs and increased
borrowings primarily as a result of the Company's May 31, 1994, term loan
agreement. None of the interest expense on borrowings under the Company's term
loan agreement or the Company's senior notes was allocated to the discontinued
operations.
Income From Continuing Operations. Income from continuing operations
decreased $1.1 million (15.4%) from $7.0 million for 1994 to $5.9 million for
1995. This decrease was largely the result of the matters discussed above,
principally the decrease in operating margin resulting from the lower level of
sales by PGE to residential and commercial heating customers. The effect of the
decreased operating margin was partially offset by the lower levels of taxes.
Subsidiary's Preferred Stock Dividends. Dividends on preferred stock
decreased $1.9 million (40.4%) from $4.6 million for 1994 to $2.8 million for
1995, as a result of the redemption by PGE on May 31, 1994, of 150,000 shares
($15.0 million) of its 9.50% cumulative preferred stock, $100 par value, and on
December 16, 1994, of 150,000 shares ($15.0 million) of its 8.90% cumulative
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<PAGE>
preferred stock, $100 par value. No dividends on preferred stock were allocated
to the discontinued operations.
Net Income (Loss). The decrease in net income (loss) of $13.5 million from
income of $12.8 million for 1994 to a loss of $713,000 for 1995, as well as the
decrease in earnings per share of common stock of $1.14 from earnings of $1.08
per share for 1994 (after an $.09 per share charge for the premium on redemption
of subsidiary's preferred stock) to a loss of $.06 per share for 1995, were
largely the result of the estimated loss (equivalent to $.52 per share) on the
sale of PGE's water utility operations, as discussed above. Also contributing
to the decreases in net income and earnings per share for 1995 was the lower
income from continuing operations. The effects of these factors were partially
offset by the reduced dividends on subsidiary's preferred stock and, in the case
of earnings per share, the absence of any premium on the redemption of
subsidiary's preferred stock.
RATE MATTERS
Rate Increase. On May 24, 1996, PGE filed an application with the PPUC
seeking an increase in its base gas rates, designed to produce $14.1 million in
additional annual revenue, to be effective July 23, 1996. On June 20, 1996, the
PPUC suspended this rate increase for seven months (until February 23, 1997) in
order to investigate the reasonableness of the proposed rates. On November 7,
1996, PGE and certain parties filing objections to the rate increase request
filed a Settlement Agreement and Joint Petition for Settlement of Rate
Investigation (the "Settlement Petition") with the Administrative Law Judge
assigned to conduct the investigation of the rate increase request. This
Settlement Petition provided for an overall 5.3% rate increase that was designed
to produce $7.5 million of additional annual revenue. By Order adopted December
19, 1996, the PPUC approved the Settlement Petition effective January 15, 1997.
Under the terms of the Settlement Petition, the billing for the impact of the
rate increase relative to PGE's residential heating customers (which it is
estimated will total $6.6 million on an annual basis) is being deferred, without
carrying charges, until July, 1997.
Gas Cost Adjustments. The provisions of the Pennsylvania Public Utility
Code require that the tariffs of LDCs such as PGE, be adjusted on an annual
basis, and on an interim basis when circumstances dictate, to reflect changes in
their purchased gas costs. The procedure includes a process for the
reconciliation of actual gas costs incurred and actual revenues received and
also provides for the refund of any overcollections, plus interest thereon, or
the recoupment of any undercollections of gas costs. The procedure is limited
to purchased gas costs, to the exclusion of other rate matters, and requires a
formal evidentiary proceeding conducted by the PPUC, the submission of specific
information regarding gas procurement practices and specific findings of fact by
the PPUC regarding the "least cost fuel procurement" policies of the utility.
Effective September 14, 1995, the PPUC adopted regulations that provide for
the quarterly adjustment of the annual purchased gas cost rate of larger LDCs,
including PGE. Such quarterly adjustments are allowed when the actual costs
vary from the costs reflected in the respective company's tariffs by 2% or more.
Except for reducing the amount of any over or undercollections of gas costs,
these regulations will not have any material effect on PGE's financial position
or results of operations, and PGE is still required to file an annual purchased
gas cost rate.
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<PAGE>
In accordance with these annual and quarterly procedures, PGE has been
permitted to make the following changes since January 1, 1994, to the gas costs
contained in its gas tariff rates:
[CAPTION]
Change in Calculated
Effective Rate per MCF Increase (Decrease)
Date From To in Annual Revenue
[S] [C] [C] [C]
March 1, 1997 $4.18 $4.49 $ 8,300,000
December 1, 1996 3.01 4.18 32,400,000
September 1, 1996 2.88 3.01 3,600,000
June 1, 1996 2.75 2.88 3,400,000
December 1, 1995 2.42 2.75 9,600,000
May 15, 1995 3.68 2.42 (8,200,000)*
December 1, 1994 3.74 3.68 (1,800,000)
* Represents estimated reduction in revenue for the period May 15, 1995,
through November 30, 1995.
The changes in gas rates on account of purchased gas costs have no effect on
PGE's earnings since the change in revenue is offset by a corresponding change
in the cost of gas.
Recovery of FERC Order 636 Transition Costs. On October 15, 1993, the PPUC
adopted an annual purchased gas cost ("PGC") order (the "PGC Order") regarding
recovery of Federal Energy Regulatory Commission ("FERC") Order 636 transition
costs. The PGC Order stated that Account 191 and New Facility Costs (the "Gas
Transition Costs") are subject to recovery through the annual PGC rate filings
made with the PPUC by PGE and other larger LDCs. The PGC Order also indicated
that while Gas Supply Realignment and Stranded Costs (the "Non-Gas Transition
Costs") are not natural gas costs eligible for recovery under the PGC rate
filing mechanism, such costs are subject to full recovery by LDCs through the
filing of a tariff pursuant to either the existing surcharge or base rate
provisions of the Code. The PGC Order further stated that all such filings
would be evaluated on a case-by-case basis.
PGE was billed a total of $1.3 million of Gas Transition Costs by its
interstate pipelines. Of this amount, $857,000 was recovered by PGE over a
twelve-month period ended January 31, 1995, through an increase in its PGC rate,
$252,000 was recovered by PGE in its annual PGC rate that the PPUC approved
effective December 1, 1995, and the remaining $213,000 is being recovered by
PGE in its PGC rate that was effective December 1, 1996.
By Order of the PPUC entered August 26, 1994, PGE began recovering the Non-
Gas Transition Costs that it estimates it will ultimately be billed pursuant to
FERC Order 636 through the billing of a surcharge to its customers effective
September 12, 1994. It is currently estimated that $10.1 million of Non-Gas
Transition Costs will be billed to PGE, generally over a six-year period
extending through January 1, 1999, of which $8.0 million had been billed to PGE
and $7.5 million had been recovered from its customers as of December 31, 1996.
PGE has recorded the estimated Non-Gas Transition Costs that remain to be billed
to it and the amounts remaining to be recovered from its customers.
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<PAGE>
Effects of Inflation. When utility property reaches the end of its useful
life and must be replaced, PGE will incur replacement costs in amounts that due
to the effects of inflation would materially exceed either the original cost or
the accrued depreciation of such property as reflected on its books of account.
However, the cost of such replacement property would be includable in PGE's rate
base, and PGE would be entitled to recover depreciation expense and earn a
return thereon, to the extent that its investment in such property was prudently
incurred and the property is used and useful in furnishing public utility
service.
LIQUIDITY AND CAPITAL RESOURCES
Sale of Water Utility Operations
On February 16, 1996, PGE sold its regulated water operations and certain
related assets to Pennsylvania-American for $414.3 million, consisting of $262.1
million in cash and the assumption of $152.2 million of PGE's liabilities,
including $141.0 million of its long-term debt. The Company and PGE used the
$203.3 million of cash proceeds from the sale, after an estimated $58.8 million
of federal and state income taxes (of which $44.6 million had been paid as of
December 31, 1996), to retire debt, to repurchase stock, for construction
expenditures and for other working capital purposes. In this regard, PGE repaid
its $50.0 million term loan due 1996 and all of its then outstanding bank
borrowings on February 16, 1996, and the Company and PGE temporarily invested
the balance of the proceeds. A portion of these proceeds were subsequently used
by the Company to repurchase 2,025,928 shares of its common stock during 1996
for an aggregate consideration of $39.8 million, of which 1,781,204 shares were
acquired in April pursuant to a self tender offer and 241,874 shares were
acquired from time to time through open market transactions and an oddlot
buyback program. Also during 1996 and using proceeds from the sale, PGE
repurchased 134,359 shares of its 9% cumulative preferred stock for an aggregate
consideration of $14.5 million and 20,330 shares of its 4.10% cumulative
preferred stock for an aggregate consideration of $1.0 million, largely pursuant
to self tender offers conducted during March and April, 1996. Additionally, on
June 17, 1996, PGE repurchased 9,408 shares of its 5.75% cumulative preferred
stock (including 800 shares redeemed in accordance with annual sinking fund
provisions) for an aggregate consideration of $838,000. As of December 31,
1996, the only unexpended proceeds from the sale were $31.4 million which the
Company had temporarily lent to PGE for its working capital needs.
Liquidity
The primary capital needs of the Company continue to be the funding of PGE's
construction program and the seasonal funding of PGE's gas purchases and
increases in its customer accounts receivable. PGE's revenues are highly
seasonal and weather-sensitive, with approximately 75% of its revenues normally
being realized in the first and fourth quarters of the calendar year when the
temperatures in its service area are the coldest.
Additionally, as the Company's nonregulated activities expand, capital will
be required for those activities, especially the residential and commercial real
estate development projects that are planned for certain Company-owned land.
The projects that are currently planned by the Company are in the initial
planning and design phases, and the amount and type of funding that those
projects will require has not yet been finalized. However, it is currently
anticipated that approximately $13.1 million will be expended with respect to
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<PAGE>
those projects in 1997 and that such expenditures will be funded by a
combination of capital provided by the Company, bank borrowings and other debt
financing.
The cash flow from PGE's operations is generally sufficient to fund a
portion of its construction expenditures. However, to the extent external
financing is required, it is the practice of PGE to use bank borrowings to fund
such expenditures, pending the periodic issuance of stock and long-term debt.
Bank borrowings are also used by PGE for the seasonal funding of its gas
purchases and increases in customer accounts receivable.
With the repayment of its term loan and all its bank borrowings on February
16, 1996, and the availability of cash proceeds from the sale of its regulated
water operations, PGE terminated its $60.0 million bank credit agreement.
However, in order to finance construction expenditures and to meet its seasonal
borrowing requirements, PGE has since made arrangements for a total of $65.5
million of unsecured revolving bank credit, which is deemed adequate for its
immediate needs. Specifically, PGE currently has six bank lines of credit with
an aggregate borrowing capacity of $65.5 million which provide for borrowings at
interest rates generally less than prime and which mature during mid-1997. As
of March 1, 1997, PGE had $27.2 million of borrowings outstanding under these
bank lines of credit.
The Company believes that PGE will be able to raise in a timely manner such
funds as are required for its future construction expenditures, refinancings and
other working capital requirements. Likewise, the Company believes that its
nonregulated subsidiaries will be able to raise such funds as are required for
their needs, including that required for the residential and commercial real
estate development that is planned.
Long-Term Debt and Capital Stock Financings
Both the Company and its subsidiaries, particularly PGE, periodically engage
in long-term debt and capital stock financings in order to obtain funds required
for construction expenditures, the refinancing of existing debt and various
working capital purposes. Set forth below is a summary of such financings
consummated since the beginning of 1995, exclusive of interim bank borrowings
and indebtedness that was assumed by Pennsylvania-American in connection with
its purchase of PGE's water utility operations.
On July 28, 1994, the Company implemented a Customer Stock Purchase Plan
(the "Customer Plan") which provided the residential customers of PGE with a
method of purchasing newly-issued shares of the Company's common stock at a 5%
discount from the market price. Under the terms of the Customer Plan, 176,462
shares ($2.4 million) and 119,074 shares ($1.7 million) of the Company's common
stock were issued in 1995 and 1994, respectively. The proceeds from the
issuance of shares through the Customer Plan were used by the Company to
purchase PGE common stock. Effective May 9, 1995, the Company suspended the
Customer Plan because of the significant reduction in its capital requirements
resulting from the sale of PGE's water utility operations to Pennsylvania-
American.
The Company also obtains external funds from the sale of its common stock
through its Dividend Reinvestment and Stock Purchase Plan (the "DRP"), its 1992
Stock Option Plan and its Employees' Savings Plan. However, from June 14, 1996,
through December 31, 1996, the Company temporarily suspended the sale of newly-
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<PAGE>
issued stock to both the DRP and Employees' Savings Plan as a result of the
proceeds received from the sale of PGE's water utility operations, and during
that period the two plans obtained shares of Company common stock for
participants through open market purchases. Effective January 1, 1997, the
Company resumed selling newly-issued stock to both the DRP and Employees'
Savings Plan.
Through the DRP, holders of shares of the Company's common stock may
reinvest cash dividends and/or make cash investments in common stock of the
Company. Under the DRP, 17,664 shares ($340,000), 232,610 shares ($3.3
million), and 124,542 shares ($1.8 million) of common stock were issued during
1996, 1995 and 1994, respectively. The DRP was amended on May 5, 1994, to
provide the Company's shareholders with a method of reinvesting cash dividends
and making cash investments to purchase newly-issued shares of the Company's
common stock at a 5% discount from the market price. Prior to such amendment,
cash dividends were reinvested at 100% of the market price in newly-issued
shares and cash investments were used to purchase shares of the Company's common
stock on the open market. Effective May 9, 1995, the Company suspended the cash
investment feature of the DRP and the 5% discount from the market price on the
reinvestment of dividends under the DRP because of the significant reduction in
its capital requirements resulting from the sale of PGE's water utility
operations to Pennsylvania-American. The cash investment feature was, however,
reinstated effective June 1, 1996.
Under the Company's Employees' Savings Plan (a section 401(k) plan) which
became effective January 1, 1992, the Company issued an additional 10,198 shares
($195,000) in 1996, 38,936 shares ($628,000) in 1995 and 36,200 shares
($540,000) in 1994. Additionally, under the Company's 1992 Stock Option Plan
37,400 shares ($561,000) and 9,600 shares ($144,000) were issued in 1996 and
1995, respectively.
On October 12, 1995, PGE borrowed $50.0 million under a term loan agreement.
The proceeds from the term loan, along with other funds provided by PGE, were
utilized on October 13, 1995, to redeem the $50.0 million principal amount of
PGE's 9.57% Series First Mortgage Bonds due September 1, 1996, in connection
with the then-pending sale of PGE's water utility operations to Pennsylvania-
American. PGE repaid its $50.0 million term loan on February 16, 1996, with
proceeds from the sale of its water utility operations to Pennsylvania-American.
On December 7, 1995, PERI borrowed $2.0 million pursuant to a five-year term
loan agreement. PERI used the proceeds it so received, along with an equity
investment from the Company, to acquire all of the outstanding stock of Keystone
(formerly known as Ford, Bacon & Davis Sealants, Inc.) from Ford, Bacon & Davis
Companies, Inc., a wholly-owned subsidiary of Deutsche Babcock Technologies,
Inc. On May 31, 1996, PERI repaid all principal amounts outstanding under the
loan with an advance it received from the Company.
Capital Expenditures and Related Financings
Capital expenditures totaled $30.5 million during 1996, including $29.2
million of expenditures for the construction of utility plant. During 1995 and
1994, respectively, expenditures for the construction of utility plant totaled
$21.1 million and $19.6 million. Such expenditures were financed with
internally-generated funds and bank borrowings, pending the periodic issuance of
stock and long-term debt.
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<PAGE>
The Company estimates that its capital expenditures will total $45.4 million
during 1997, consisting of $27.9 million relative to utility plant and $17.5
million with respect to the Company's nonregulated activities, including $13.1
million for residential and commercial real estate development. Capital
expenditures are currently expected to range from $35.0-40.0 million in each of
the years 1998 and 1999, of which $25.0-30.0 million will involve utility plant
and the balance will relate to the Company's nonregulated activities, primarily
residential and commercial real estate development projects. It is anticipated
that such capital expenditures will be financed with internally generated funds
and bank borrowings, and to the extent necessary by the periodic issuance of
stock and long-term debt.
Current Maturities of Long-Term Debt and Preferred Stock
As of December 31, 1996, $38.7 million of PGE's long-term debt, and $115,000
of PGE's preferred stock was required to be repaid within twelve months.
On September 30, 1996, the Company defeased the $28.7 million outstanding
principal amount of its 10.125% Senior Notes, due June 15, 1999 (the "Senior
Notes"). Specifically, on that date, the Company deposited $29.9 million with
the trustee for the Senior Notes, which will be used, together with interest
earned on the funds so deposited, to pay the Company's interest and principal
obligations through June 15, 1997, the date on which the Senior Notes will be
redeemed. The deposit of such funds acted to discharge all of the Company's
obligations with respect to the Senior Notes. Of the $29.9 million required to
defease the Senior Notes, $17.2 million was obtained through the liquidation of
the Company's temporary cash investments and $12.7 million was obtained through
the repayment of loans that had been made by the Company to PGE.
Forward-Looking Statements
Certain statements made above relating to plans, conditions, objectives and
economic performance go beyond historical information and may provide an
indication of future results. To that extent, they are forward-looking
statements within the meaning of Section 21E of the Securities Exchange Act of
1934, and each is subject to factors that could cause actual results to differ
from those in the forward-looking statement, such as the nature of Pennsylvania
legislation restructuring the natural gas industry and general economic
conditions and uncertainties relating to new projects like the residential and
commercial development projects on Company-owned land.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The consolidated financial statements of the Company and its subsidiaries
and the report of independent public accountants thereon are presented on pages
31 through 57 of this Form 10-K. All per share data included in this Item 8 has
been restated to reflect the two-for-one split of the Company's Common Stock
effective March 20, 1997, as more fully discussed in Note 5 of the Notes to
Consolidated Financial Statements contained herein.
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<PAGE>
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To Pennsylvania Enterprises, Inc.:
We have audited the accompanying consolidated balance sheets and consolidated
statements of capitalization of Pennsylvania Enterprises, Inc. (a Pennsylvania
corporation) and subsidiaries (the "Company") as of December 31, 1996 and 1995,
and the related consolidated statements of income, common shareholders'
investment, and cash flows for each of the three years in the period ended
December 31, 1996. These consolidated financial statements are the
responsibility of the Company's management. Our responsibility is to express an
opinion on these consolidated financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the consolidated financial statements are
free of material misstatement. An audit includes examining, on a test basis,
evidence supporting the amounts and disclosures in the consolidated 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 provide a
reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present
fairly, in all material respects, the financial position of Pennsylvania
Enterprises, Inc. and subsidiaries as of December 31, 1996 and 1995, and the
results of their operations and their cash flows for each of the three years in
the period ended December 31, 1996 in conformity with generally accepted
accounting principles.
Our audit was made for the purpose of forming an opinion on the basic
consolidated financial statements taken as a whole. Supplemental Schedule II,
Valuation and Qualifying Accounts for the three-year period ended December 31,
1996 (see index of financial statements) is presented for purposes of complying
with the Securities and Exchange Commission's rules and is not part of the basic
consolidated financial statements. This schedule has been subject to the
auditing procedures applied in the audit of the basic consolidated financial
statements and, in our opinion, fairly states in all material respects the
financial data required to be set forth therein in relation to the basic
consolidated financial statements taken as a whole.
ARTHUR ANDERSEN LLP
New York, N.Y.
February 19, 1997
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<PAGE>
PENNSYLVANIA ENTERPRISES, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
<TABLE>
<CAPTION>
December 31,
1996 1995
(Thousands of Dollars)
ASSETS
<S> <C> <C>
UTILITY PLANT:
At original cost $319,205 $295,895
Accumulated depreciation (79,783) (76,882)
239,422 219,013
OTHER PROPERTY AND INVESTMENTS:
Nonutility property and equipment 12,502 11,553
Accumulated depreciation (4,674) (5,394)
Other 1,720 983
9,548 7,142
CURRENT ASSETS:
Cash and cash equivalents 1,126 629
Accounts receivable -
Customers 22,464 21,066
Others 565 815
Reserve for uncollectible accounts (1,233) (788)
Unbilled revenues 12,966 10,319
Materials and supplies, at average cost 2,865 2,876
Gas held by suppliers, at average cost 20,265 15,140
Natural gas transition costs collectible 2,525 4,612
Deferred cost of gas and supplier refunds, net 19,316 -
Prepaid expenses and other 1,438 3,486
82,297 58,155
DEFERRED CHARGES:
Regulatory assets -
Deferred taxes collectible 29,771 30,015
Other 4,274 3,013
Unamortized debt expense 1,498 2,630
35,543 35,658
NET ASSETS OF DISCONTINUED OPERATIONS (Note 2) - 204,250
TOTAL ASSETS $366,810 $524,218
The accompanying notes are an integral part of the consolidated financial statements.
</TABLE>
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<PAGE>
PENNSYLVANIA ENTERPRISES, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
<TABLE>
<CAPTION>
December 31,
1996 1995
(Thousands of Dollars)
CAPITALIZATION AND LIABILITIES
<S> <C> <C>
CAPITALIZATION (see accompanying statements):
Common shareholders' investment (Notes 5 and 8) $117,651 $162,739
Preferred stock of PGE (Note 6) -
Not subject to mandatory redemption, net 18,851 33,615
Subject to mandatory redemption 739 1,680
Long-term debt (Note 7) 75,000 106,706
212,241 304,740
CURRENT LIABILITIES:
Current portion of long-term debt (Notes 7 and 9) 38,721 116,001
Preferred stock subject to repurchase or mandatory
redemption (Note 6) 115 80
Notes payable (Note 9) 10,000 10,180
Accounts payable 19,945 18,531
Deferred cost of gas and supplier refunds, net - 434
Accrued general business and realty taxes 2,350 1,493
Accrued income taxes 14,525 526
Accrued interest 1,243 2,307
Accrued natural gas transition costs (Note 3) 2,095 2,278
Other 3,904 3,534
92,898 155,364
DEFERRED CREDITS:
Deferred income taxes 49,270 48,835
Accrued natural gas transition costs (Note 3) - 1,144
Unamortized investment tax credits 4,767 4,938
Operating reserves 3,086 3,709
Other 4,548 5,488
61,671 64,114
COMMITMENTS AND CONTINGENCIES (Notes 11 and 12)
TOTAL CAPITALIZATION AND LIABILITIES $366,810 $524,218
The accompanying notes are an integral part of the consolidated financial statements.
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</TABLE>
<PAGE>
<TABLE>
<CAPTION>
PENNSYLVANIA ENTERPRISES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
Year Ended December 31,
1996 1995 1994
(Thousands of Dollars)
<S> <C> <C> <C>
OPERATING REVENUES:
Gas sales and services $ 173,622 $ 160,850 $ 176,830
Pipeline construction and services 10,733 826 44
Other 125 259 223
Total operating revenues 184,480 161,935 177,097
OPERATING EXPENSES:
Cost of gas 98,475 90,478 105,832
Other operation expenses 37,417 24,584 24,133
Maintenance 5,513 4,967 4,436
Depreciation 7,833 7,018 6,671
Income taxes 5,800 3,955 4,541
Taxes other than income taxes 11,182 9,982 10,852
Total operating expenses 166,220 140,984 156,465
OPERATING INCOME 18,260 20,951 20,632
OTHER INCOME, NET (Note 4) 1,726 355 111
INCOME BEFORE INTEREST CHARGES 19,986 21,306 20,743
INTEREST CHARGES:
Interest on long-term debt 9,609 13,672 12,589
Other interest 760 1,844 1,223
Allowance for borrowed funds used
during construction (177) (94) (21)
Total interest charges 10,192 15,422 13,791
INCOME FROM CONTINUING OPERATIONS 9,794 5,884 6,952
INCOME (LOSS) WITH RESPECT TO DISCONTINUED
OPERATIONS (Note 2) (363) (3,834) 10,504
INCOME BEFORE SUBSIDIARY'S PREFERRED
STOCK DIVIDENDS 9,431 2,050 17,456
SUBSIDIARY'S PREFERRED STOCK DIVIDENDS 1,730 2,763 4,639
INCOME (LOSS) BEFORE EXTRAORDINARY LOSS 7,701 (713) 12,817
EXTRAORDINARY LOSS (NET OF TAX BENEFIT
OF $575,000) (Note 7) (1,117) - -
NET INCOME (LOSS) $ 6,584 $ (713) $ 12,817
COMMON STOCK: (Note 5)
Earnings (loss) per share of common stock:
Continuing operations $ .79 $ .27 $ .21
Discontinued operations (.04) (.33) .96
Net income (loss) before premium on
repurchase/redemption of subsidiary's
preferred stock and extraordinary loss .75 (.06) 1.17
Premium on repurchase/redemption of
subsidiary's preferred stock (.13) - (.09)
Extraordinary loss (.11) - -
Earnings (loss) per share of common stock $ .51 $ (.06) $ 1.08
Weighted average number of shares outstanding 10,222,002 11,458,872 10,913,136
The accompanying notes are an integral part of the consolidated financial statements.
</TABLE>
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<PAGE>
PENNSYLVANIA ENTERPRISES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
<TABLE>
<CAPTION>
Year Ended December 31,
1996 1995 1994
(Thousands of Dollars)
<S> <C> <C> <C>
CASH FLOW FROM OPERATING ACTIVITIES:
Income from continuing operations, net of
subsidiary's preferred stock dividends $ 8,064 $ 3,121 $ 2,313
Effects of noncash charges to income -
Depreciation 7,896 7,018 6,693
Deferred income taxes, net 2,104 (251) 752
Provisions for self insurance 1,042 2,652 1,030
Extraordinary loss, net of tax benefit (1,117) - -
Other, net 2,335 5,572 3,074
Changes in working capital, exclusive of cash
and current portion of long-term debt -
Receivables and accrued utility revenues (3,350) (219) 1,435
Gas held by suppliers (5,125) 4,885 6,625
Accounts payable 2,057 321 (4,375)
Deferred cost of gas and supplier refunds, net (18,493) 5,715 5,784
Other current assets and liabilities, net 2,235 (6,509) (763)
Other operating items, net (5,458) 2,628 (6,588)
Net cash provided by (used for) continuing
operations (7,810) 24,933 15,980
Net cash provided by (used for) discontinued
operations (45,173) 3,764 552
Net cash provided by (used for) operating
activities (52,983) 28,697 16,532
CASH FLOW FROM INVESTING ACTIVITIES:
Additions to utility plant (29,312) (20,615) (16,960)
Proceeds from the sale of discontinued operations 261,752 - -
Acquisition of nonregulated business - (3,169) -
Other, net (1,803) (4,934) 1,098
Net cash provided by (used for) investing
activities 230,637 (28,718) (15,862)
CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock 1,291 4,045 3,887
Repurchase of common stock (40,452) - -
Common stock subscribed, net - - 2,515
Repurchase/redemption of preferred stock of PGE (15,670) (80) (30,080)
Dividends on common stock (11,174) (12,605) (12,002)
Issuance of long-term debt - 52,000 50,000
Repayment of long-term debt (81,906) (53,535) (31,055)
Net increase (decrease) in bank borrowings (27,903) 10,500 15,370
Other, net (1,343) (5) (1,724)
Net cash provided by (used for) financing
activities (177,157) 320 (3,089)
NET INCREASE (DECREASE) IN CASH AND CASH
EQUIVALENTS 497 299 (2,419)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR 629 330 2,749
CASH AND CASH EQUIVALENTS AT END OF YEAR $ 1,126 $ 629 $ 330
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:
Cash paid during the year for:
Interest (net of amount capitalized) $ 10,423 $ 27,951 $ 24,622
Income taxes $ 46,605 $ 8,748 $ 7,460
The accompanying notes are an integral part of the consolidated financial statements.
</TABLE>
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<PAGE>
PENNSYLVANIA ENTERPRISES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CAPITALIZATION
<TABLE>
<CAPTION>
December 31,
1996 1995
(Thousands of Dollars)
<S> <C> <C>
COMMON SHAREHOLDERS' INVESTMENT (Notes 5 and 8):
Common stock, no par value
(stated value $5 per share)
Authorized - 30,000,000 shares
Outstanding - 9,607,972 shares and
11,568,638 shares, respectively $ 48,040 $ 57,843
Additional paid-in capital 20,391 49,749
Retained earnings 49,220 55,147
Total common shareholders' investment 117,651 55.4% 162,739 53.4%
PREFERRED STOCK of PGE, par value $100 per share
Authorized - 997,500 shares (Note 6):
Not subject to mandatory redemption, net -
4.10% cumulative preferred,
79,670 and 100,000 shares outstanding,
respectively 7,967 10,000
Less current repurchases (35) -
9% cumulative preferred, 115,641 and
250,000 shares outstanding, respectively,
net of issuance costs 10,919 23,615
Total preferred stock not subject to
mandatory redemption, net 18,851 8.9% 33,615 11.0%
Subject to mandatory redemption -
5.75% cumulative preferred, 8,192 and
17,600 shares outstanding, respectively 819 1,760
Less current redemption requirements (80) (80)
Total preferred stock subject to
mandatory redemption 739 0.4% 1,680 0.6%
LONG-TERM DEBT (Note 7):
First mortgage bonds 55,000 55,000
Notes 58,721 167,707
Less current maturities and sinking
fund requirements (38,721) (116,001)
Total long-term debt 75,000 35.3% 106,706 35.0%
TOTAL CAPITALIZATION $ 212,241 100.0% $ 304,740 100.0%
The accompanying notes are an integral part of the consolidated financial statements.
</TABLE>
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<PAGE>
PENNSYLVANIA ENTERPRISES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' INVESTMENT
FOR THE YEARS ENDED DECEMBER 31, 1994, 1995 AND 1996
<TABLE>
<CAPTION>
Common Additional
Common Stock Paid-In Retained
Stock Subscribed Capital Earnings Total
(Thousands of Dollars)
<S> <C> <C> <C> <C> <C>
Balance at December 31, 1993 $54,140 $ - $ 43,005 $ 68,630 $165,775
Net income for 1994 - - - 12,817 12,817
Issuance of common stock 1,399 - 2,488 - 3,887
Common stock subscribed, net - 2,515 - - 2,515
Premium on redemption of
preferred stock of PGE - - - (980) (980)
Cash dividends on common stock
($1.10 per share) - - - (12,002) (12,002)
Balance at December 31, 1994 55,539 2,515 45,493 68,465 172,012
Net loss for 1995 - - - (713) (713)
Issuance of common stock 2,304 - 4,256 - 6,560
Common stock subscribed, net - (2,515) - - (2,515)
Cash dividends on common stock
($1.10 per share) - - - (12,605) (12,605)
Balance at December 31, 1995 57,843 - 49,749 55,147 162,739
Net income for 1996 - - - 6,584 6,584
Issuance of common stock 328 - 963 - 1,291
Repurchase of common stock (10,131) - (30,321) - (40,452)
Premium on repurchase of
preferred stock of PGE - - - (1,337) (1,337)
Cash dividends on common stock
($1.10 per share) - - - (11,174) (11,174)
Balance at December 31, 1996 $48,040 $ - $ 20,391 $ 49,220 $117,651
The accompanying notes are an integral part of the consolidated financial statements.
</TABLE>
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<PAGE>
PENNSYLVANIA ENTERPRISES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Nature of the Business. Pennsylvania Enterprises, Inc. ("the Company") is a
holding company whose principal subsidiary, PG Energy Inc. ("PGE"), a regulated
public utility formerly known as Pennsylvania Gas and Water Company, distributes
natural gas to a ten-county area in northeastern Pennsylvania, a territory that
includes 116 municipalities, in addition to the cities of Scranton, Wilkes-Barre
and Williamsport. On February 14, 1997, PGE acquired all of the outstanding
capital stock of Honesdale Gas Company ("Honesdale"), also a regulated public
utility, which distributes natural gas to approximately 3,200 customers in
portions of Pike and Wayne Counties in northeastern Pennsylvania.
The Company, through its other subsidiaries, Pennsylvania Energy Resources,
Inc. ("PERI"), Theta Land Corporation and Keystone Pipeline Services, Inc.
("Keystone"), a wholly-owned subsidiary of PERI, is also engaged in various
nonregulated activities, including the marketing and sale of natural gas and
propane and other energy-related services, as well as the construction,
maintenance and rehabilitation of natural gas distribution pipelines.
Additionally, Theta is presently initiating several residential and commercial
real estate development projects on Company-owned land, for which construction
will commence in 1997. Prior to 1996, these activities were not significant to
the operations of the Company as a whole. Pennsylvania Energy Marketing
Company, previously a subsidiary of the Company, was merged into PERI on May 31,
1996.
Principles of Consolidation. The consolidated financial statements include
the accounts of the Company and its subsidiaries, PGE, PERI and Theta. The
consolidated financial statements also include the accounts of Keystone
beginning December 4, 1995, the date Keystone was acquired by PERI. All
material intercompany accounts have been eliminated in consolidation.
PGE, a wholly-owned subsidiary of Pennsylvania Enterprises, Inc., is a
regulated public utility subject to the jurisdiction of the Pennsylvania Public
Utility Commission ("PPUC") for rate and accounting purposes. The financial
statements of PGE that are incorporated in these consolidated financial
statements have been prepared in accordance with generally accepted accounting
principles, including the provisions of Financial Accounting Standards Board
("FASB") Statement 71, "Accounting for the Effects of Certain Types of
Regulation," which give recognition to the rate and accounting practices of
regulatory agencies such as the PPUC.
Use of Accounting 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 and disclosure of contingent assets and liabilities at the date of
the financial statements and the reported amounts of revenues and expenses
during the reporting period. These estimates involve judgments with respect to,
among other things, various future economic factors and regulatory matters (see
"Management's Discussion and Analysis of Financial Conditions and Results of
Operations - Restructuring of Natural Gas Industry" in Item 7 of this Form 10-K)
which are difficult to predict and are beyond the control of the Company.
Therefore, actual amounts could differ from these estimates.
-38-
<PAGE>
Utility Plant and Depreciation. Utility plant is stated at cost, which
represents the original cost of construction, including payroll, administrative
and general costs, and an allowance for funds used during construction.
The allowance for funds used during construction ("AFUDC") is defined as the
net cost during the period of construction of borrowed funds used and a
reasonable rate upon other funds when so used. Such allowance is charged to
utility plant and reported as a reduction of interest expense (with respect to
the cost of borrowed funds) in the accompanying consolidated statements of
income. AFUDC varies according to changes in the level of construction work in
progress and in the sources and costs of capital. The weighted average rate for
such allowance was approximately 9% in 1996, 8% in 1995 and 7% in 1994.
PGE provides for depreciation on a straight-line basis. Exclusive of
transportation and work equipment, the annual provision for depreciation, as
related to the average depreciable original cost of utility plant, was 2.60% in
1996, 2.75% in 1995 and 2.77% in 1994, respectively.
When depreciable property is retired, the original cost of such property is
removed from the utility plant accounts and is charged, together with the cost
of removal less salvage, to accumulated depreciation. No gain or loss is
recognized in connection with retirements of depreciable property, other than in
the case of significant involuntary conversions or extraordinary retirements.
Revenues and Cost of Gas. PGE bills its customers monthly based on
estimated or actual meter readings on cycles that extend throughout the month.
The estimated unbilled amounts from the most recent meter reading dates through
the end of the period being reported on are recorded as accrued revenues.
PGE generally passes on to its customers increases or decreases in gas costs
from those reflected in its tariff charges. In accordance with this procedure,
PGE defers any current under or over-recoveries of gas costs and collects or
refunds such amounts in subsequent periods. PGE had underrecoveries of gas
costs totaling $29.6 million, $10.4 million and $15.8 million as of December 31,
1996, 1995 and 1994, respectively.
Deferred Charges (Regulatory Assets). PGE generally accounts for and
reports its costs in accordance with the economic effect of rate actions by the
PPUC. To this extent, certain costs are recorded as deferred charges pending
their recovery in rates. These amounts relate to previously-issued orders of
the PPUC and are of a nature which, in the opinion of the Company, will be
recoverable in future rates, based on such rate orders. In addition to deferred
taxes collectible, which represent the probable future rate recovery of the
previously unrecorded deferred taxes primarily relating to certain temporary
differences in the basis of utility plant not previously recorded because of the
regulatory rate practices of the PPUC, the following deferred charges are
included as "Other" regulatory assets as of December 31, 1996 and 1995:
[CAPTION]
1996 1995
(Thousands of Dollars)
[S] [C] [C]
Computer software costs $ 1,293 $ 415
Early retirement plan charges 664 710
Rate case expense 588 11
Low income usage reduction program 492 429
Extraordinary charges due to flooding 426 -
Customer assistance program 219 109
Corrosion control costs 194 341
Natural gas transition costs collectible - 497
Other 398 501
Total $ 4,274 $ 3,013
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<PAGE>
The Company also records, as deferred charges, the direct financing costs
incurred in connection with the issuance of long-term debt and redeemable
preferred stock and equitably amortizes such amounts over the life of such
securities.
Cash and Cash Equivalents. For the purposes of the consolidated statements
of cash flows, the Company considers all highly liquid debt instruments
purchased, which generally have a maturity of three months or less, to be cash
equivalents. Such instruments are carried at cost, which approximates market
value.
Income Taxes. The Company provides for deferred taxes in accordance with
the provisions of FASB Statement 109. The components of the Company's net
deferred income tax liability relative to continuing operations as of
December 31, 1996 and 1995, are shown below:
[CAPTION]
1996 1995
(Thousands of Dollars)
[S] [C] [C]
Utility plant basis differences $53,132 $51,822
FERC Order 636 transition costs 181 700
Postretirement benefits (726) (536)
Take-or-pay costs, net (467) (467)
Alternative minimum tax - (1,947)
Operating reserves (1,406) (1,300)
Other (1,444) 563
Net deferred income tax liability $49,270 $48,835
The provision for income taxes relative to continuing operations consists of
the following components:
[CAPTION]
1996 1995 1994
(Thousands of Dollars)
[S] [C] [C] [C]
Included in operating expenses:
Currently payable -
Federal $ 2,513 $ 3,129 $ 1,814
State 1,519 1,284 1,219
Total currently payable 4,032 4,413 3,033
Deferred, net -
Federal 2,059 198 1,785
State (119) (463) (105)
Total deferred, net 1,940 (265) 1,680
Amortization of investment tax credits (172) (193) (172)
Total included in operating expenses 5,800 3,955 4,541
Included in other income, net:
Currently payable -
Federal 806 126 185
State (19) 44 79
Total currently payable 787 170 264
Deferred, net -
Federal - - 10
State - - 12
Total deferred, net - - 22
Total included in other income, net 787 170 286
Total provision for income taxes $ 6,587 $ 4,125 $ 4,827
-40-
<PAGE>
The total provision for income taxes relative to continuing operations shown
in the accompanying consolidated statements of income differs from the amount
which would be computed by applying the statutory federal income tax rate to
income before income taxes. The following table summarizes the major reasons
for this difference:
[CAPTION]
1996 1995 1994
(Thousands of Dollars)
[S] [C] [C] [C]
Income before income taxes $16,381 $10,009 $11,828
Tax expense at statutory federal
income tax rate $ 5,733 $ 3,503 $ 4,140
Increases (reductions) in taxes
resulting from -
State income taxes, net of
federal income tax benefit 898 562 942
Amortization of investment tax
credits (172) (193) (172)
Other, net 128 253 (83)
Total provision for income taxes $ 6,587 $ 4,125 $ 4,827
Long Lived Assets. FASB Statement 121, "Accounting for the Impairment of
Long-Lived Assets" requires that long-lived assets, identifiable intangibles,
capital leases and goodwill be reviewed for impairment whenever events occur or
changes in circumstances indicate that the carrying amount of the assets may not
be recoverable. In addition, FASB Statement 121 requires that regulatory assets
meet the recovery criteria of FASB Statement 71, "Accounting for Effects of
Certain Types of Regulation", on an ongoing basis in order to avoid a writedown.
The implementation of FASB Statement 121 in 1996 did not have a significant
impact on the Company or PGE. The carrying amount of all assets, including
regulatory assets, is considered recoverable.
(2) DISCONTINUED OPERATIONS
Pursuant to an Asset Purchase Agreement dated April 26, 1995, as amended
(the "Agreement"), among the Company, PGE, American Water Works Company, Inc.
("American") and Pennsylvania-American Water Company ("Pennsylvania-American"),
a wholly-owned subsidiary of American, the Company and PGE sold substantially
all of the assets, properties and rights of PGE's water utility operations to
Pennsylvania-American on February 16, 1996. Under the terms of the Agreement,
Pennsylvania-American paid PGE $414.3 million consisting of $262.1 million in
cash and the assumption of $152.2 million of PGE's liabilities, including $141.0
million of its long-term debt. PGE continued to operate the water utility
business until February 16, 1996. The cash proceeds from the sale of
approximately $203.3 million, net of the estimated $58.8 million of income
taxes, were used by the Company and PGE to retire debt, to repurchase stock (see
Note 5 of these Notes to Consolidated Financial Statements), for construction
expenditures and for working capital for their continuing operations.
The sale price reflected a $6.5 million premium over the book value of the
assets sold. However, after transaction costs and the net effect of other
items, the sale resulted in an estimated after tax loss of approximately $6.2
million, net of the income from the water operations during the phase-out period
(which for financial reporting purposes was April 1, 1995, through February 15,
1996). The sale involved a gain for income tax purposes, primarily because of
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<PAGE>
the accelerated depreciation that had been claimed by PGE with respect to the
water utility plant that was sold. It is estimated that the income taxes
payable on the sale, for which deferred income taxes had previously been
provided, will be approximately $58.8 million, of which $44.6 million had been
paid as of December 31, 1996.
The accompanying consolidated financial statements reflect PGE's water
utility operations as "discontinued operations" effective March 31, 1995.
Interest charges relating to indebtedness of PGE were allocated through the date
of disposition to the discontinued operations based on the relationship of the
gross water utility plant that was sold to the total of PGE's gross gas and
water utility plant. This is the same method as was utilized by PGE and the
PPUC in establishing the revenue requirements of both PGE's gas and water
utility operations. None of the dividends on PGE's preferred stock nor any of
the Company's interest expense were allocated to the discontinued operations.
Selected financial information for the discontinued operations as of
December 31, 1995, and for the years ended December 31, 1995 and 1994, is set
forth below:
Net Assets of Discontinued Operations
[CAPTION]
As of
December 31, 1995
(Thousands of Dollars)
[S] [C]
Net utility plant $ 368,742
Other assets 38,508
Total assets being acquired by
Pennsylvania-American 407,250
Liabilities being assumed by
Pennsylvania-American 147,080
Net assets being acquired by
Pennsylvania-American 260,170
Estimated liability for income taxes on
sale of discontinued operations (56,710)
Estimated net income of discontinued operations
during the remainder of the phase-out period 790
Total net assets of discontinued operations $ 204,250
Income From Discontinued Operations
[CAPTION]
Years ended December 31,
1995* 1994
(Thousands of Dollars)
[S] [C] [C]
Operating revenues $ 15,640 $ 66,731
Operating expenses, excluding income taxes 8,875 36,677
Operating income before income taxes 6,765 30,054
Income taxes 1,403 6,850
Operating income 5,362 23,204
Other income 9 49
Allocated interest charges (3,244) (12,749)
Income from discontinued operations $ 2,127 $ 10,504
* Reflects amounts only through March 31, 1995, the effective date of the
discontinuance of PGE's water utility operations for financial statement
purposes.
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<PAGE>
Net Cash Provided by Discontinued Operations
[CAPTION]
Years ended December 31,
1995* 1994
(Thousands of Dollars)
[S] [C] [C]
Income from discontinued operations $ 2,127 $ 10,504
Noncash charges (credits) to income:
Depreciation 1,946 7,672
Deferred treatment plant costs, net 145 581
Deferred income taxes 447 5,146
Deferred water utility billings - (5,574)
Changes in working capital, exclusive
of long-term debt 1,648 353
Additions to utility plant (2,276) (20,980)
Utilization of restricted funds - 9,753
Net increase (decrease) in long-term
debt 1,010 (6,834)
Other, net (1,283) (69)
Net cash provided by discontinued
operations $ 3,764 $ 552
* Reflects amounts only through March 31, 1995, the effective date of the
discontinuance of PGE's water utility operations for financial statement
purposes.
(3) RATE MATTERS
Rate Increase. On May 24, 1996, PGE filed an application with the PPUC
seeking an increase in its base gas rates, designed to produce $14.1 million in
additional annual revenue, to be effective July 23, 1996. On June 20, 1996, the
PPUC suspended this rate increase for seven months (until February 23, 1997) in
order to investigate the reasonableness of the proposed rates. On November 7,
1996, PGE and certain parties filing objections to the rate increase request
filed a Settlement Agreement and Joint Petition for Settlement of Rate
Investigation (the "Settlement Petition") with the Administrative Law Judge
assigned to conduct the investigation of the rate increase request. This
Settlement Petition provided for an overall 5.3% rate increase that was designed
to produce $7.5 million of additional annual revenue. By Order adopted December
19, 1996, the PPUC approved the Settlement Petition effective January 15, 1997.
Under the terms of the Settlement Petition, the billing for the impact of the
rate increase relative to PGE's residential heating customers (which it is
estimated will total $6.6 million on an annual basis) is being deferred, without
carrying charges, until July, 1997.
Gas Cost Adjustments. The provisions of the Pennsylvania Public Utility
Code require that the tariffs of local gas distribution companies ("LDCs") such
as PGE, be adjusted on an annual basis, and on an interim basis when
circumstances dictate, to reflect changes in their purchased gas costs. The
procedure includes a process for the reconciliation of actual gas costs incurred
and actual revenues received and also provides for the refund of any
overcollections, plus interest thereon, or the recoupment of any
undercollections of gas costs.
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<PAGE>
In accordance with these procedures PGE has been permitted to make the
following changes since January 1, 1994, to the gas costs contained in its gas
tariff rates:
[CAPTION]
Change in Calculated
Effective Rate per MCF Increase (Decrease)
Date From To in Annual Revenue
[S] [C] [C] [C]
December 1, 1996 3.01 4.18 $32,400,000
September 1, 1996 2.88 3.01 3,600,000
June 1, 1996 2.75 2.88 3,400,000
December 1, 1995 2.42 2.75 9,600,000
May 15, 1995 3.68 2.42 (8,200,000)*
December 1, 1994 3.74 3.68 (1,800,000)
* Represents estimated reduction in revenue for the period May 15, 1995,
through November 30, 1995.
The changes in gas rates on account of purchased gas costs have no effect on
PGE's earnings since the change in revenue is offset by a corresponding change
in the cost of gas.
Recovery of FERC Order 636 Transition Costs. On October 15, 1993, the PPUC
adopted an annual purchased gas cost ("PGC") order (the "PGC Order") regarding
recovery of Federal Energy Regulatory Commission ("FERC") Order 636 transition
costs. The PGC Order stated that Account 191 and New Facility Costs (the "Gas
Transition Costs") are subject to recovery through the annual PGC rate filings
made with the PPUC by PGE and other LDCs. The PGC Order also indicated that
while Gas Supply Realignment and Stranded Costs (the "Non-Gas Transition Costs")
are not natural gas costs eligible for recovery under the PGC rate filing
mechanism, such costs are subject to full recovery by LDCs through the filing of
a tariff pursuant to either the existing surcharge or base rate provisions of
the Code. The PGC Order further stated that all such filings would be evaluated
on a case-by-case basis.
PGE was billed a total of $1.3 million of Gas Transition Costs by its
interstate pipelines. Of this amount, $857,000 was recovered by PGE over a
twelve-month period ended January 31, 1995, through an increase in its PGC rate,
$252,000 was recovered by PGE in its annual PGC rate that the PPUC approved
effective December 1, 1995, and the remaining $213,000 is being recovered by PGE
in its PGC rate that was effective December 1, 1996.
By Order of the PPUC entered August 26, 1994, PGE began recovering the Non-
Gas Transition Costs that it estimates it will ultimately be billed pursuant to
FERC Order 636 through the billing of a surcharge to its customers effective
September 12, 1994. It is currently estimated that $10.1 million of Non-Gas
Transition Costs will be billed to PGE, generally over a six-year period
extending through January 1, 1999, of which $8.0 million had been billed to PGE
and $7.5 million had been recovered from its customers as of December 31, 1996.
PGE has recorded the estimated Non-Gas Transition Costs that remain to be billed
to it and the amounts remaining to be recovered from its customers.
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<PAGE>
(4) OTHER INCOME, NET
Other income, net was comprised of the following elements:
Year Ended December 31,
1996 1995 1994
(Thousands of Dollars)
[S] [C] [C] [C]
Interest income on the temporary investment
of proceeds from the sale of PGE's
water utility operations, net of related
income taxes $ 1,895 $ - $ -
Loss on sale and retirement of gas wells
and related abandonment of subsurface
gas rights, net of related income taxes (321) - -
Gain on sale of land and other property,
net of related income taxes 141 - 165
Write-off of expired advances relating
to income taxes, net of related
income taxes - 227 -
Amortization of preferred stock issuance
costs, net of related income tax benefits (13) (1) (227)
Other 24 129 173
Total $ 1,726 $ 355 $ 111
(5) COMMON STOCK
Common Stock Split. On February 19, 1997, the Board of Directors adopted
resolutions to amend the Company's Restated Articles of Incorporation to (i)
increase the number of authorized shares of its common stock from 15 million
shares to 30 million shares and (ii) reduce the stated value of such shares from
$10.00 per share to $5.00 per share upon the filing of a Certificate of
Amendment with the Secretary of the State of Pennsylvania on March 20, 1997.
Such actions will have no effect on the Company's capital accounts. On February
19, 1997, the Board of Directors also declared a two-for-one stock split of the
Company's Common Stock effective March 20, 1997. The number of shares of common
stock reflected in these consolidated financial statements and the earnings per
share of common stock for each year presented have been restated to give
retroactive effect to this stock split.
Repurchase of Common Stock. During 1996, the Company used proceeds it
received in connection with PGE's sale of its water utility operations to
Pennsylvania-American on February 16, 1996, to repurchase shares of its common
stock. Specifically, a portion of these proceeds were used by the Company to
repurchase 2,025,928 shares of its common stock during 1996 for an aggregate
consideration of $39.8 million, of which 1,781,204 shares were acquired in April
pursuant to a self tender offer and 244,724 shares were acquired from time to
time through open market purchases and an oddlot buyback program.
Customer Stock Purchase Plan. On July 28, 1994, the Company implemented a
Customer Stock Purchase Plan (the "Customer Plan") which provided the
residential customers of PGE with a method of purchasing newly-issued shares of
the Company's common stock at a 5% discount from the market price. Under the
terms of the Customer Plan, 176,462 shares ($2.4 million) and 119,074 shares
($1.7 million) of the Company's common stock were issued during 1995 and 1994,
respectively. Effective May 9, 1995, the Company suspended the Customer Plan
because of the significant reduction in its capital requirements resulting from
the sale of PGE's water utility operations to Pennsylvania-American.
Dividend Reinvestment and Stock Purchase Plan. Through the Company's
Dividend Reinvestment and Stock Purchase Plan ("DRP"), holders of shares of the
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<PAGE>
Company's common stock may reinvest cash dividends and/or make cash investments
in the common stock of the Company. Under the DRP, 17,664 shares ($340,000),
233,010 shares ($3.3 million) and 124,542 shares ($1.8 million) of common stock
were issued during 1996, 1995 and 1994, respectively.
Employees' Savings Plan. Under the Company's Employees' Savings Plan (a
section 401(k) plan) which became effective January 1, 1992, the Company issued
an additional 10,198 shares ($195,000) in 1996, 38,936 shares ($628,000) in 1995
and 36,200 shares ($540,000) in 1994.
Stock Option Plan. On June 3, 1992, the Company's shareholders approved the
Pennsylvania Enterprises, Inc. 1992 Stock Option Plan (the "Plan"). Under the
terms of the Plan, a total of 430,000 shares of authorized but unissued shares
of the Company's common stock have been reserved and made available for
distribution to eligible employees. Stock options awarded under the Plan may be
either Incentive Stock Options or Nonqualified Stock Options.
In October, 1995, FASB Statement 123, "Accounting For Stock-Based
Compensation," was issued. The Company adopted the disclosure provisions of
FASB Statement 123 in 1996, but opted to remain under the expense recognition
provisions of Accounting Principles Board (APB) Opinion No. 25, "Accounting for
Stock Issued to Employees," in accounting for stock option and stock award
plans. Accordingly, for the years ended December 31, 1996, 1995 and 1994, no
compensation expense was recognized for options granted under the Plan. Had
compensation expense for stock options granted under the Plan been determined
based on fair value at the grant dates consistent with the method required for
1996 in accordance with FASB Statement 123, the Company's net income and
earnings per share for 1996 would have been reduced to the pro forma amounts
shown below:
[CAPTION]
[S] [C]
Net income:
As reported $6.6 million
Pro forma $5.9 million
Earnings per common share:
As reported $ .51
Pro forma $ .44
A summary of the stock options outstanding during each of the three years in
the period ended December 31, 1996, pursuant to the terms of the Plan, all of
which were Nonqualified Stock Options, is set forth below:
[CAPTION]
Number of Weighted
shares subject average exercise
to option price
[S] [C] [C]
Outstanding at December 31, 1993 90,000 $ 15.00
Expired during 1994 (800) 15.00
Outstanding at December 31, 1994 89,200 15.00
Exercised during 1995 (9,600) 18.63
Outstanding at December 31, 1995 79,600 15.00
Granted during 1996 340,000 20.38
Exercised during 1996 (37,400) 20.05
Outstanding at December 31, 1996 382,200 $ 18.09
Options exercisable at December 31, 1996 42,200 15.00
Options available for future grant at
December 31, 1996 800
Weighted average fair value of options
granted during 1996 $3.66
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<PAGE>
The weighted average fair value of options granted in 1996 was estimated as
of the date of grant using the Black-Scholes stock option pricing model, based
on the following weighted average assumptions: quarterly dividend yield of
1.25%, annual expected return of 5.3%, annual standard deviation (volatility) of
20.5%, risk free interest rate of 6.91%, and expected term of 7 years.
The following table summarizes information regarding the stock options
outstanding at December 31, 1996, pursuant to the terms of the Plan:
[CAPTION]
Options outstanding Options exercisable
Weighted Average Weighted
At Range of Remaining At average
December 31, exercise contractual Exercise December 31, exercise
1996 prices life price 1996 price
[S] [C] [C] [C] [C] [C]
42,200 $15.00 6.27 Years $15.00 42,200 $15.00
340,000 $19.50-20.75 9.56 Years $20.38 -
382,200 42,200
Shareholder Rights Plan. On April 26, 1995, the Company adopted a
Shareholder Rights Plan under the terms of which each shareholder of record at
the close of business on May 16, 1995, will receive a dividend distribution of
one right ("Right" or "Rights") for each share of common stock held.
Each Right will entitle shareholders to purchase from the Company one-half
of a share of common stock. No less than two Rights, and only integral
multiples of two Rights, may be exercised by holders of Rights at an exercise
price of $50 per share of common stock (equivalent to $25 for each one-half
share of common stock), subject to certain adjustments. The Rights will become
exercisable only if a person or group acquires 15% or more of the Company's
common stock, or commences a tender or exchange offer which, if consummated,
would result in that person or group owning at least 15% of the common stock.
Prior to that time, the Rights will not trade separately from the common stock.
If a person or group acquires 15% or more of the Company's common stock, all
other holders of Rights will then be entitled to purchase, by payment of the $50
exercise price upon the exercise of two Rights, the Company's common stock (or a
common stock equivalent) with a value of twice the exercise price. In addition,
at any time after a 15% position is acquired and prior to the acquisition by any
person or group of 50% or more of the outstanding common stock, the Company's
Board of Directors may, at its option, require each outstanding Right (other
than Rights held by the acquiring person or group) to be exchanged for one share
of common stock (or one common stock equivalent).
If, following an acquisition of 15% or more of the Company's common stock,
the Company is acquired by any person in a merger or other business combination
transaction or sells more than 50% of its assets or earning power to any person
(other than the sale of PGE's water utility operations to Pennsylvania-
American), all other holders of Rights will then be entitled to purchase, by
payment of the $50 exercise price upon the exercise of two Rights, common stock
of the acquiring company with a value of twice the exercise price.
The Company may redeem the Rights at $.0025 per Right at any time prior to
the time that a person or group has acquired 15% or more of its common stock.
The Rights, which expire on May 16, 2005, do not have voting or dividend rights
and, until they become exercisable, have no dilutive effect on the earnings per
share of the Company.
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<PAGE>
(6) PREFERRED STOCK
Preferred Stock of PGE Subject to Mandatory Redemption. On May 31, 1994,
PGE redeemed the remaining 150,000 outstanding shares of its 9.50% 1988 series
cumulative preferred stock, $100 par value, at a price of $103.5625 per share,
which included a voluntary redemption premium of $3.5625 per share ($534,375 in
the aggregate), plus accrued dividends.
On December 16, 1994, PGE redeemed all 150,000 shares of its 8.90%
cumulative preferred stock at a price of $102.97 per share, which included a
voluntary redemption premium of $2.97 per share ($445,500 in the aggregate).
The holders of the 5.75% cumulative preferred stock have a noncumulative
right each year to tender to PGE and to require it to purchase at a per share
price not exceeding $100, up to (a) that number of shares of the 5.75%
cumulative preferred stock which can be acquired for an aggregate purchase price
of $80,000 less (b) the number of such shares which PGE may already have
purchased during the year at a per share price of not more than $100. On
June 17, 1996, PGE repurchased 9,408 shares of its 5.75% cumulative preferred
stock (including 800 shares redeemed in accordance with annual sinking fund
provisions) for an aggregate consideration of $838,000. Eight hundred such
shares were acquired and cancelled by PGE in each of the years ended
December 31, 1995 and 1994, for an aggregate purchase price in each year of
$80,000.
As of December 31, 1996, the sinking fund requirements relative to PGE's
5.75% cumulative preferred stock (the only series of preferred stock subject to
mandatory redemption that was outstanding as of such date) were $80,000 for each
of the years 1997 through 2001. At PGE's option, the 5.75% cumulative preferred
stock may currently be redeemed at a price of $102.00 per share ($836,000 in the
aggregate).
Preferred Stock of PGE Not Subject to Mandatory Redemption. During the year
ended December 31, 1996, PGE repurchased 134,359 shares of its 9% cumulative
preferred stock, $100 par value, for an aggregate consideration of $14.5
million, largely pursuant to a self tender offer conducted during March and
April, 1996. The 9% cumulative preferred stock is not redeemable at the option
of PGE prior to September 15, 1997. Thereafter, it is redeemable at the option
of PGE, in whole or in part, upon not less than 30 days' notice, at $100 per
share plus accrued dividends to the date of redemption and at a premium of $8
per share if redeemed from September 15, 1997, to September 14, 1998, and a
premium of $4 per share if redeemed from September 15, 1998, to September 14,
1999.
During the year ended December 31, 1996, PGE repurchased 20,330 shares of
its 4.10% cumulative preferred stock, $100 par value, for an aggregate
consideration of $1.0 million, largely pursuant to a self tender offer conducted
during March and April, 1996. An additional 350 shares of 4.10% cumulative
preferred stock were repurchased in January, 1997, for an aggregate
consideration of $19,000. At PGE's option, the 4.10% cumulative preferred stock
may currently be redeemed at a redemption price of $105.50 per share or for an
aggregate redemption price of $8,368,260.
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<PAGE>
Dividend Information. The dividends on the preferred stock of PGE in each
of the three years in the period ended December 31, 1996, were as follows:
[CAPTION]
Series 1996 1995 1994
(Thousands of Dollars)
[S] [C] [C] [C]
4.10% $ 348 $ 410 $ 410
5.75% 72 103 108
8.90% - - 1,280
9.00% 1,310 2,250 2,250
9.50% 1988 series - - 591
Total $1,730 $2,763 $4,639
Dividends on all series of PGE's preferred stock are cumulative and PGE may
not declare dividends on its common stock if any dividends on shares of
preferred stock then outstanding are in default.
(7) LONG-TERM DEBT
Long-term debt consisted of the following components at December 31, 1996
and 1995:
[CAPTION]
1996 1995
(Thousands of Dollars)
[S] [C] [C]
Indebtedness of the Company:
10.125% senior notes, due 1999, net of
unamortized discount $ - $ 29,906
Term loan, due 1999 20,000 20,000
Total long-term debt of the Company 20,000 49,906
Indebtedness of PGE:
First mortgage bonds -
8.375% Series, due 2002 30,000 30,000
9.23 % Series, due 1999 10,000 10,000
9.34 % Series, due 2019 15,000 15,000
55,000 55,000
Notes -
Term loan, due 1996 - 50,000
Bank borrowings, at weighted average interest
rates of 6.18% and 6.62%, respectively (Note 9) 38,721 65,801
38,721 115,801
Less current maturities and sinking
fund requirements (38,721) (115,801)
Total long-term debt of PGE 55,000 55,000
Indebtedness of PERI:
Term loan, due 2000 - 2,000
Less current maturities - (200)
Total long-term debt of PERI - 1,800
Total consolidated long-term debt $ 75,000 $106,706
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<PAGE>
Term Loan Agreements. Borrowings under the Company's $20.0 million term
loan which matures on May 31, 1999, bear interest at LIBOR ("London Interbank
Offered Rates") plus one-half of one percent (5.906% as of March 1, 1997).
Under the terms of the loan, the Company can choose interest rate periods of
one, two, three or six months.
On October 12, 1995, PGE borrowed $50.0 million pursuant to a term loan
agreement. Proceeds from the loan, along with other funds provided by PGE, were
utilized on October 13, 1995, to redeem the $50.0 million principal amount of
PGE's 9.57% Series First Mortgage Bonds due September 1, 1996. PGE repaid its
$50.0 million term loan on February 16, 1996, with proceeds from the sale of its
water operations to Pennsylvania-American.
On December 7, 1995, PERI borrowed $2.0 million pursuant to a five-year term
loan agreement. PERI used the proceeds it so received along with an equity
investment from the Company to acquire all of the outstanding stock of Keystone
effective December 4, 1995. On May 31, 1996, PERI repaid all principal amounts
outstanding under the loan with an advance it received from the Company.
10.125% Senior Notes/Extraordinary Loss. On May 26, 1996, the Company
repurchased $1.3 million principal amount of its 10.125% Senior Notes due June
15, 1999 (the "Senior Notes") which the holders thereof elected pursuant to
terms of the Senior Notes to require the Company to repurchase as a result of
the sale of PGE's water utility operations on February 16, 1996. On September
30, 1996, the Company defeased the remaining $28.7 million principal amount of
the Senior Notes and recorded an extraordinary loss of $1.1 million ($1.6
million, net of $575,000 of related income tax benefits).
Specifically, on that date, the Company deposited $29.9 million with the
trustee for the Senior Notes which will be used, together with interest earned
on the funds so deposited, to pay the Company's interest and principal
obligations through June 15, 1997, the date on which the Senior Notes will be
redeemed. The deposit of such funds acted to discharge all of the Company's
obligations with respect to the Senior Notes. Of the $29.9 million required to
defease the Senior Notes, $17.2 million was obtained through the liquidation of
the Company's temporary cash investments and $12.7 million was obtained through
the repayment of loans that had been made by the Company to PGE.
Maturities and Sinking Fund Requirements. As of December 31, 1996, the
aggregate annual maturities and sinking fund requirements of long-term debt for
each of the next five years ending December 31, were:
[CAPTION]
Year Amount
[S] [C]
1997 $ 38,721,000 (a)
1998 $ -
1999 $ 30,000,000 (b)
2000 $ -
2001 $ -
(a) Represents the $38.7 million of PGE bank borrowings outstanding as of
December 31, 1996.
(b) Includes the $20.0 million of borrowings outstanding as of December 31,
1996, under the Company's Term Loan Agreement due May 31, 1999, and
PGE's 9.23% Series First Mortgage Bonds in the principal amount of $10.0
million due September 1, 1999.
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<PAGE>
(8) DIVIDEND RESTRICTIONS
There are no dividend restrictions in the Company's Restated Articles of
Incorporation. However, the preferred stock provisions of PGE's Restated
Articles of Incorporation and certain of the agreements under which the Company
and PGE have issued long-term debt provide for certain dividend restrictions.
As of December 31, 1996, $5,416,000 of the consolidated retained earnings of the
Company were restricted against the payment of cash dividends on common stock
under the most restrictive of these covenants.
(9) BANK NOTES PAYABLE
As of April 19, 1993, PGE entered into a revolving bank credit agreement, as
subsequently amended (the "Credit Agreement"), with a group of six banks under
the terms of which $60.0 million was available for borrowing by PGE through
May 31, 1996. The Credit Agreement was terminated on February 26, 1996,
following the sale of PGE's water operations to Pennsylvania-American on
February 16, 1996, and the repayment of all borrowings outstanding under the
Credit Agreement with proceeds from such sale. The interest rate on borrowings
under the Credit Agreement was generally less than prime. The Credit Agreement
required the payment of a commitment fee of .195% per annum on the average daily
amount of the unused portion of the available funds.
PGE currently has arrangements for six revolving bank lines of credit with
an aggregate borrowing capacity of $65.5 million which provide for borrowings at
interest rates generally less than prime and which mature during mid-1997. As
of March 1, 1997, PGE had $27.2 million outstanding under these bank lines of
credit.
Because of limitations imposed by the terms of PGE's preferred stock, PGE is
prohibited, without the consent of the holders of a majority of the outstanding
shares of its preferred stock, from issuing more than $12.0 million of unsecured
debt due on demand or within one year from issuance. PGE had $10.0 million due
on demand or within one year from issuance outstanding as of December 31, 1996.
Information relating to PGE's bank lines of credit and borrowings under
those lines of credit is set forth below:
<TABLE>
<CAPTION>
As of December 31,
1996 1995 1994
(Thousands of Dollars)
<S> <C> <C> <C>
Borrowings under lines of credit
Short-term $ 10,000 $ 10,000 $ -
Long-term 38,721 65,801 65,500
$ 48,721 $ 75,801 $ 65,500
Unused lines of credit
Short-term $ - $ - $ -
Long-term 16,779 4,699 2,000
$ 16,779 $ 4,699 $ 2,000
Total lines of credit
Prime rate $ - $ - $ -
Other than prime rate 65,500 80,500 67,500
$ 65,500 $ 80,500 $ 67,500
Short-term bank borrowings (a)
Maximum amount outstanding $ 10,000 $ 10,000 $ 5,692
Daily average amount outstanding $ 1,392 $ 2,581 $ 441
Weighted daily average interest
rate 6.241% 6.513% 3.984%
Weighted average interest rate at
year-end 6.206% 6.334% -
Range of interest rates 5.875- 6.290- 3.700-
6.438% 6.660% 6.000%
(a) PGE had no short-term bank borrowings outstanding as of December 31,
1994.
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</TABLE>
<PAGE>
(10) POSTEMPLOYMENT BENEFITS
Pension Benefits. The Company's retirement plan is a trusteed,
noncontributory, defined benefit pension plan which covers substantially all
employees of the Company, except those of Keystone. Pension benefits are based
on years of service and average final salary. The Company's funding policy is
to contribute an amount necessary to provide for benefits based on service to
date, as well as for benefits expected to be earned in the future by current
participants. To the extent that the present value of these obligations is
fully covered by assets in the trust, a contribution may not be made for a
particular year.
Under the terms of the agreement regarding the sale of PGE's water utility
operations to Pennsylvania-American, on February 16, 1996, Pennsylvania-American
assumed the accumulated benefit obligations relating to employees of PGE who
accepted employment with Pennsylvania-American (the "Transferred Employees").
In this regard, plan assets in an amount equal to the actuarial present value of
accumulated plan benefits relative to the Transferred Employees, with interest
from February 16, 1996, were transferred to the American pension plan in June,
1996. As a result of this and other actions, the Company recognized, as of
December 31, 1995, an estimated settlement loss of $200,000 ($117,000 net of the
related income tax benefit) and curtailment gain of $2.7 million ($1.6 million
net of related income taxes) in its determination of the estimated loss on the
disposal of PGE's water utility operations.
In December, 1995, the Company offered an Early Retirement Plan ("ERP") to
its employees who would be 59 years of age or older and had a minimum of five
years of service as of December 31, 1995. Of the 63 eligible employees, 50
elected to accept this offer and retired as of December 31, 1995, resulting in
the recording, as of December 31, 1995, of an additional pension liability of
$1.6 million reflecting the increased costs associated with the ERP. Such
amount was charged to the estimated loss on the disposal of PGE's water utility
operations.
Net pension costs relative to continuing operations, including amounts
capitalized, were $385,000, $353,000 and $309,000 in 1996, 1995 and 1994,
respectively. The following items were the components of such net pension
costs:
[CAPTION]
1996 1995 1994
(Thousands of Dollars)
[S] [C] [C] [C]
Present value of benefits earned
during the year $ 799 $ 430 $ 549
Interest cost on projected benefit
obligations 2,731 1,459 1,400
Return on plan assets (5,875) (1,502) 535
Net amortization and deferral (79) (34) (55)
Deferral of investment (loss) gain 2,809 - (2,120)
Net pension cost $ 385 $ 353 $ 309
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<PAGE>
The funded status of the plan as of December 31, 1996 and 1995, was as
follows:
[CAPTION]
1996 1995
(Thousands of Dollars)
[S] [C] [C]
Actuarial present value of the projected
benefit obligations:
Accumulated benefit obligations
Vested $ 28,613 $ 29,100
Nonvested 21 47
Total 28,634 29,147
Provision for future salary increases 6,933 7,841
Projected benefit obligations 35,567 36,988
Approximate market value of plan assets,
primarily invested in equities and bonds 39,000 34,000
Plan assets in excess of (less than) projected
benefit obligations 3,433 (2,988)
Unrecognized net transition asset as of
January 1, 1986, being amortized over 20 years (1,939) (2,155)
Unrecognized prior service costs 2,258 1,507
Unrecognized net (gain) loss (4,259) 2,155
Accrued pension cost at year-end $ (507) $ (1,481)
The assumptions used in determining pension obligations were:
<TABLE>
<CAPTION>
1996 1995 1994
<S> <C> <C> <C>
Discount rate 7.75 % 7.00 % 8.75 %
Expected long-term rate of return
on plan assets 9.00 % 9.00 % 9.00 %
Projected increase in future
compensation levels 5.00 % 5.00 % 5.50 %
Other Postretirement Benefits. In addition to pension benefits, the Company
provides certain health care and life insurance benefits for retired employees.
All of the Company's employees, except those of Keystone, may become eligible
for those benefits if they reach retirement age while working for the Company.
The Company records the cost of retiree health care and life insurance benefits
as a liability over the employees' active service periods instead of on a
benefits-paid basis.
Under the terms of the agreement regarding the sale of PGE's water utility
operations to Pennsylvania-American, on February 16, 1996, Pennsylvania-American
assumed the Company's obligation to provide retiree health care and life
insurance benefits to the Transferred Employees, as well as 45% of PGE's retired
employees as of that date. In this regard, plan assets in an amount
proportional to the actuarial present value of accumulated plan benefits
relative to the Transferred Employees and 45% of the retired employees as of
February 16, 1996, will be transferred to trusts established by Pennsylvania-
American, which is expected to occur in the second quarter of 1997.
Pennsylvania-American is reimbursing PGE for benefit plan payments made on
behalf of the retired employees for whom Pennsylvania-American has assumed
responsibility. As a result of the transfer, early retirement and displacement
of employees, the Company recognized an estimated settlement and curtailment
loss of $385,000 ($225,000 net of the related income tax benefit) as part of the
loss on the disposal of PGE's water utility operations.
</TABLE>
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<PAGE>
In conjunction with the ERP offered by the Company to certain of its
employees, PGE recorded, as of December 31, 1995, an additional liability of
$805,000, ($471,000 net of the related income tax benefit) reflecting the cost
of future health care benefits required to be recognized in conjunction with the
ERP. Such amount was charged to the estimated loss on disposal of PGE's water
utility operations.
The following items were the components of the net cost of postretirement
benefits other than pensions relative to continuing operations for the years
1996, 1995 and 1994:
<TABLE>
<CAPTION>
1996 1995 1994
(Thousands of Dollars)
<S> <C> <C> <C>
Present value of benefits earned during
the year $ 253 $ 127 $ 148
Interest cost on accumulated benefit
obligation 506 577 532
Return on plan assets - (69) (4)
Net amortization and deferral 314 391 360
Net cost of postretirement benefits other
than pensions 1,073 1,026 1,036
Less disbursements for benefits (501) (555) (543)
Increase in liability for postretirement
benefits other than pensions $ 572 $ 471 $ 493
</TABLE>
Reconciliations of the accumulated benefit obligation to the accrued
liability for postretirement benefits other than pensions as of December 31,
1996 and 1995, follow:
[CAPTION]
1996 1995
(Thousands of Dollars)
[S] [C] [C]
Accumulated benefit obligation:
Retirees $ 4,359 $ 6,514
Fully eligible active employees 1,033 850
Other active employees 1,552 1,074
6,944 8,438
Plan assets at fair value 169 -
Accumulated benefit obligation
in excess of plan assets 6,775 8,438
Unrecognized transition obligation
being amortized over 20 years (5,022) (5,438)
Unrecognized net gain (loss) 1,116 (703)
Accrued liability for postretirement
benefits other than pensions $ 2,869 $ 2,297
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<PAGE>
The assumptions used in determining other postretirement benefit obligations
were:
[CAPTION]
1996 1995 1994
[S] [C] [C] [C]
Discount rate 7.75 % 7.00 % 8.75 %
Expected long-term rate of return
on plan assets 9.00 % 9.00 % 9.00 %
Projected increase in future
compensation levels 5.00 % 5.00 % 5.50 %
It was also assumed that the per capita cost of covered health care benefits
would increase at an annual rate of 8-1/2% in 1997 and that this rate would
decrease gradually to 5-1/2% for the year 2003 and remain at that level
thereafter. The health care cost trend rate assumption had a significant effect
on the amounts accrued. To illustrate, increasing the assumed health care cost
trend rate by 1 percentage point in each year would increase the transition
obligation as of January 1, 1997, by approximately $294,000 and the aggregate of
the service and interest cost components of the net cost of postretirement
benefits other than pensions for the year 1996 by approximately $31,000.
Since PGE did not seek to increase its base gas rates prior to 1996, the
$442,000 ($259,000 net of related income taxes), $441,000 ($258,000 net of
related income taxes) and $447,000 ($256,000 net of related income taxes) of
additional cost incurred in 1996, 1995 and 1994, respectively, as a result of
the adoption of the provisions of FASB Statement 106 were expensed without any
adjustment being made to its gas rates. Effective with its January 15, 1997
base rate increase (see Note 3 of these Notes to Consolidated Financial
Statements), PGE will begin funding and recovering in rates its accumulated
benefit obligations with respect to other postretirement benefits.
(11) CAPITAL EXPENDITURES
The Company estimates the cost of its 1997 capital expenditure program will
be $45.4 million, consisting of $27.9 million relative to PGE's construction
program and $17.5 million with respect to the Company's nonregulated activities,
including $13.1 million relative to residential and commercial real estate
development. It is anticipated that such expenditures will be financed with
internally generated funds and bank borrowings and, to the extent necessary, by
the periodic issuance of stock and long-term debt.
(12) COMMITMENTS AND CONTINGENCIES
Environmental Matters. PGE, like many gas distribution companies, once
utilized manufactured gas plants in connection with providing gas service to its
customers. None of these plants has been in operation since 1960, and several
of the plant sites are no longer owned by PGE. Pursuant to the Comprehensive
Environmental Response, Compensation and Liability Act of 1980 ("CERCLA"), PGE
filed notices with the United States Environmental Protection Agency (the "EPA")
with respect to the former plant sites. None of the sites is or was formerly on
the proposed or final National Priorities List. The EPA has conducted site
inspections and made preliminary assessments of each site and has concluded that
no further remedial action is planned. While this conclusion does not
constitute a legal prohibition against further regulatory action under CERCLA or
other applicable federal or state law, the Company does not believe that
additional costs, if any, related to these manufactured gas plant sites would be
material to its financial position or results of operations since environmental
remediation costs generally are recoverable through rates over a period of time.
-55-
<PAGE>
(13) QUARTERLY FINANCIAL DATA (UNAUDITED)
[CAPTION]
QUARTER ENDED
March 31, June 30, September 30, December 31,
1996 1996 1996 1996
(Thousands of Dollars, Except Per Share Amounts)
[S] [C] [C] [C] [C]
Operating revenues $ 74,087 $ 30,257 $ 19,354 $ 60,782
Operating income (loss) 10,223 995 (751) 7,793
Income (loss) from continuing
operations 7,337 (455) (2,940) 4,122
Loss with respect to
discontinued operations (365) (21) - 23
Extraordinary loss, net - - (1,117) -
Net income (loss) $ 6,972 $ (476) $ (4,057) $ 4,145
Earnings (loss) per share
of common stock (a):
Continuing operations $ .63 $ (.05) $ (.30) $ .43
Discontinued operations (.03) - - -
Net income (loss) before
premium on repurchase/
redemption of subsidiary's
preferred stock and
extraordinary loss .60 (.05) (.30) .43
Premium on repurchase/redemption
of subsidiary's preferred
stock - (.13) (.01) -
Extraordinary loss, net - - (.11) -
Earnings (loss) per share of
common stock (a) $ .60 $ (.18) $ (.42) $ .43
<TABLE>
<CAPTION>
QUARTER ENDED
March 31, June 30, September 30, December 31,
1995 1995 1995 1995
(Thousands of Dollars, Except Per Share Amounts)
<S> <C> <C> <C> <C>
Operating revenues $ 70,882 $ 27,397 $ 13,547 $ 50,109
Operating income 9,910 2,478 506 8,057
Income (loss) from continuing
operations 5,669 (2,133) (4,159) 3,744
Loss with respect to
discontinued operations (3,704) - - (130)
Net income (loss) $ 1,965 $ (2,133) $ (4,159) $ 3,614
Earnings (loss) per share
of common stock: (a)
Continuing operations $ .50 $ (.19) $ (.36) $ .32
Discontinued operations (.33) - - (.01)
Earnings (loss) per share of
common stock (a) $ .17 $ (.19) $ (.36) $ .31
(a) The total of the earnings per share for the quarters does not equal the
earnings per share for the year, as shown elsewhere in the consolidated
financial statements and supplementary data of this report, as a result
of the Company's issuance of additional shares of common stock at
various dates in 1994 and 1995 and its repurchase of shares of common
stock at various dates during 1996.
Because of the seasonal nature of PGE's gas heating business, there are
substantial variations in operations reported on a quarterly basis.
-56-
</TABLE>
<PAGE>
(14) DISCLOSURES ABOUT FAIR VALUE OF FINANCIAL INSTRUMENTS
The following methods and assumptions were used to estimate the fair value
of each class of financial instruments for which it is practicable to estimate
that value:
o Long-term debt. The fair value of both the Company's and PGE's long-term
debt has been estimated based on the quoted market price as of the
respective dates for the portion of such debt which is publicly traded and,
with respect to the portion of such debt which is not publicly traded, on
the estimated borrowing rate as of the respective dates for long-term debt
of comparable credit quality with similar terms and maturities.
o Preferred stock subject to mandatory redemption. The fair value of PGE's
preferred stock subject to mandatory redemption has been estimated based on
the market value as of the respective dates for preferred stock of
comparable credit quality with similar terms and maturities.
The carrying amounts and estimated fair values of the Company's and PGE's
financial instruments at December 31, 1996 and 1995, were as follows:
[CAPTION]
1996 1995
Carrying Estimated Carrying Estimated
Amount Fair Value Amount Fair Value
(Thousands of Dollars)
[S] [C] [C] [C] [C]
Long-term debt (including current
portion):
Company $ 20,000 $ 20,000 $ 49,906 $ 50,300
PGE 93,721 99,222 170,801 175,431
PERI - - 2,000 2,000
Preferred stock of PGE subject to
mandatory redemption (including
current portion) 819 836 1,760 1,795
The Company believes that the regulatory treatment of any excess or
deficiency of fair value relative to the carrying amounts of these items, if
such items were settled at amounts approximating those above, would dictate that
these amounts be used to increase or reduce PGE's rates over a prescribed
amortization period. Accordingly, any settlement would not result in a material
impact on PGE's financial position or the results of operations of either the
Company or PGE.
ITEM 9. CHANGE IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
-57-
<PAGE>
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
(a) Identification of Directors
The information required by this item concerning directors of the Company
has been omitted from this Form 10-K since the Company expects to file its
definitive proxy statement not later than 120 days after the close of its fiscal
year covered by this Form 10-K.
(b) Identification of Executive Officers
Information concerning the Company's executive officers is set forth in Part
I of this Form 10-K under the heading "Executive Officers of the Company."
ITEM 11. EXECUTIVE COMPENSATION
This information has been omitted from this Form 10-K since the Company
expects to file its definitive proxy statement not later than 120 days after the
close of its fiscal year covered by this Form 10-K.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
This information has been omitted from this Form 10-K since the Company
expects to file its definitive proxy statement not later than 120 days after the
close of its fiscal year covered by this Form 10-K.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
This information has been omitted from this Form 10-K since the Company
expects to file its definitive proxy statement not later than 120 days after the
close of its fiscal year covered by this Form 10-K.
-58-
<PAGE>
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
(a) 1. Financial Statements
The following consolidated financial statements, notes to
consolidated financial statements and report of independent public
accountants for the Company and its subsidiaries are presented in Item
8 of this Form 10-K.
Page
Report of Independent Public Accountants . . . . . . . . . . . 31
Consolidated Balance Sheets as of December 31, 1996 and 1995 . 32
Consolidated Statements of Income for each of the three years
in the period ended December 31, 1996. . . . . . . . . . . . 34
Consolidated Statements of Cash Flows for each of the three
years in the period ended December 31, 1996. . . . . . . . . 35
Consolidated Statements of Capitalization as of December 31,
1996 and 1995. . . . . . . . . . . . . . . . . . . . . . . . 36
Consolidated Statements of Common Shareholders' Investment
for each of the three years in the period ended December
31, 1996 . . . . . . . . . . . . . . . . . . . . . . . . . . 37
Notes to Consolidated Financial Statements . . . . . . . . . . 38
2. Financial Statement Schedules
The following consolidated financial statement schedule for the
Company and its subsidiaries is filed as a part of this Form 10-K.
Schedules not included have been omitted because they are not
applicable or the required information is shown in the consolidated
financial statements or notes thereto.
Schedule Number Page
II Valuation and Qualifying Accounts for the three-year
period ended December 31, 1996 . . . . . . . . . . . . 61
3. Exhibits
See "Index to Exhibits" located on page 63 for a listing of all
exhibits filed herein or incorporated by reference to a previously
filed registration statement or report with the Securities and Exchange
Commission.
-59-
<PAGE>
<TABLE>
<CAPTION>
<S> <C> <C> <C>
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K - continued
(b) Reports on Form 8-K
No reports on Form 8-K were filed during the last quarter of 1996.
(c) Executive Compensation Plans and Arrangements
The following listing includes the Company's executive compensation plans
and arrangements in effect as of December 31, 1996.
Exhibit
10-23 Form of Change in Control Agreement between the Company and certain
of its Officers -- filed as Exhibit 10-38 to the Company's Annual
Report on Form 10-K for 1989, File No. 0-7812.
10-24 First Amendment to Form of Change in Control Agreement, dated as of
May 24, 1995, between the Company and certain of its Officers --
filed as Exhibit 10-29 to the Company's Annual Report on Form 10-K
for 1995, File No. 0-7812.
10-25 Agreement by and between the Company, PGE and Robert L. Jones dated
as of March 15, 1991 -- filed as Exhibit No. 10-44 to the Company's
Annual Report on Form 10-K for 1990, File No. 0-7812.
10-26 Employment Agreement effective September 1, 1995, between the
Company and Dean T. Casaday -- filed as Exhibit 10-2 to the
Company's Quarterly Report on Form 10-Q for the quarter ended
September 30, 1995, File No. 0-7812.
10-27 Supplemental Retirement Agreement, dated as of December 23, 1991,
between the Company and Dean T. Casaday -- filed as Exhibit 10-17 to
the Company's Common Stock Form S-2, Registration No. 33-43382.
10-28 First Amendment to the Supplemental Retirement Agreement, dated as
of September 1, 1994, between the Company and Dean T. Casaday --
filed as Exhibit 10-37 to the Company's Annual Report on Form 10-K
for 1994, File No. 0-7812.
10-29 Pennsylvania Enterprises, Inc. 1992 Stock Option Plan, effective
June 3, 1992 -- filed as Exhibit A to the Company's 1993 definitive
Proxy Statement, File No. 0-7812.
10-30 Employment Agreement dated as of June 26, 1996, by and among the
Company, PGE and Kenneth L. Pollock -- filed as Exhibit 10-1 to the
Company's Quarterly Report on Form 10-Q for the quarter ended
September 30, 1996, File No. 0-7812.
10-31 Employment Agreement dated as of August 28, 1996, by and among the
Company, PGE and Thomas F. Karam -- filed as Exhibit 10-2 to the
Company's Quarterly Report on Form 10-Q for the quarter ended
September 30, 1996, File No. 0-7812.
(d) Statements Excluded from Annual Report to Shareholders
Not applicable.
</TABLE>
-60-
<PAGE>
SCHEDULE II
-61-
<PAGE>
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.
[CAPTION]
PENNSYLVANIA ENTERPRISES, INC.
(Registrant)
[S] [C] [C]
Date: March 6, 1997 By: /s/ Thomas F. Karam
Thomas F. Karam
President and Chief Executive Officer
(Principal Executive Officer)
Date: March 6, 1997 By: /s/ John F. Kell, Jr.
John F. Kell, Jr.
Vice President, Financial Services
(Principal Financial Officer
and Principal Accounting Officer)
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
Registrant and in the capacities and on the dates indicated.
Signature Capacity Date
/s/ Kenneth L. Pollock Chairman of the Board of March 6, 1997
Kenneth L. Pollock Directors
/s/ William D. Davis Vice Chairman of the Board March 6, 1997
William D. Davis of Directors
/s/ Thomas F. Karam Director, President and March 6, 1997
Thomas F. Karam Chief Executive Officer
/s/ Paul R. Freeman Director March 6, 1997
Paul R. Freeman
/s/ Robert J. Keating Director March 6, 1997
Robert J. Keating
/s/ John D. McCarthy Director March 6, 1997
John D. McCarthy
/s/ John D. McCarthy, Jr. Director March 6, 1997
John D. McCarthy, Jr.
/s/ Kenneth M. Pollock Director March 6, 1997
Kenneth M. Pollock
/s/ Richard A. Rose, Jr. Director March 6, 1997
Richard A. Rose, Jr.
/s/ James A. Ross Director March 6, 1997
James A. Ross
/s/ Ronald W. Simms Director March 6, 1997
Ronald W. Simms
-62-
<PAGE>
INDEX TO EXHIBITS
Exhibit
Number
(2) Plan of Acquisition, Reorganization, Arrangement, Liquidation or Succession:
2-1 Asset Purchase Agreement dated as of April 26, 1995, among the
Company, PGE, American Water Works Company, Inc., and Pennsylvania-
American Water Company -- filed as Exhibit 2-1 to PGE's Quarterly
Report on Form 10-Q for the quarter ended March 31, 1995, File No.
1-3490.
(3) Articles of Incorporation and By Laws:
3-1 Restated Articles of Incorporation of the Company, as amended --
filed as Exhibit 3-1 to the Company's Senior Note Form S-2,
Registration No. 33-47581.
3-2 By-Laws of the Company, as amended and restated on January 18, 1995
-- filed as Exhibit 3-2 to the Company's Annual Report on Form 10-K
for 1994, File No. 0-7812.
(4) Instruments Defining the Rights of Security Holders, Including Debentures:
4-1 Indenture of Mortgage and Deed of Trust, dated as of March 15, 1946,
between Scranton-Spring Brook Water Service Company (now PGE) and
First Trust of New York, National Association, as Successor Trustee
to Morgan Guaranty Trust Company of New York -- filed as Exhibit
2(c) to PGE's Bond Form S-7, Registration No. 2-55419.
4-2 Fourth Supplemental Indenture, dated as of March 15, 1952 -- filed
as Exhibit 2(d) to PGE's Bond Form S-7, Registration No. 2-55419.
4-3 Ninth Supplemental Indenture, dated as of March 15, 1957 -- filed as
Exhibit 2(e) to PGE's Bond Form S-7, Registration No. 2-55419.
4-4 Tenth Supplemental Indenture, dated as of September 1, 1958 -- filed
as Exhibit 2(f) to PGE's Bond Form S-7, Registration No. 2-55419.
4-5 Twelfth Supplemental Indenture, dated as of July 15, 1960 -- filed
as Exhibit 2(g) to PGE's Bond Form S-7, Registration No. 2-55419.
4-6 Fourteenth Supplemental Indenture, dated as of December 15, 1961 --
filed as Exhibit 2(h) to PGE's Bond Form S-7, Registration No.
2-55419.
4-7 Fifteenth Supplemental Indenture, dated as of December 15, 1963 --
filed as Exhibit 2(i) to PGE's Bond Form S-7, Registration No.
2-55419.
4-8 Sixteenth Supplemental Indenture, dated as of June 15, 1966 -- filed
as Exhibit 2(j) to PGE's Bond Form S-7, Registration No. 2-55419.
4-9 Seventeenth Supplemental Indenture, dated as of October 15, 1967 --
filed as Exhibit 2(k) to PGE's Bond Form S-7, Registration No.
2-55419.
-63-
<PAGE>
Exhibit
Number
4-10 Eighteenth Supplemental Indenture, dated as of May 1, 1970 -- filed
as Exhibit 2(1) to PGE's Bond Form S-7, Registration No. 2-55419.
4-11 Nineteenth Supplemental Indenture, dated as of June 1, 1972 -- filed
as Exhibit 2(m) to PGE's Bond Form S-7, Registration No. 2-55419.
4-12 Twentieth Supplemental Indenture, dated as of March 1, 1976 -- filed
as Exhibit 2(n) to PGE's Bond Form S-7, Registration No. 2-55419.
4-13 Twenty-first Supplemental Indenture, dated as of December 1, 1976 --
filed as Exhibit 4-16 to PGE's Annual Report on Form 10-K for 1982,
File No. 1-3490.
4-14 Twenty-second Supplemental Indenture, dated as of August 15, 1989 --
filed as Exhibit 4-22 to the Company's Annual Report on Form 10-K
for 1989, File No. 0-7812.
4-15 Twenty-third Supplemental Indenture, dated as of August 15, 1989 --
filed as Exhibit 4-23 to the Company's Annual Report on Form 10-K
for 1989, File No. 0-7812.
4-16 Twenty-fourth Supplemental Indenture, dated as of September 1, 1991,
-- filed as Exhibit 4-3 to the Company's Common Stock Form S-2,
Registration No. 33-43382.
4-17 Twenty-fifth Supplemental Indenture, dated as of September 1, 1992,
-- filed as Exhibit 4-17 to the Company's Annual Report on Form 10-K
for 1992, File No. 0-7812.
4-18 Twenty-sixth Supplemental Indenture, dated as of December 1, 1992,
-- filed as Exhibit 4-18 to the Company's Annual Report on Form 10-K
for 1992, File No. 0-7812.
4-19 Twenty-seventh Supplemental Indenture, dated as of December 1, 1992,
-- filed as Exhibit 4-19 to the Company's Annual Report on Form 10-K
for 1992, File No. 0-7812.
4-20 Twenty-eighth Supplemental Indenture, dated as of December 1, 1993,
-- filed as Exhibit 4-20 to PGE's Annual Report on Form 10-K for
1993, File No. 1-3490.
4-21 Twenty-ninth Supplemental Indenture, dated as of November 1, 1994,
-- filed as Exhibit 4-21 to PGE's Annual Report on Form 10-K for
1994, File No. 1-3490.
4-22 Thirtieth Supplemental Indenture, dated as of December 1, 1995, --
filed as Exhibit 4-22 to PGE's Annual Report on Form 10-K for 1995,
File No. 1-3490.
NOTE: The First, Second, Third, Fifth, Sixth, Seventh, Eighth,
Eleventh and Thirteenth Supplemental Indentures merely convey
additional properties to the Trustee.
-64-
<PAGE>
Exhibit
Number
4-23 Rights Agreement dated as of April 26, 1995, between the Company and
Chemical Bank, as Rights Agent -- filed as Exhibit 4-1 to the
Company's Quarterly Report on Form 10-Q for the quarter ended March
31, 1995, File No. 0-7812.
(10) Material Contracts:
10-1 Service Agreement for storage service under Rate Schedule LGA, dated
August 6, 1974, between PGE and Transcontinental Gas Pipe Line
Corporation -- filed as Exhibit 10-3 to PGE's Annual Report on Form
10-K for 1984, File No. 1-3490.
10-2 Service Agreement for transportation service under Rate Schedule FT,
dated February 1, 1992, by and between PGE and Transcontinental Gas
Pipe Line Corporation -- filed as Exhibit 10-4 to PGE's Annual
Report on Form 10-K for 1991, File No. 1-3490.
10-3 Service Agreement for storage service under Rate Schedule SS-2,
dated April 1, 1990, between PGE and Transcontinental Gas Pipe Line
Corporation -- filed as Exhibit 10-8 to the Company's Common Stock
Form S-2, Registration No. 33-43382.
10-4 Service Agreement for sales service under Rate Schedule FS, dated
August 1, 1991, between PGE and Transcontinental Gas Pipe Line
Corporation -- filed as Exhibit 10-6 to the Company's Annual Report
on Form 10-K for 1991, File No. 0-7812.
10-5 Service Agreement for transportation service under Rate Schedule FT,
dated August 1, 1991, between PGE and Transcontinental Gas Pipe Line
Corporation -- filed as Exhibit 10-10 to the Company's Common Stock
Form S-2, Registration No. 33-43382.
10-6 Service Agreement for transportation service under Rate Schedule IT,
dated January 31, 1992, between PGE and Transcontinental Gas
Pipeline Corporation -- filed as Exhibit 10-8 to the Company's
Annual Report on Form 10-K for 1991, File No. 0-7812.
10-7 Service Agreement for storage service under Rate Schedule LSS, dated
October 1, 1993, by and between PGE and Transcontinental Gas Pipe
Line Corporation -- filed as Exhibit 10-7 to PGE's Annual Report on
Form 10-K for 1993, File No. 1-3490.
10-8 Service Agreement for storage service under Rate Schedule GSS, dated
October 1, 1993, by and between PGE and Transcontinental Gas
Pipeline Corporation Company -- filed as Exhibit 10-8 to PGE's
Annual Report on Form 10-K for 1993, File No. 1-3490.
-65-
<PAGE>
Exhibit
Number
10-9 Service Agreement for transportation service under Rate Schedule
FTS, dated November 1, 1993, by and between PGE and Columbia Gas
Transmission Corporation -- filed as Exhibit 10-9 to PGE's Annual
Report on Form 10-K for 1993, File No. 1-3490.
10-10 Service Agreement for transportation service under Rate Schedule
SST, dated November 1, 1993, by and between PGE and Columbia Gas
Transmission Corporation -- filed as Exhibit 10-10 to PGE's Annual
Report on Form 10-K for 1993, File No. 1-3490.
10-11 Service Agreement for storage service under Rate Schedule FSS, dated
November 1, 1993, by and between PGE and Columbia Gas Transmission
Corporation -- filed as Exhibit 10-11 to PGE's Annual Report on Form
10-K for 1993, File No. 1-3490.
10-12 Service Agreement for transportation service under Rate Schedule
FTS-1, dated November 1, 1993, by and between PGE and Columbia Gulf
Transmission Company -- filed as Exhibit 10-12 to PGE's Annual
Report on Form 10-K for 1993, File No. 1-3490.
10-13 Service Agreement for transportation service under Rate Schedule
ITS-1, dated November 1, 1993, by and between PGE and Columbia Gulf
Transmission Company -- filed as Exhibit 10-13 to PGE's Annual
Report on Form 10-K for 1993, File No. 1-3490.
10-14 Service Agreement for transportation service under Rate Schedule
ITS, dated November 1, 1993, by and between PGE and Columbia Gas
Transmission Corporation -- filed as Exhibit 10-14 to PGE's Annual
Report on Form 10-K for 1993, File No. 1-3490.
10-15 Service Agreement (Contract No. 946) for transportation service
under Rate Schedule FT-A, dated September 1, 1993, by and between
PGE and Tennessee Gas Pipeline Company -- filed as Exhibit 10-1 to
PGE's Quarterly Report on Form 10-Q for the quarter ended September
30, 1993, File No. 1-3490.
10-16 Service Agreement (Service Package No. 171) for transportation
service under Rate Schedule FT-A, dated September 1, 1993, by and
between PGE and Tennessee Gas Pipeline Company -- filed as Exhibit
10-2 to PGE's Quarterly Report on Form 10-Q for the quarter ended
September 30, 1993, File No. 1-3490.
10-17 Service Agreement (Service Package No. 187) for transportation
service under Rate Schedule FT-A, dated September 1, 1993, by and
between PGE and Tennessee Gas Pipeline Company -- filed as Exhibit
10-3 to PGE's Quarterly Report on Form 10-Q for the quarter ended
September 30, 1993, File No. 1-3490.
10-18 Service Agreement (Service Package No. 190) for transportation
service under Rate Schedule FT-A, dated September 1, 1993, by and
between PGE and Tennessee Gas Pipeline -- filed as Exhibit 10-4 to
PGE's Quarterly Report on Form 10-Q for the quarter ended September
30, 1993, File No. 1-3490.
-66-
<PAGE>
Exhibit
Number
10-19 Service Agreement (Contract No. 2289) for storage service under Rate
Schedule FS, dated September 1, 1993, by and between PGE and
Tennessee Gas Pipeline -- filed as Exhibit 10-5 to PGE's Quarterly
Report on Form 10-Q for the quarter ended September 30, 1993, File
No. 1-3490.
10-20 Service Agreement for transportation service under Rate Schedule FT,
dated April 1, 1995, by and between PGE and Transcontinental Gas
Pipe Line Corporation -- filed as Exhibit 10-1 to PGE's Quarterly
Report on Form 10-Q for the quarter ended March 31, 1995, File No.
1-3490.
10-21 Service Agreement for storage service dated October 13, 1995, by and
between PGE and Avoca Natural Gas Storage -- filed as Exhibit 10-1
to PGE's Quarterly Report on Form 10-Q for the quarter ended
September 30, 1995, File No. 1-3490.
10-22 Bond Purchase Agreement, dated September 1, 1989, relating to PGE's
First Mortgage Bonds 9.23% Series due 1999 and First Mortgage Bonds
9.34% Series due 2019 among Allstate Life Insurance Company,
Allstate Life Insurance Company of New York and PGE -- filed as
Exhibit 10-34 to the Company's Annual Report on Form 10-K for 1989,
File No. 0-7812.
10-23 Form of Change in Control Agreement between the Company and certain
of its Officers -- filed as Exhibit 10-38 to the Company's Annual
Report on Form 10-K for 1989, File No. 0-7812.
10-24 First Amendment to Form of Change in Control Agreement, dated as of
May 24, 1995, between the Company and certain of its Officers --
filed as Exhibit 10-29 to the Company's Annual Report on Form 10-K
for 1995, File No. 0-7812.
10-25 Agreement, dated as of March 15, 1991, by and between the Company,
PGE and Robert L. Jones -- filed as Exhibit 10-38 to the Company's
Annual Report on Form 10-K for 1990, File No. 0-7812.
10-26 Employment Agreement effective September 1, 1995, between the
Company and Dean T. Casaday -- filed as Exhibit 10-2 to the
Company's Quarterly Report on Form 10-Q for the quarter ended
September 30, 1995, File No. 0-7812.
10-27 Supplemental Retirement Agreement, dated as of December 23, 1991,
between the Company and Dean T. Casaday -- filed as Exhibit 10-17 to
the Company's Common Stock Form S-2, Registration No. 33-43382.
10-28 First Amendment to the Supplemental Retirement Agreement, dated as
of September 1, 1994, between the Company and Dean T. Casaday --
filed as Exhibit 10-37 to the Company's Annual Report on Form 10-K
for 1994, File No. 0-7812.
10-29 Pennsylvania Enterprises, Inc. 1992 Stock Option Plan, effective
June 3, 1992 - filed as Exhibit A to the Company's 1993 definitive
Proxy Statement, File No. 0-7812.
-67-
<PAGE>
Exhibit
Number
10-30 Employment Agreement dated as of June 26, 1996, by and among the
Company, PGE and Kenneth L. Pollock -- filed as Exhibit 10-1 to the
Company's Quarterly Report on Form 10-Q for the quarter ended
September 30, 1996, File No. 0-7812.
10-31 Employment Agreement dated as of August 28, 1996, by and among the
Company, PGE and Thomas F. Karam -- filed as Exhibit 10-2 to the
Company's Quarterly Report on Form 10-Q for the quarter ended
September 30, 1996, File No. 0-7812.
(11) Statement Re Computation of Per Share Earnings:
11-1 Statement Re Computation of Per Share Earnings -- filed herewith.
(21) Subsidiaries of the Registrant:
21-1 Subsidiaries of the Registrant -- filed herewith.
(23) Consents of Experts and Counsel:
23-1 Consent of Independent Public Accountants -- filed herewith.
-68-
<PAGE>
TABLE OF CONTENTS
<TABLE>
<CAPTION>
PART I PAGE
<S> <C>
Item l. BUSINESS . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Item 2. PROPERTIES . . . . . . . . . . . . . . . . . . . . . . . . . . 13
Item 3. LEGAL PROCEEDINGS . . . . . . . . . . . . . . . . . . . . . . 13
Item 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS . . . . . 13
PART II
Item 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED
STOCKHOLDER MATTERS . . . . . . . . . . . . . . . . . . . . 14
Item 6. SELECTED FINANCIAL DATA . . . . . . . . . . . . . . . . . . . 15
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS . . . . . . . . . . . . 18
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA . . . . . . . . . 30
Item 9. CHANGE IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
ACCOUNTING AND FINANCIAL DISCLOSURE . . . . . . . . . . . . 57
PART III
Item 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT . . . . . . 58
Item 11. EXECUTIVE COMPENSATION . . . . . . . . . . . . . . . . . . . . 58
Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL
OWNERS AND MANAGEMENT . . . . . . . . . . . . . . . . . . . 58
Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS . . . . . . . . 58
PART IV
Item 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS
ON FORM 8-K . . . . . . . . . . . . . . . . . . . . . . . . 59*
SIGNATURES . . . . . . . . . . . . . . . . . . . . . . . . . . 62
________________________
* The "Index to Exhibits" is located on page 63.
</TABLE>
<PAGE>
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.
<TABLE>
<CAPTION>
PENNSYLVANIA ENTERPRISES, INC.
(Registrant)
<S> <C> <C>
Date: March 6, 1997 By:
Thomas F. Karam
President and Chief Executive Officer
(Principal Executive Officer)
Date: March 6, 1997 By:
John F. Kell, Jr.
Vice President, Financial Services
(Principal Financial Officer
and Principal Accounting Officer)
</TABLE>
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
Registrant and in the capacities and on the dates indicated.
Signature Capacity Date
Chairman of the Board of March 6, 1997
Kenneth L. Pollock Directors
Vice Chairman of the Board March 6, 1997
William D. Davis of Directors
Director, President and March 6, 1997
Thomas F. Karam Chief Executive Officer
Director March 6, 1997
Paul R. Freeman
Director March 6, 1997
Robert J. Keating
Director March 6, 1997
John D. McCarthy
Director March 6, 1997
John D. McCarthy, Jr.
Director March 6, 1997
Kenneth M. Pollock
Director March 6, 1997
Richard A. Rose, Jr.
Director March 6, 1997
James A. Ross
Director March 6, 1997
Ronald W. Simms
<PAGE>
(THIS PAGE INTENTIONALLY LEFT BLANK)
<PAGE>
<TABLE>
<CAPTION>
PENNSYLVANIA ENTERPRISES, INC. AND SUBSIDIARIES
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
FOR THE THREE-YEAR PERIOD ENDED DECEMBER 31, 1996
Balance at Charged Charged Balance
beginning to to other at end
Description of year income accounts Deductions of year
<S> <C> <C> <C> <C> <C>
(Thousands of Dollars)
Deducted from the asset to which it applies:
Reserve for uncollectible accounts-
Year ended December 31, 1996 $ 788 $ 2,103 $ - $ 1,658(a) $ 1,233
Year ended December 31, 1995 $ 937 $ 1,538 $ - $ 1,687(a) $ 788
Year ended December 31, 1994 $ 817 $ 1,776 $ - $ 1,656(a) $ 937
Shown as operating reserves on the consolidated
balance sheets:
Insurance -
Year ended December 31, 1996 $ 3,709 $ 1,042 $ - $ 1,665(b) $ 3,086
Year ended December 31, 1995 $ 2,383 $ 2,652 $ - $ 1,326(b) $ 3,709
Year ended December 31, 1994 $ 1,863 $ 1,695 $ - $ 1,175(b) $ 2,383
NOTES:
(a) Deductions represent uncollectible balances of accounts receivable written off, net of recoveries.
(b) Deductions are principally payments made in settlement of claims.
</TABLE>
<PAGE>
EXHIBIT 11-1
PENNSYLVANIA ENTERPRISES, INC.
Statement Re Computation of Per Share Earnings for the
Twelve Month Periods Ended December 31, 1996 and 1995
[CAPTION]
Twelve Months Ended
1996 1995
[S] [C] [C]
Income before subsidiary's
preferred stock dividends $ 8,314,000 $ 2,050,000
Subsidiary's preferred stock dividends 1,730,000 2,763,000
Net income $ 6,584,000 $ (713,000)
Earnings per share of common stock (1)(2) $ .51 $ (.06)
Computations of additional common shares
outstanding (1)
Average shares of common stock 10,222,002 11,458,872
Incremental common shares applicable to
options, based on the daily average
market price 20,684 5,208
Average common shares as adjusted 10,242,686 11,464,080
Average shares of common stock 10,222,002 11,458,872
Incremental common shares applicable to
options, based on the more dilutive of
daily average or ending market price 17,634 8,190
Average common shares fully diluted 10,239,636 11,467,062
Earnings per share of common stock (1)
Average common shares as adjusted $ .51 $ (.06)
Average common shares fully diluted $ .51 $ (.06)
(1) Restated to reflect the two-for-one split of the Company's common stock
effective March 20, 1997.
(2) Reflects the effect of premiums totaling $1,337,012 on the redemption
of subsidiary's preferred stock in 1996 that were charged to retained
earnings and not included in the determination of net income.
<PAGE>
<TABLE> <S> <C>
<ARTICLE> UT
<LEGEND>
THIS STATEMENT CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM THE
BALANCE SHEET, STATEMENTS OF INCOME AND CASH FLOW, AND IS QUALIFIED IN ITS
ENTIRETY BY REFERENCE TO SUCH STATEMENTS.
</LEGEND>
<CIK> 0000077231
<NAME> PENNSYLVANIA ENTERPRISES, INC.
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> DEC-31-1996
<PERIOD-END> DEC-31-1996
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 239,422,000
<OTHER-PROPERTY-AND-INVEST> 9,548,000
<TOTAL-CURRENT-ASSETS> 82,297,000
<TOTAL-DEFERRED-CHARGES> 35,543,000
<OTHER-ASSETS> 0
<TOTAL-ASSETS> 366,810,000
<COMMON> 48,040,000
<CAPITAL-SURPLUS-PAID-IN> 20,391,000
<RETAINED-EARNINGS> 49,220,000
<TOTAL-COMMON-STOCKHOLDERS-EQ> 117,651,000
739,000
18,851,000
<LONG-TERM-DEBT-NET> 75,000,000
<SHORT-TERM-NOTES> 10,000,000
<LONG-TERM-NOTES-PAYABLE> 0
<COMMERCIAL-PAPER-OBLIGATIONS> 0
<LONG-TERM-DEBT-CURRENT-PORT> 38,721,000
115,000
<CAPITAL-LEASE-OBLIGATIONS> 0
<LEASES-CURRENT> 0
<OTHER-ITEMS-CAPITAL-AND-LIAB> 105,733,000
<TOT-CAPITALIZATION-AND-LIAB> 366,810,000
<GROSS-OPERATING-REVENUE> 184,480,000
<INCOME-TAX-EXPENSE> 5,800,000
<OTHER-OPERATING-EXPENSES> 160,420,000
<TOTAL-OPERATING-EXPENSES> 166,220,000
<OPERATING-INCOME-LOSS> 18,260,000
<OTHER-INCOME-NET> 1,726,000
<INCOME-BEFORE-INTEREST-EXPEN> 19,986,000
<TOTAL-INTEREST-EXPENSE> 10,192,000
<NET-INCOME> 8,314,000
1,730,000
<EARNINGS-AVAILABLE-FOR-COMM> 6,584,000
<COMMON-STOCK-DIVIDENDS> 11,174,000
<TOTAL-INTEREST-ON-BONDS> 4,837,000
<CASH-FLOW-OPERATIONS> (52,983,000)
<EPS-PRIMARY> .51
<EPS-DILUTED> .51
</TABLE>
EXHIBIT 21-1
PENNSYLVANIA ENTERPRISES, INC. AND SUBSIDIARIES
Subsidiaries of the Registrant
The following are subsidiaries of the Registrant. Their voting securities
are owned 100% by the Registrant. All of the subsidiaries are incorporated in
Pennsylvania.
PG Energy Inc.
Pennsylvania Energy Resources, Inc.
Theta Land Corporation
Pennsylvania Energy Marketing Company
Penn Gas Development Co.*
Keystone Pipeline Services, Inc.**
Honesdale Gas Company***
* A subsidiary of PG Energy Inc. accounted for on the equity method which has
not been consolidated since it is insignificant.
** A subsidiary of Pennsylvania Energy Resources, Inc. ("PERI") included in the
consolidation of PERI into the Registrant.
*** A subsidiary of PG Energy Inc. acquired on February 14, 1997.
<PAGE>
Exhibit 23-1
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
ON SUPPLEMENTAL SCHEDULE
To Pennsylvania Enterprises, Inc.:
We have audited in accordance with generally accepted auditing
standards, the consolidated financial statements included in Pennsylvania
Enterprises, Inc.'s 1996 Annual Report to Shareholders incorporated by
reference in this Form 10-K, and have issued our report thereon dated
February 19, 1997. Our audit was made for the purpose of forming an
opinion on those consolidated financial statements taken as a whole.
Supplemental Schedule II, Valuation and Qualifying Accounts for the three-
year period ended December 31, 1996 (see index of financial statements) is
presented for purposes of complying with the Securities and Exchange
Commissions rules and is not part of the basic consolidated financial
statements. This schedule has been subjected to the auditing procedures
applied in the audit of the basic consolidated financial statements and, in
our opinion, fairly states in all material respects the financial data
required to be set forth therein in relation to the basic consolidated
financial statements taken as a whole.
ARTHUR ANDERSEN LLP
New York, N.Y.
February 19, 1997
<PAGE>
