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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D. C. 20549
FORM 10-K
X ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
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SECURITIES EXCHANGE ACT OF 1934
For the Fiscal Year Ended June 30, 1995
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
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SECURITIES EXCHANGE ACT OF 1934
Commission File No. 1-6407
SOUTHERN UNION COMPANY
(Exact name of registrant as specified in its charter)
Delaware 75-0571592
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
504 Lavaca Street, Eighth Floor 78701
Austin, Texas (Zip Code)
(Address of principal executive offices)
Registrant's telephone number, including area code:
(512) 477-5852
Securities Registered Pursuant to Section 12(b) of the Act:
Title of each class Name of each exchange on which registered
- ------------------- -----------------------------------------
Common Stock, par New York Stock Exchange
value $1 per share
Securities Registered Pursuant to Section 12(g) of the Act: None
Indicate by check mark whether the registrant (1) has filed all
reports required to be filed by Section 13 or 15(d) of the
Securities Exchange Act of 1934 during the preceding 12 months
(or for such shorter period that the registrant was required to
file such reports), and (2) has been subject to such filing
requirements for the past 90 days. Yes X No
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Indicate by check mark if disclosure of delinquent filers pursu-
ant to Item 405 of Regulation S-K is not contained herein, and
will not be contained, to the best of registrant's knowledge, in
definitive proxy or information statements incorporated by
reference in Part III of this Form 10-K or any amendment to this
Form 10-K. X
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The aggregate market value of the voting stock held by non-
affiliates of the registrant on September 22, 1995, was approxi-
mately $125,747,641. The number of shares of the registrant's
Common Stock outstanding on September 22, 1995 was 11,518,622.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant's proxy statement for its annual
meeting of stockholders to be held on November 7, 1995 are
incorporated by reference into Part III hereof, to the extent
indicated herein.
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PART I
ITEM 1. Business.
Introduction
Southern Union Company ("Southern Union" and together with its
subsidiaries, the "Company") was incorporated under the laws of
the State of Delaware in 1932. The Company's principal line of
business is the distribution of natural gas as a public utility
through Southern Union Gas and Missouri Gas Energy, each of which
is a division of Southern Union. Southern Union Gas, head-
quartered in Austin, Texas, serves approximately 498,000 residen-
tial, commercial, industrial, agricultural and other customers in
Texas (including the cities of Austin, Brownsville, El Paso,
Galveston and Port Arthur) and Oklahoma. Missouri Gas Energy,
headquartered in Kansas City, Missouri, serves approximately
478,000 customers in central and western Missouri (including the
cities of Kansas City, St. Joseph, Joplin and Monett). See
"Missouri Acquisition."
Subsidiaries of Southern Union have been established to support
and expand natural gas sales and to capitalize on the Company's
gas energy expertise. These subsidiaries market natural gas to
end-users, sell natural gas as a vehicular fuel, operate intra-
state and interstate natural gas pipeline systems, sell commer-
cial gas air conditioning and other gas-fired engine-driven
applications and convert vehicles to operate on natural gas. By
providing "one-stop shopping," the Company can serve its various
customers' specific energy needs, which encompass substantially
all of the natural gas distribution and sales businesses from
natural gas sales to specialized energy consulting services.
Certain subsidiaries also own or hold interests in real estate
and other assets, which are primarily used in the Company's
utility business. See "Company Operations."
The Company is a sales and market-driven energy company whose
management is committed to achieving profitable growth of its
natural gas energy businesses in an increasingly competitive
business environment. Management's strategies for achieving
these objectives principally consist of: (i) promoting new sales
opportunities and markets for natural gas; (ii) enhancing finan-
cial and operating performance; and (iii) expanding the Company
through development of existing systems and selective acquisition
of new systems. Management develops and continually evaluates
these strategies and the Company's implementation of them by
applying their experience and expertise in analyzing the energy
industry, technological advances, market opportunities and
general business trends. Each of these strategies, as imple-
mented throughout the Company's businesses, reflects the Com-
pany's commitment to its core natural gas utility business.
Central to all of the Company's businesses and strategies is the
sale and transportation of natural gas.
The Company has a goal of selected growth and expansion, pri-
marily in the natural gas industry. To that extent, the Company
intends to consider, when appropriate, and if financially prac-
ticable to pursue, the acquisition of other natural gas distri-
bution or transmission businesses. The nature and location of
any such properties, the structure of any such acquisitions, and
the method of financing any such expansion or growth will be
determined by management and the Southern Union Board of
Directors.
Missouri Acquisition
On January 31, 1994, Southern Union purchased certain Missouri
natural gas distribution operations (the "Missouri Acquisition")
which Southern Union operates as Missouri Gas Energy. The
acquisition was accounted for as a purchase. Earnings from
operations of Missouri Gas Energy have been included in the Com-
pany's statement of consolidated operations since February 1,
1994.
At closing, Southern Union paid approximately $400,300,000 in
cash, based on account balances as of December 31, 1993. The
final purchase price, which was determined through post-closing
adjustments and subsequent arbitration, was approximately
$401,600,000. The Missouri Acquisition was financed through the
sale of $475,000,000 of 7.60% Senior Notes due 2024 (the "Senior
Debt Securities") completed on January 31, 1994 and net proceeds
from a $50,000,000 common stock subscription rights offering (the
"Rights Offering") completed on December 31, 1993. See "Man-
agement's Discussion and Analysis of Financial Condition and
Results of Operations ("MD&A") -- Liquidity and Capital
Resources" and "Long-Term Debt" in the Notes to the Consolidated
Financial Statements.
As a result of the Missouri Acquisition, the Company nearly
doubled the number of customers served by its natural gas dis-
tribution system and became one of the top 15 gas utilities in
the United States, as measured by number of customers. In addi-
tion, the Missouri Acquisition lessens the sensitivity of the
Company's operations to weather risk and local economic condi-
tions by diversifying operations into a different geographic
area.
The approval of the Missouri Acquisition by the Missouri Public
Service Commission ("MPSC") was subject to the terms of a stipu-
lation and settlement agreement (the "MPSC Stipulation") among
Southern Union, Western Resources, Inc. (the "seller" of the
Missouri properties), the MPSC Staff and others. Among other
things, the MPSC Stipulation: (i) provides that the Company
attain a total debt to total capital ratio that does not exceed
Standard and Poor's Corporation's Utility Financial Benchmark
ratio for the lowest investment grade (BBB) investor-owned
natural gas distribution company (which currently is approxi-
mately 58%) in order for Missouri Gas Energy to implement any
general rate increase; (ii) prohibits Missouri Gas Energy from
implementing a general rate increase in Missouri before
January 31, 1997 except in certain unusual events; (iii) required
the seller to contribute an additional $9,000,000 to the quali-
fied defined benefit plan assets transferred to the Company; (iv)
requires the Company to contribute an additional $3,000,000 to
the Company's qualified defined benefit plan for the benefit of
Missouri Gas Energy's employees and retirees; and (v) requires
Missouri Gas Energy to reduce rate base by $30,000,000 (amortized
over a ten-year period on a straight-line basis) to compensate
rate payers for rate base reductions that were eliminated as a
result of the Missouri Acquisition. The Company has subsequently
attained the financial benchmark ratio described above. See
"Business -- Changes in Capital Structure."
Southern Union assumed certain liabilities of the seller with
respect to the Missouri properties, including certain liabilities
arising from certain specified contracts assigned to Southern
Union at closing, including gas supply and transportation con-
tracts, office equipment and real estate leases, liabilities
arising from certain contracts entered into by the seller in the
ordinary course of business, certain liabilities that have arisen
or may arise from the operation of Missouri Gas Energy, and
liabilities for certain accounts payable of the seller pertaining
to Missouri Gas Energy.
Southern Union and the seller also entered into an Environmental
Liability Agreement (the "Environmental Liability Agreement") at
the closing of the Missouri Acquisition. The Environmental
Liability Agreement provides for a tiered approach to the allo-
cation of certain liabilities under environmental laws that may
exist or arise with respect to Missouri Gas Energy. At the
present time, and based upon information available to management,
the Company believes that the costs of any remediation efforts
that may be required for Missouri Gas Energy for which it may
ultimately have responsibility will not exceed the aggregate
amount subject to substantial sharing by the seller. The Com-
pany believes that it will be able to obtain substantial reim-
bursement or recovery for any environmental liabilities from
other potentially responsible third parties, under insurance or
through rates charged to customers. See "Commitments and Con-
tingencies" in the Notes to the Consolidated Financial State-
ments.
Pursuant to the terms of an Employee Agreement with the seller,
after the closing of the Missouri Acquisition, Southern Union
employed certain employees of the seller involved in the opera-
tion of Missouri Gas Energy ("Continuing Employees"). Under the
terms of the Employee Agreement, the assets and liabilities under
the seller's qualified defined benefit plans attributable to
Continuing Employees and certain retired Missouri employees
("Retired Employees") were transferred to a qualified defined
benefit plan of Southern Union that for at least two years will
provide benefits to Continuing Employees and Retired Employees
substantially similar in aggregate to those provided for under
the seller's qualified defined benefit plans. Southern Union
amended its qualified defined benefit plan to cover the Con-
tinuing Employees and Retired Employees and provide Continuing
Employees and Retired Employees with certain welfare, separation
and other benefits.
Other Acquisitions and Divestitures
During July 1995, Southern Union Company entered into a letter of
intent to sell Western Gas Interstate Company ("WGI"), a wholly-
owned subsidiary of the Company, exclusive of certain WGI assets
in El Paso, Texas and WGI's Del Norte interconnect operation
which transmits natural gas into Mexico, and to sell certain gas
distribution operations of Southern Union Gas in the panhandle
areas of Texas and Oklahoma for approximately $14,800,000. The
sale is subject to approval by the Federal Regulatory Energy
Commission ("FERC") and the Oklahoma Corporation Commission and
must be reported to the Railroad Commission of Texas.
In September 1993, the Company acquired the Rio Grande Valley Gas
Company ("Rio Grande") for approximately $30,500,000 (the "Rio
Grande Acquisition"). Rio Grande currently serves approximately
75,000 customers in the south Texas counties of Willacy, Cameron
and Hidalgo which includes 32 towns and cities along the Mexico
border, including Harlingen, McAllen and Brownsville (the
southernmost city in the continental U.S.). The Company
initially funded the purchase with borrowings from its revolving
credit facility which were subsequently repaid with proceeds from
the sale of the Senior Debt Securities and the Rights Offering.
See "MD&A -- Liquidity and Capital Resources."
In July 1993, the Company acquired the natural gas distribution
facilities serving the city of Eagle Pass, Texas (the "Eagle Pass
Acquisition"), for approximately $2,000,000. In May 1993, the
Company acquired the natural gas distribution facilities of Berry
Gas Company (the "Berry Gas Acquisition") serving the Texas
cities and towns of Nome, Raywood, Hull and Devers for approxi-
mately $274,000. Combined, these operations serve approximately
4,400 customers.
In February 1993, Southern Union Exploration Company ("SX"), a
former wholly-owned subsidiary of Southern Union, entered into a
purchase and sale agreement pursuant to which it sold substan-
tially all of its oil and gas leasehold interests and associated
production for approximately $22,000,000, effective January 1,
1993. The Company recorded a book loss on the sale of approxi-
mately $4,400,000 as of December 31, 1992. In connection with
the sale, the Company recorded an income tax liability of
approximately $6,960,000 resulting from the recognition of a tax
basis gain of approximately $18,800,000.
Changes in Capital Structure
On May 17, 1995, Southern Union Financing I (the "Subsidiary
Trust"), a consolidated wholly-owned subsidiary of Southern
Union, issued $100,000,000 of 9.48% Trust Originated Preferred
Securities (the "Preferred Securities"). In connection with the
Subsidiary Trust's issuance of the Preferred Securities and the
related purchase by Southern Union of all of the Subsidiary
Trust's common securities (the "Common Securities"), Southern
Union issued to the Subsidiary Trust $103,092,800 principal
amount of its 9.48% Subordinated Deferrable Interest Notes,
due 2025 (the "Subordinated Notes"). The sole assets of the
Subsidiary Trust are and will be the Subordinated Notes. The
interest and other payment dates on the Subordinated Notes
correspond to the distribution and other payment dates on the
Preferred Securities and the Common Securities. Under certain
circumstances, the Subordinated Notes may be distributed to
holders of the Preferred Securities and holders of the Common
Securities in liquidation of the Subsidiary Trust. The Sub-
ordinated Notes are redeemable at the option of the Company
on or after May 17, 2000, at a redemption price of $25 per
Subordinated Note plus accrued and unpaid interest. The
Preferred Securities and the Common Securities will be
redeemed on a pro rata basis to the same extent as the Sub-
ordinated Notes are repaid, at $25 per Preferred Security
and Common Security plus accumulated and unpaid distribu-
tions. Southern Union's obligations under the Subordinated
Notes and related agreements, taken together, constitute a
full and unconditional guarantee by Southern Union of payments
due on the Preferred Securities. As of June 30, 1995,
4,000,000 shares of Preferred Securities were outstanding.
Southern Union has the right under the Subordinated Notes to
defer interest payment periods up to 20 consecutive quarters,
and, as a consequence, quarterly distributions on the Preferred
Securities may be deferred (but will continue to accrue with
interest thereon at a per annum rate of 9.48% compounded quar-
terly) by the Subsidiary Trust during any such extended interest
payment period. If interest payments are deferred by Southern
Union, Southern Union: (i) may not pay cash dividends, or redeem,
purchase or acquire, or make a liquidation payment with respect
to, any of its capital stock or the capital stock of any sub-
sidiary of Southern Union; and (ii) shall not make any payment of
interest, principal or premium, if any, on or repay, repurchase
or redeem any debt securities issued by Southern Union that rank
pari passu with or junior to the subordinate debentures.
The issuance of the Preferred Securities was part of a
$300,000,000 shelf registration filed with the Securities and
Exchange Commission on March 29, 1995. Southern Union may sell a
combination of preferred securities of financing trusts and
senior and subordinated debt securities of Southern Union of up
to $196,907,200 (the remaining shelf) from time to time, at
prices determined at the time of any offering. The net proceeds
from the $100,000,000 Preferred Securities offering have been
used to repurchase $35,000,000 of 7.60% Senior Debt Securities
through July 1995. The remaining proceeds will be used to
repurchase additional long-term debt, provide working capital for
seasonal needs or for other business opportunities. See
"Preferred Securities of Subsidiary Trust" and "Long-Term Debt"
in
the Notes to the Consolidated Financial Statements.
The following table sets forth the summary capitalization of the
Company.
July 31, 1995 June 30, 1995
Amount Percent Amount Percent
------ ------- ------ -------
(thousands, except percentages)
Short-term debt (1)........ $ 2,370 $ 770
======== ========
Long-term debt
Senior notes............. 440,000 460,000
First mortgage bonds
and other.............. 2,503 2,503
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442,503 57.7% 462,503 58.7%
Company-obligated Preferred
Securities of Trust(2)..... 100,000 13.0 100,000 12.7
Common stockholders'
equity................... 223,966 29.3 225,664 28.6
-------- ----- -------- -----
Total capitalization....... $766,469 100.0% $788,167 100.0%
======== ===== ======== =====
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(1) Includes amounts payable under the revolving credit facility
and long-term debt due within one year. The outstanding
balance under the revolving credit facility at July 31, 1995
and June 30, 1995 was $1,600,000 and zero, respectively.
(2) See "Preferred Securities of Subsidiary Trust" in the Notes
to the Consolidated Financial Statements.
Company Operations
The Company's principal line of business is the distribution of
natural gas through its Southern Union Gas and Missouri Gas
Energy divisions. Southern Union Gas provides service to a num-
ber of communities and rural areas in Texas, including the
municipalities of Austin, Brownsville, El Paso, Galveston,
Harlingen, McAllen and Port Arthur, as well as several communi-
ties in the Oklahoma panhandle. Missouri Gas Energy provides
service to various cities and communities in central and western
Missouri including Kansas City, St. Joseph, Joplin and Monett.
The Company's gas utility operations are generally seasonal in
nature, with a significant percentage of its annual revenues and
earnings occurring in the traditional winter heating season.
Western Gas Interstate Company operates interstate pipeline sys-
tems principally serving the Company's gas distribution
properties in the El Paso, Texas area and in the Texas and
Oklahoma panhandles. During 1993, WGI received approval in its
restructuring and rate case dockets from the FERC which allowed
WGI to implement services pursuant to FERC Order No. 636. WGI is
now providing unbundled transportation service for those gas
volumes entering the pipeline's transportation system. WGI also
transported approximately 16,400 million cubic feet (MMcf) to the
city of Juarez, Mexico and the Samalayuca Power Plant in north
Mexico in fiscal 1995. The sale of WGI, exclusive of its Del
Norte interconnect operation and various assets in El Paso, is
pending. See "Business -- Other Acquisitions and Divestitures."
Southern Transmission Company ("Southern"), a wholly-owned sub-
sidiary of Southern Union, owns and operates approximately 121
miles of intrastate pipeline. Southern's system connects the
cities of Lockhart, Luling, Cuero, Shiner, Yoakum, and Gonzales,
Texas, as well as an industrial customer in Port Arthur, Texas.
Southern also owns a transmission line which supplies gas to the
community of Sabine Pass, Texas and manages and operates 419
miles of transmission lines in the Rio Grande Valley of Texas.
Mercado Gas Services Inc. ("Mercado"), a wholly-owned subsidiary
of Southern Union, markets natural gas to large volume customers.
Mercado's sales and purchasing activities are made through short-
term contracts. These contracts and business activities are not
subject to direct rate regulation.
Southern Union Econofuel Company ("Econofuel"), a wholly-owned
subsidiary of Southern Union, markets and sells natural gas for
natural gas vehicles ("NGVs") as an alternative fuel to gasoline.
Econofuel owns fuel dispensing equipment in Austin, El Paso, Port
Arthur, and Galveston, Texas, located at independent retail fuel
stations for NGVs. These stations primarily serve fleet and
governmental vehicles which have been manufactured or converted
to operate on natural gas. In 1991, Econofuel and Natural Gas
Development Company, Inc. of California formed a joint venture
that, in 1992, opened the Natural Gas Vehicle Technology Centers,
L.L.P. (the "Tech Center") in Austin, Texas. The Tech Center
converts gasoline-driven vehicles to operate using natural gas.
In August 1994, the Tech Center became the first facility in the
United States to receive certification from Ford Motor Company as
a "Qualified Vehicle Modifier."
Southern Union Energy Products and Services Company ("SUEPASCO"),
a wholly-owned subsidiary of Southern Union, markets and sells
commercial gas air conditioning, irrigation pumps and other gas-
fired engine-driven applications and related services.
Southern Union Energy International, Inc. ("International"), a
wholly-owned subsidiary of Southern Union, seeks to participate
in energy related projects internationally.
The Company also holds investments in commercially developed real
estate as well as undeveloped tracts of land through Southern
Union's wholly-owned subsidiary, Lavaca Realty Company ("Lavaca
Realty").
Competition
Southern Union Gas and Missouri Gas Energy are not currently in
significant direct competition with any other distributors of
natural gas to residential and small commercial customers within
their service areas. However, in recent years, certain large
volume customers, primarily industrial and significant commercial
customers, have had opportunities to access alternative natural
gas supplies and, in some instances, delivery service from pipe-
line systems. The Company has offered transportation arrange-
ments to customers who secure their own gas supplies. These
transportation arrangements, coupled with the efforts of Southern
Union's unregulated marketing subsidiary, Mercado, enable the
Company to provide competitively priced gas service to these
large volume customers. In addition, the Company has success-
fully used flexible rate provisions, when needed, to retain cus-
tomers who may have access to alternative energy sources.
As energy providers, Southern Union Gas and Missouri Gas Energy
have historically competed with alternative energy sources, par-
ticularly electricity and also propane, coal, natural gas liquids
and other refined products available in the Company's service
areas. At present rates, the cost of electricity to residential
and commercial customers in the Company's service areas generally
is higher than the effective cost of its natural gas service.
There can be no assurances, however, that future fluctuations in
gas and electric costs will not reduce the cost advantage of
natural gas service. The cost of expansion for peak load
requirements of electricity in some of Southern Union Gas' ser-
vice areas has historically provided opportunities to allow
energy switching to natural gas pursuant to integrated resource
planning techniques. Electric competition has responded by
offering equipment rebates and incentive rates.
Competition between the use of fuel oil and natural gas, particu-
larly by industrial, electric generation and agricultural custo-
mers, has increased as oil prices have decreased. While
competition between such fuels is generally more intense outside
the Company's service areas, this competition affects the nation-
wide market for natural gas. Additionally, the general economic
conditions in its service areas continue to affect certain custo-
mers and market areas, thus impacting the results of the Com-
pany's operations.
Gas Supply
The low cost of natural gas service is dependent upon the Com-
pany's ability to contract for natural gas using favorable mixes
of long-term and short-term supply arrangements and favorable
transportation contracts. The Company has been directly
acquiring its gas supplies since the mid-1980s when interstate
pipeline systems opened their systems for transportation service.
The Company has the organization, personnel and equipment neces-
sary to dispatch and monitor gas volumes on a daily and even
hourly basis to ensure reliable service to customers.
The Company's experience has been of major benefit in the post-
FERC Order No. 636 procurement environment. FERC Order No. 636
required the "unbundling" of services offered by interstate pipe-
line companies. As a result, gas purchasing and transportation
decisions and associated risks have been shifted from the pipe-
line companies to the gas distributors. The increased demands on
distributors to effectively manage their gas supply in an
environment of volatile gas prices provides an advantage to dis-
tribution companies such as the Company that have demonstrated a
history of contracting favorable and efficient gas supply
arrangements in an open market system.
The majority of Southern Union Gas' 1995 gas requirements for
utility operations were delivered under long-term transportation
contracts through five major pipeline companies. All of Missouri
Gas Energy's 1995 gas requirements were delivered under short-
and long-term transportation contracts through three pipeline
companies. These contracts have various expiration dates ranging
from 1996 through 2013. Southern Union Gas also purchases sig-
nificant volumes of gas under long-term and short-term arrange-
ments with suppliers. The amounts of such short-term purchases
are contingent upon price. Southern Union Gas and Missouri Gas
Energy both have firm supply commitments for all areas that are
supplied with gas purchased under short-term arrangements.
Missouri Gas Energy also holds contract rights to over 16 billion
cubic feet ("Bcf") of storage capacity to assist in meeting peak
demands.
Gas sales and/or transportation contracts with interruption pro-
visions, whereby large volume users purchase gas with the under-
standing that they may be forced to shut down or switch to
alternate sources of energy at times when the gas is needed for
higher priority customers, have been utilized for load management
by Southern Union and the gas industry as a whole for many years.
In addition, during times of special supply problems, curtail-
ments of deliveries to customers with firm contracts may be made
in accordance with guidelines established by appropriate federal
and state regulatory agencies. There have been no supply-related
curtailments of deliveries to Southern Union Gas or Missouri Gas
Energy utility sales customers during the last ten years.
The following table shows, for each of the Company's principal
utility service areas, the percentage of gas utility revenues and
sales volume for the year ended June 30, 1995 and the average
cost per Mcf of gas in 1995.
Percent
Percent of Gas
of Gas Utility Average
Utility Sales Cost
Service Area Revenues Volume Per Mcf
------------ -------- ------- -------
Southern Union Gas
Austin and South Texas............ 13 11 $2.21
El Paso and West Texas............ 13 17 1.81
Rio Grande Valley................. 6 3 4.17
Other............................. 8 7 2.43
--- ---
40 38
Missouri Gas Energy................. 60 62 2.95
--- ---
100 100
=== ===
The Company is committed under various agreements to purchase
certain quantities of gas in the future. At June 30, 1995, the
Company has purchase commitments for nominal quantities of gas at
fixed prices. These fixed price commitments have an annual value
of approximately $2,500,000 for Southern Union Gas. Missouri Gas
Energy currently does not have any fixed price commitment con-
tracts for the 1995/1996 winter heating season. At June 30,
1995, the Company also had purchase commitments for certain quan-
tities of gas at variable, market-based prices. These market-
based price commitments have an annual value of approximately
$37,000,000 for Southern Union Gas and $66,000,000 for Missouri
Gas Energy. The Company's purchase commitments may extend over a
period of several years depending upon when the required quantity
is purchased. The Company has purchase gas tariffs in effect for
all its utility service areas that provide for recovery of its
purchase gas costs.
Utility Regulation and Rates
The Company's rates and operations are subject to regulation by
federal, state and local authorities. In Texas, municipalities
have primary jurisdiction over rates within their respective
incorporated areas. Rates in adjacent environs and appellate
matters are the responsibility of the Railroad Commission of
Texas. Rates in Oklahoma are regulated by the Oklahoma Corpora-
tion Commission. In Missouri, rates are established by the MPSC
on a system-wide basis. The FERC and the Railroad Commission of
Texas have jurisdiction over rates, facilities and services of
WGI and Southern, respectively.
The Company holds non-exclusive franchises with varying expira-
tion dates in all incorporated communities where it is necessary
to carry on its business as it is now being conducted. In the
five largest cities in which the Company's utility customers are
located, such franchises expire as follows: Kansas City,
Missouri in 1997; El Paso, Texas in 2000; Austin, Texas in 2006;
and Port Arthur, Texas in 2013. The franchise in St. Joseph,
Missouri is perpetual. The Company fully expects these fran-
chises to be renewed upon their expiration.
Gas service rates are established by regulatory authorities to
permit utilities to recover operating, administrative and finance
costs, and the opportunity to earn a return on equity. Gas costs
are billed to customers through purchase gas adjustment clauses
which permit the Company to adjust its sales price as the cost of
purchased gas changes. This is important because the cost of
natural gas accounts for a significant portion of the Company's
total expenses. The appropriate regulatory authority must
receive notice of such adjustments prior to billing implementa-
tion.
The Company must support any service rate changes to its regula-
tors using a historic test year of operating results adjusted to
normal conditions and for any known and measurable revenue or
expense changes. Because the rate regulatory process has certain
inherent time delays, rate orders may not reflect the operating
costs at the time new rates are put into effect.
The monthly customer bill contains a fixed service charge, a
usage charge for service to deliver gas, and a charge for the
amount of natural gas used. While the monthly fixed charge pro-
vides an even revenue stream, the usage charge increases the Com-
pany's annual revenue and earnings in the traditional heating
load months when usage of natural gas increases. The majority of
the Company's rate increases in Texas and Oklahoma in recent
years have resulted in increased monthly fixed charges which help
stabilize earnings. Weather normalization clauses, now in place
in Austin and Galveston and two other service areas in Texas,
also help stabilize earnings.
On February 10, 1993, the Company's South Texas service area
received an annualized rate increase of $777,000. On July 1,
1993, rates for Austin were changed to provide: (i) an approxi-
mate $1,700,000 annual base revenue increase; (ii) new and
increased fees that add approximately $250,000 annually; and
(iii) weather normalization clause revisions. On October 15,
1993, Missouri Gas Energy's rates increased by $9,750,000
annually. On November 1, 1993, El Paso rates changed to provide
an approximate annual revenue increase of $463,000. Other rate
increases in 1993 throughout Southern Union Gas service terri-
tories aggregated $204,000 annually.
During the year ended June 30, 1995 and the six-month period
ended June 30, 1994, the Company did not file for any rate
increases in any of its service areas other than several annual
cost of service adjustments. In addition to the regulation of
its utility and pipeline businesses, the Company is affected by
numerous other regulatory controls, including, among others,
pipeline safety requirements of the U. S. Department of Trans-
portation, safety regulations under the Occupational Safety and
Health Act, and various state and federal environmental statutes
and regulations. The Company believes that its operations are in
compliance with applicable safety and environmental statutes and
regulations.
Statistics of Gas Utility and Related Operations
The following table provides the number of gas utility customers
served as of:
June 30, December 31,
1995 1994 1993
------- ------- ------------
Southern Union Gas:
Austin and South Texas....... 156,043 153,757 153,096
El Paso and West Texas....... 171,691 168,350 168,361
Galveston and Port Arthur.... 51,943 52,329 52,953
Panhandle and North Texas.... 32,111 31,652 32,821
Rio Grande Valley............ 78,501 77,832 79,616
------- ------- -------
490,289 483,920 486,847
------- ------- -------
Missouri Gas Energy:
Kansas City, Missouri
Metropolitan Area.......... 368,440 362,147 --
St. Joseph, Joplin, Monett
and others................. 102,714 100,732 --
------- ------- -------
471,154 462,879 --
------- ------- -------
Total........................ 961,443 946,799 486,847
======= ======= =======
Southern Union Gas, Mercado, WGI and Southern. The following
- ---------------------------------------------
table shows certain operating statistics of the Company's gas
distribution, transportation, marketing and transmission opera-
tions in Texas and Oklahoma:
Year Ended
-------------------------------
June 30, December 31,
-----------------
1995 1994 1993
-------- -------- ------------
Average number of gas sales
customers served (a):
Residential................... 457,821 432,474 391,154
Commercial.................... 29,584 28,593 26,814
Industrial and irrigation..... 383 722 774
Public authorities and other.. 2,798 2,522 2,309
Pipeline and marketing........ 450 273 182
-------- -------- --------
Total average customers
served...................... 491,036 464,584 421,233
======== ======== ========
Gas sales in millions of
cubic feet (Mmcf):
Residential................... 21,567 23,852 22,171
Commercial.................... 9,925 10,173 9,545
Industrial and irrigation..... 2,113 2,216 2,615
Public authorities and other.. 3,209 2,959 2,938
Pipeline and marketing........ 7,596 7,482 6,934
-------- -------- --------
Gas sales billed............ 44,410 46,682 44,203
Net change in unbilled
gas sales..................... (10) (18) 656
-------- -------- --------
Total gas sales............. 44,400 46,664 44,859
======== ======== ========
Gas sales revenues (thousands
of dollars):
Residential................... $117,843 $137,135 $117,954
Commercial.................... 41,626 47,020 41,219
Industrial and irrigation..... 6,641 8,848 9,206
Public authorities and other.. 7,877 10,943 10,592
Pipeline and marketing........ 16,409 17,759 16,247
-------- -------- --------
Gas revenues billed......... 190,396 221,705 195,218
Net change in unbilled gas
sales revenues................ (204) (2,018) 4,141
-------- -------- --------
Total gas sales revenues.... $190,192 $219,687 $199,359
======== ======== ========
Gas sales margin (thousands
of dollars) (b):................ $ 96,808 $ 95,136 $ 88,975
======== ======== ========
Gas sales revenue per thousand
cubic feet (Mcf) billed (c):
Residential................... $ 5.464 $ 5.750 $ 5.320
Commercial.................... 4.194 4.622 4.318
Industrial and irrigation..... 3.143 3.992 3.520
Public authorities and other.. 2.455 3.698 3.605
Pipeline and marketing........ 2.160 2.374 2.343
Weather effect:
Degree days (d)............... 1,669 1,950 2,025
Percent of normal, based on
30 year average (e)........... 78% 90% 90%
Gas transported in millions
of cubic feet (Mmcf).......... 38,128 24,461 22,750
Gas transportation revenues
(thousands of dollars)........ $ 10,881 $ 7,393 $ 6,485
- ---------------------------
(a) Increase in the average customers served in 1995 and 1994 is
due to the Rio Grande and Eagle Pass Acquisitions in Septem-
ber 1993 and July 1993, respectively, involving a total of
approximately 78,000 customers.
(b) Gas sales margin is equal to gas sales revenues less pur-
chased gas costs.
(c) Fluctuations in gas price billed between each period reflect
changes in the average cost of purchased gas and the effect
of rate adjustments.
(d) "Degree days" are a measure of the coldness of the weather
experienced. A Degree day is equivalent to each degree that
the daily mean temperature for a day falls below 65 degrees
Fahrenheit. The decrease in 1995 and 1994 actual Degree
days was impacted by warmer than normal weather and the tem-
perate climate of Rio Grande acquired in September 1993.
(e) Information with respect to weather conditions is provided
by the National Oceanic and Atmospheric Administration.
Percentages of normal are computed based on the weighted
average volumes of gas sales billed.
Missouri Gas Energy. The following table shows certain operating
- -------------------
statistics of the gas distribution and transportation operations
in Missouri:
Five
Year Months
Ended Ended Year Ended
-----------------------
June 30, June 30, June 30, December 31,
1995(a) 1994(a) 1994(a) 1993
-------- -------- --------- ------------
Average number of
gas sales customers
served:
Residential....... 410,291 410,934 400,222 396,755
Commercial........ 59,087 58,830 57,300 57,330
Industrial........ 296 254 257 260
-------- -------- -------- --------
Total average
customers
served.......... 469,674 470,018 457,779 454,345
======== ======== ======== ========
Gas sales in
millions of cubic
feet (Mmcf):
Residential....... 41,354 21,569 45,407 47,244
Commercial........ 18,863 10,023 21,363 22,669
Industrial........ 241 26 143 309
-------- -------- -------- --------
Gas sales
billed.......... 60,458 31,618 66,913 70,222
Net change in
unbilled gas
sales............. (19) (6,059) (104) (58)
-------- -------- -------- --------
Total gas sales. 60,439 25,559 66,809 70,164
======== ======== ======== ========
Gas sales revenues
thousands of
dollars):
Residential....... $186,716 $108,871 $234,360 $215,806
Commercial........ 77,101 47,257 102,036 95,520
Industrial........ 1,731 458 1,480 2,015
-------- -------- -------- --------
Gas sales
revenues billed. 265,548 156,586 337,876 313,341
Net change in
unbilled gas
sales revenues.... (740) (28,564) (1,210) 3,818
-------- -------- -------- --------
Total gas
sales revenues.. $264,808 $128,022 $336,666 $317,159
======== ======== ======== ========
Gas sales margin
(thousands of
dollars) (b)........ $116,353 $ 41,445 $103,191 $106,687
======== ======== ======== ========
Gas sales revenue
per thousand cubic
feet (Mcf)
billed:(c)
Residential....... $ 4.515 $ 5.048 $ 5.161 $ 4.568
Commercial........ 4.087 4.715 4.776 4.214
Industrial........ 7.183 17.615 10.350 6.521
Weather effect:
Degree days (d)... 4,779 1,916 5,277 5,608
Percent of
normal, based
on 30-year
average: (e).... 90% 93% 100% 106%
Gas transported in
millions of cubic
feet (Mmcf)....... 30,464 11,673 29,498 28,064
Gas transportation
revenues
(thousands of
dollars).......... $ 8,336 $ 2,568 $ 6,614 $ 6,676
- --------------------------
(a) Missouri Gas Energy was acquired by the Company on
January 31, 1994 and, therefore, is consolidated with the
Company as of that date. The Company included Missouri Gas
Energy in its results of operations beginning February 1,
1994. The increase in the average number of customers
served in 1994 is due to the seasonality of the Company's
business in which a greater number of customers are served
during the winter-heating season.
(b) Gas sales margin is equal to gas sales revenues less pur-
chased gas.
(c) Fluctuations in gas price billed between each period reflect
changes in the average cost of purchased gas and the effect
of rate adjustments.
(d) "Degree days" are a measure of the coldness of the weather
experienced. A Degree day is equivalent to each degree that
the daily mean temperature for a day falls below 65 degrees
Fahrenheit.
(e) Information with respect to weather conditions is provided
by the National Oceanic and Atmospheric Administration.
Percentages of normal are computed based on the weighted
average volumes of gas sales billed.
Investments in Real Estate
Lavaca Realty owns a commercially developed tract of land in the
central business district of Austin, Texas, containing a combined
11-story office building, parking garage, drive-through bank and
mini-bank facility ("Lavaca Plaza"). Approximately 49% of the
office space at Lavaca Plaza is used in the Company's business
while 51% is leased to non-affiliated entities. Lavaca Realty
also owns a commercially developed tract of land in Austin, Texas
that is used exclusively in the Company's business. Other real
estate investments held at June 30, 1995 include two small com-
mercial tracts in downtown Austin, 11 acres of undeveloped land
in Dallas, Texas, 42 acres of undeveloped land in Denton, Texas
and eight acres of undeveloped land in San Antonio, Texas. The
real estate located in Denton and San Antonio was sold subsequent
to June 30, 1995. The Company is attempting to sell all
remaining undeveloped real estate. Lavaca Realty also owns
approximately 36,000 square feet of improved property in Kansas
City, Missouri, which is leased to a non-affiliated entity.
Employees
As of August 11, 1995, the Company has 1,743 employees, of whom
1,443 are paid on an hourly basis, 278 are paid on a salary basis
and 22 are paid on a commission basis. Of the 1,443 hourly paid
employees, approximately 57% are represented by unions. Of those
employees represented by unions, 82% are employed by Missouri Gas
Energy.
In May 1994, the Company announced an early retirement program
for certain employees of Missouri Gas Energy with an election
period from May 20 to June 23, 1994. Of an eligible 133
employees, 81 accepted the 1994 early retirement program. In
January 1993, the Company provided an early retirement program to
certain of the Company's employees with an election period from
January to March 1993. Of an eligible 109 employees, 75 accepted
the 1993 early retirement program.
From time to time the Company may be subject to labor disputes;
however, such disputes have not previously disrupted its busi-
ness. The Company believes that its relations with its employees
are good.
ITEM 2. Properties.
See Item 1, "Business," for information concerning the general
location and characteristics of the important physical properties
and assets of the Company.
Southern Union Gas has 8,584 miles of mains, 3,694 miles of ser-
vice lines and 307 miles of transmission lines. Missouri Gas
Energy has 7,093 miles of mains, 3,720 miles of service lines and
71 miles of transmission lines. WGI has 217 miles of transmis-
sion lines and 48 miles of gathering lines. Southern has 137
miles of transmission lines. The Company considers its systems
to be in good condition and to be well-maintained, and it has
continuing replacement programs based on historical performance
and system surveillance.
Pursuant to a 1989 MPSC order, Missouri Gas Energy is engaged in
a major gas safety program in its service territories. This pro-
gram includes replacement of company- and customer-owned gas
service and yard lines, the movement and resetting of meters, the
replacement of cast iron mains and the replacement and cathodic
protection of bare steel mains (the "Missouri Safety Program").
In recognition of the significant capital expenditures associated
with this safety program, the MPSC permits the deferral, and sub-
sequent recovery through rates, of depreciation expense, property
taxes and associated carrying costs, related to the Missouri
Safety Program. Missouri Gas Energy was required to continue the
Missouri Safety Program and has deferred depreciation expense,
property taxes and carrying costs of approximately $4,154,000 and
$600,000 for 1995 and 1994, respectively.
ITEM 3. Legal Proceedings.
See "Commitments and Contingencies" and "Acquisitions and
Divestiture -- Missouri Gas Energy" in the Notes to Consolidated
Financial Statements for discussions of the Company's legal pro-
ceedings.
ITEM 4. Submission of Matters to a Vote of Security Holders.
There were no matters submitted to a vote of security holders of
Southern Union during the quarter ended June 30, 1995.
<PAGE>
PART II
ITEM 5. Market for the Registrant's Common Stock and Related
Stockholder Matters.
Market Information
On March 6, 1995, Southern Union's common stock began trading on
the New York Stock Exchange under the symbol "SUG." Prior to
March 6, 1995, Southern Union's common stock was traded on the
American Stock Exchange under the same symbol. On May 25, 1994
the Company's Board of Directors declared a 5% stock dividend,
paid on June 30, 1994 to stockholders of record on June 14, 1994.
On February 11, 1994 the Company's Board of Directors declared a
three-for-two stock split distributed in the form of a 50% stock
dividend on March 9, 1994 to stockholders of record on
February 23, 1994.
The high and low sales prices (adjusted for the June 30 and
March 9, 1994 distributions) for shares of Southern Union common
stock since July 1, 1993 are set forth below:
$/Share
---------------
High Low
------ ------
July 1 to September 22, 1995.................. 19 1/2 17 1/4
(Quarter Ended)
June 30, 1995................................. 19 1/4 16 3/8
March 31, 1995................................ 17 7/8 15 1/2
December 31, 1994............................. 18 1/4 16 3/8
September 30, 1994............................ 18 3/8 16 5/8
(Quarter Ended)
June 30, 1994................................. 19 16 1/4
March 31, 1994................................ 23 3/8 16 1/2
December 31, 1993............................. 20 1/8 12 5/8
September 30, 1993............................ 14 1/8 11 7/8
Holders
As of September 22, 1995, there were 278 holders of record of
Southern Union's common stock. This number does not include per-
sons whose shares are held of record by a bank, brokerage house
or clearing agency, but does include any such bank, brokerage
house or clearing agency.
There were 11,518,622 shares of Southern Union's common stock
outstanding on September 22, 1995 of which 6,532,345 shares were
held by non-affiliates.
Dividends
Southern Union paid no cash dividends on its common stock in fis-
cal 1995, 1994 or 1993. Provisions in certain of Southern
Union's long-term notes and its bank revolving credit facility
limit the payment of cash or asset dividends on capital stock.
Under the most restrictive provisions in effect, Southern Union
may not declare or pay any cash or asset dividends on its common
stock or acquire or retire any of Southern Union's common stock,
unless no event of default exists and the Company meets certain
financial ratio requirements. See "Business -- Changes in
Capital Structure."
On March 9, 1994 Southern Union distributed a 50% stock dividend.
On June 30, 1994 Southern Union paid a 5% stock dividend. The
June 30, 1994 stock dividend was consistent with the decision of
Southern Union's Board of Directors, as announced in February
1994, to commence regular stock dividends of approximately 5%
each year in conjunction with annual meetings of stockholders.
The specific amount and declaration, record and distribution
dates for an annual stock dividend will be determined by the
Board and announced at a date that is not expected to be later
than the annual stockholders meeting each year. The next stock
dividend is expected to be a 5% stock dividend declared in con-
nection with the Company's annual meeting of stockholders to be
held on November 7, 1995. A portion of the June 14, 1994 distri-
bution was characterized as a distribution of capital due to the
level of the Company's retained earnings available for distribu-
tion as of the date of declaration.
ITEM 6. Selected Financial Data.
Years Ended June 30, Years Ended December 31,
-------------------- ------------------------------
1995(a) 1994(a)(b) 1993(b)(c) 1992(c) 1991(c)
---------- ---------- ---------- --------- ---------
(thousands of dollars, except per share amounts)
Total
operating
revenues.. $ 480,046 $374,516 $209,005 $192,445 $200,261
Earnings
from con-
tinuing
opera-
tions..... 16,069 8,378 7,733 6,391 4,673
Earnings
from con-
tinuing
opera-
tions per
share of
common
stock (d). 1.40 .85 .83 .47 .26
Total
assets.... 1,002,502 897,712 416,207 377,167 369,783
Common
stock-
holders'
equity.... 225,664 208,975 201,938 148,003 147,356
Short-term
debt...... 770 889 40,655 14,360 2,385
Long-term
debt, ex-
cluding
current
maturi-
ties...... 462,503 479,048 89,019 109,464 110,482
Redeemable
preferred
stock..... -- -- -- 24,900 25,000
Company-
obligated
manda-
torily
redeem-
able pre-
ferred
securi-
ties of
subsidi-
ary
trust..... 100,000 -- -- -- --
Average
customers
served..... 960,710 660,425 421,233 394,199 428,077
- ------------------
(a) Missouri Gas Energy, a division of Southern Union head-
quartered in Kansas City, Missouri, was acquired on
January 31, 1994 and was accounted for as a purchase.
Missouri Gas Energy assets were included in the Company's
consolidated balance sheet at January 31, 1994 and its
results of operations were included in the Company's con-
solidated results of operations beginning February 1, 1994.
For these reasons, the consolidated results of operations of
the Company for the period subsequent to the acquisition are
not comparable to prior periods. See "Business -- Missouri
Acquisition."
(b) During 1994, the Company changed its fiscal year-end from
December 31 to June 30. The Company believes the new fiscal
year more closely conforms its financial condition and
results of operations to its natural business cycle. The
consolidated results of operations for the year ended
June 30, 1994 and the year ended December 31, 1993 include
the effects of the following which occurred in the two quar-
ters in common during the six-month period ended
December 31, 1993: (i) a non-recurring adjustment of
approximately $2,489,000 to reverse a tax reserve upon the
final settlement of prior period federal income tax audits;
(ii) a pre-tax gain of approximately $494,000 on the sale of
undeveloped real estate; and (iii) the write-off of approxi-
mately $357,000 of acquisition-related costs as a result of
the termination of negotiations for various acquisitions.
(c) The Company completed the Berry Gas, Eagle Pass and Rio
Grande acquisitions during 1993 and the Nixon acquisition in
1992. In addition, during 1991 the Company completed the
South Texas, Brazos River and Andrews acquisitions and the
sale of its Arizona gas utility operations. For these rea-
sons, 1993, 1992 and 1991 results of operations are not com-
parable between periods.
(d) Earnings per share in 1994, 1993, 1992 and 1991 were com-
puted based on the weighted average number of shares of com-
mon stock outstanding during the year adjusted for the 5%
stock dividend distributed on June 30, 1994 and the 50%
stock dividend distributed on March 9, 1994.
ITEM 7. Management's Discussion and Analysis of Financial
Condition and Results of Operations.
Introduction
The Company's principal line of business is the distribution of
natural gas as a public utility through Southern Union Gas and,
subsequent to January 31, 1994, Missouri Gas Energy, each of
which is a division of the Company. Missouri Gas Energy was
acquired on January 31, 1994 and was accounted for as a purchase.
Accordingly, the operating results of Missouri Gas Energy have
been included in the consolidated results of operations subse-
quent to the date of acquisition. In addition, during 1993 the
Company completed the Rio Grande, Berry Gas and Eagle Pass
Acquisitions, which were also accounted for as purchases. See
"Acquisitions and Divestitures" in the Notes to Consolidated
Financial Statements. For these reasons, the results of opera-
tions of the Company for the periods subsequent to those acquisi-
tions are not comparable to those periods prior to the
acquisitions nor are the 1995 results of operations comparable
with prior periods.
Southern Union Gas, which accounted for approximately 39% of the
Company's total revenues for the year ended June 30, 1995, serves
approximately 498,000 residential, commercial, industrial, agri-
cultural and other customers in the States of Texas (including
the cities of Austin, Brownsville, El Paso, Galveston and Port
Arthur) and Oklahoma. Missouri Gas Energy, which accounted for
approximately 57% of the Company's total revenues for the year
ended June 30, 1995, serves approximately 478,000 customers in
central and western Missouri, including Kansas City, St. Joseph,
Joplin and Monett. In addition, the Company operates interstate
and intrastate natural gas pipeline systems, markets natural gas
to end users and markets and sells natural gas for natural gas
vehicles. The Company also holds investments in real estate and
other assets.
On May 25, 1994, Southern Union's Board of Directors declared a
5% stock dividend distributed on June 30, 1994 to stockholders of
record on June 14, 1994. A portion of the 5% stock dividend was
characterized as a distribution of capital due to the level of
the Company's retained earnings available for distribution as of
the date of declaration. The 5% stock dividend was consistent
with the Board of Directors decision announced in February 1994
to commence regular stock dividends of approximately 5% annually.
Also in February 1994, Southern Union's Board of Directors
declared a three-for-two stock split distributed in the form of a
50% stock dividend on March 9, 1994 to stockholders of record on
February 23, 1994. Unless otherwise stated, all per share data
included in this Management's Discussion and Analysis of Finan-
cial Condition and Results of Operations ("MD&A") and in the
accompanying consolidated financial statements and notes to the
consolidated financial statements have been restated to give
effect to the stock split and stock dividend.
In May 1994, the Board of Directors changed the Company's fiscal
year-end from December 31 to June 30. The new fiscal year more
closely conforms the reporting of the Company's financial condi-
tion and results of operations to its seasonal business cycle.
The comparison of consolidated results or operations for the year
ended June 30, 1994 and the year ended December 31, 1993 include
the effects of the following items that occurred in the two quar-
ters in common during the six-month period ended December 31,
1993: (i) a non-recurring adjustment of approximately $2,489,000
to reverse a tax reserve upon the final settlement of prior
period federal income tax audits; (ii) a pre-tax gain of approxi-
mately $494,000 on the sale of undeveloped real estate; and (iii)
the write-off of approximately $357,000 of acquisition-related
costs as a result of the termination of negotiations for various
acquisitions. All references in this MD&A to years 1995, 1994
and 1993 reflect the twelve months ended June 30, 1995, June 30,
1994 and December 31, 1993, respectively.
Several of the Company's business activities are subject to regu-
lation by federal, state or local authorities. Thus, the Com-
pany's financial condition and results of operations have been
dependent upon the receipt of adequate and timely adjustments in
rates. Gas service rates, which consist of a monthly fixed
charge and a gas usage charge, are established by regulatory
authorities and are intended to permit utilities to recover
operating, administrative and financing costs and to have the
opportunity to earn a return on equity. The monthly fixed charge
provides a base revenue stream while the usage charge increases
the Company's revenues and earnings in colder weather when
natural gas usage increases.
The Company's revenues and earnings are primarily dependent upon
gas sales volumes and gas service rates. Gas purchase costs
generally do not directly affect the Company's earnings as such
costs are usually passed through to customers pursuant to pur-
chase gas adjustment clauses. Accordingly, while changes in the
cost of gas may cause the Company's operating revenues to fluc-
tuate, operating margin (defined as operating revenues less gas
purchase costs) is generally not affected by increases or
decreases in the cost of gas.
Gas sales volumes fluctuate as a function of seasonal weather
impact and the size of the Company's customer base, which is
affected by competitive factors in the industry as well as econo-
mic development and residential growth in its service areas. The
primary factors that affect the distribution and sale of natural
gas are the seasonal nature of gas use, adequate and timely rate
relief from regulatory authorities, competition from alternative
fuels, competition within the gas business for industrial custo-
mers and volatility in the supply and price of natural gas.
In recent years weather variances experienced during the tradi-
tional heating load months have significantly impacted the Com-
pany's results of operations. The average temperatures in
Southern Union Gas' service areas during the past several winter
seasons have been much warmer than normal. To mitigate the
impact of these seasonal variances, Southern Union Gas has
requested and received approval for weather normalization clauses
in Austin, Galveston and in two other service areas in Texas.
These clauses allow for rate adjustments that help stabilize cus-
tomers' monthly bills and the Company's earnings from the varying
effects of weather.
Results of Operations
Net Earnings Available for Common Stock
The Company recorded net earnings available for common stock of
$16,069,000 for the year ended June 30, 1995 compared to
$8,378,000 in 1994, an increase of 92%. Net earnings per common
share, based on weighted average shares outstanding were $1.40 in
1995 compared to $.85 in 1994. Net earnings available for common
stock in 1993 were $6,890,000 or $.83 per share based on
weighted average shares outstanding.
Net earnings between reporting periods were primarily affected by
the January 31, 1994 acquisition of Missouri Gas Energy and the
September 30, 1993 acquisition of Rio Grande. These acquisitions
collectively contributed approximately $8,887,000 or 55% in 1995
and $880,000 or 11% in 1994 to net earnings after deductions for
allocated corporate expenses, interest and income taxes. Rate
increases also affect comparability between periods. Rate
increases included: a $777,000 annualized increase in the Com-
pany's South Texas service area effective February 10, 1993; a
$1,950,000 annualized increase in Austin effective July 1, 1993;
and a $463,000 annualized increase in El Paso effective
November 1, 1993.
The Company's net earnings in 1995 and 1994 were positively
impacted by the elimination of preferred stock dividends due to
the retirement of Southern Union's Series A 10% Cumulative Pre-
ferred Stock begun in March and completed in June 1993. This was
partially offset in 1995 by the issuance of $100,000,000 of 9.48%
Trust Originated Preferred Securities which impacted net earnings
by $753,000 in 1995.
As previously noted, Missouri Gas Energy's results of operations
were included in the consolidated operating results of the Com-
pany subsequent to January 31, 1994. Accordingly, the Company's
1994 results of operations do not include Missouri Gas Energy's
operations for December 1993 or January 1994, two of the coldest
months of Missouri's winter-heating season. In addition,
Missouri Gas Energy's rate structure collects a greater per-
centage of its margin during the winter-heating season months
than does Southern Union Gas. This results in a significant
timing difference occurring between the collection of revenues in
the winter months to recover annual costs and the actual incur-
rence of these costs throughout the year. Thus, Missouri Gas
Energy's contribution to the Company's results of operations in
1994 were not significant.
Operating Revenues
Total operating revenues in 1995, 1994 and 1993 were
$480,046,000, $374,516,000 and $209,005,000, respectively. Reve-
nues are affected by the level of sales volumes, customer base
and the pass-through of increases or decreases in the Company's
gas purchase costs through its purchase gas adjustment clauses.
Operating revenues increased $105,530,000, or approximately 28%,
in 1995, primarily due to the acquisition of Missouri Gas Energy,
which contributed operating revenues of $274,862,000 or 57% of
total operating revenues in 1995 and $143,502,000 or 38% of total
operating revenues in 1994. The Company's average customer base
served in 1995 and 1994 was approximately 961,000 and 660,000,
respectively. The increase in the average customer base from
1994 to 1995 primarily is the result of consolidating Missouri
Gas Energy's operations with the Company for the full twelve
months of 1995 as compared with only five months in 1994. Gas
sales volume increased to 104,839 MMcf in 1995 from 72,223 MMcf
in 1994, while the average cost of gas decreased to $2.31 per Mcf
in 1995 from $2.92 per Mcf in 1994. The increase in volume is
attributable to growth in the average customer base as a result
of the acquisition of Missouri Gas Energy. The decrease in the
average cost of gas primarily is the result of decreases in
average spot market gas prices throughout the Company's distribu-
tion system as a result of competitive pricing within the indus-
try which was impacted by warmer than normal weather throughout
the Company's service territories. The Texas and Oklahoma ser-
vice areas experienced 78% of normal weather in 1995 compared to
90% of normal in 1994. Weather in the Missouri service area
decreased from 93% of normal in 1994 to 90% of normal in 1995.
Operating revenues increased $165,511,000, or approximately 79%,
in 1994, primarily due to an increase in over a half a million
customers resulting from the Missouri, Rio Grande, Berry Gas and
Eagle Pass Acquisitions. Revenues from these acquisitions were
approximately $167,692,000 in 1994. The average customer base
served in 1994 and 1993 was approximately 660,000 and 421,000,
respectively. The increase in the average customer base was pri-
marily the result of the Missouri Gas Energy acquisition.
Operating revenues also increased due to receipt of rate
increases in 1993, described above, and by a 19% increase in the
average cost of gas from $2.46 per Mcf in 1993 to $2.92 per Mcf
in 1994.
Gas Sales and Transportation Volumes
Gas sales volumes billed in 1995, 1994 and 1993 totaled 104,868
MMcf, 78,300 MMcf and 44,203 MMcf, respectively, at an average
Mcf sales price of $4.35, $4.83 and $4.42, respectively. Gas
sales volumes fluctuate as a function of weather and customer
base. The increase in gas sales volumes is due principally to
the increase in gas sales subsequent to the Missouri Acquisition
and the Rio Grande Acquisition. Gas sales volumes billed by
these acquired operations were 63,861 MMcf in 1995 and 34,512
MMcf in 1994. Gas sales volumes are also directly impacted by
the weather patterns in the Company's service areas. The Texas
and Oklahoma service areas averaged 28% warmer than normal in
1995 and 11% warmer than normal in both 1994 and 1993, while the
Missouri service area was 11% warmer than normal in 1995 and 8%
warmer than normal in the five months ended June 30, 1994. The
average sales price per Mcf varied between periods as a result of
variations in contracted and spot market gas prices, which are
effected by competitive factors in the industry.
Gas transportation volumes in 1995, 1994 and 1993 totaled 68,592
MMcf, 36,134 MMcf and 22,750 MMcf, respectively, at an average
transportation rate per Mcf of $.28, $.28 and $.29 respectively.
Transportation volumes increased in 1995 as compared to 1994 as a
result of the Missouri Acquisition, which contributed 30,464 MMcf
in 1995, and by an increase in WGI's transported volumes into
Mexico from 8,500 MMcf in 1994 to 16,400 MMcf in 1995. Transpor-
tation volumes increased in 1994 as compared to 1993 as a result
of 11,673 MMcf transported by Missouri Gas Energy in 1994.
Gas Purchase Costs
Gas purchase costs in 1995, 1994 and 1993 were $241,839,000,
$211,127,000 and $110,384,000, respectively. The increase in gas
purchase costs in 1995 and 1994 was due to the Missouri Acquisi-
tion contributing $147,799,000 or 61% of gas purchase costs in
1995 and $86,577,000 or 41% in 1994. These increases were
partially offset by a decrease in both the average spot market
price of natural gas as well as a decrease in gas sales volumes
in the Company's Texas and Oklahoma service territories,
previously discussed. The average spot market price of natural
gas per million British thermal units ("MMBtu") in 1995, 1994 and
1993 was $1.43, $1,90 and $1.96, respectively. The average gas
purchase cost, including both spot purchases and contract pur-
chases, was $2.31 per Mcf in 1995, $2.92 per Mcf in 1994 and
$2.46 per Mcf in 1993. The decrease in average gas purchase cost
in 1995 as compared to 1994 was due to a 25% decrease in the
average spot market price of natural gas due to competitive
pricing during the unusually warm 1994/1995 winter season as dis-
cussed above. The increase in average gas purchase cost in 1994
as compared to 1993 was due to certain previously negotiated
fixed price gas supply contracts with certain suppliers to the
Missouri operations assigned to the Company in the Missouri
Acquisition.
Operating, Maintenance and General Expenses
Operating, maintenance and general expenses were $104,072,000,
$79,667,000 and $50,076,000 in 1995, 1994, and 1993, respec-
tively. The Missouri and Rio Grande Acquisitions contributed
combined operating, maintenance and general expenses of
$60,546,000, $32,814,000 and $1,779,000 for 1995, 1994 and 1993,
respectively. The operating, maintenance and general expenses of
Southern Union Gas, excluding Rio Grande, decreased in both 1995
and 1994 as a result of efforts to reduce costs and improve
operating efficiencies, including approximately $1,444,000 in
savings in 1994 from the reduction in payroll expenses as a
result of the Company's 1993 early retirement program finalized
in April 1993.
Taxes
Federal and state income tax expense in 1995, 1994 and 1993 was
$10,974,000, $5,185,000 and $3,855,000, respectively. The in-
crease in income taxes in 1995 and 1994 primarily is a result of
an increase in pre-tax income attributable to the Company's re-
vent acquisitions. Income taxes in both 1994 and 1993 were im-
pacted by reductions related to amended prior year federal income
tax returns and non-taxable income items included with "other
income" related to the reversal of a tax reserve recorded in
September 1993, discussed below. In July 1993 the Company paid
the Internal Revenue Service ("IRS") approximately $1,266,000 in
settlement for federal income taxes and interest related to the
tax years 1984 through 1989. The Company had previously esti-
mated and accrued an amount for the tax deficiencies and related
interest and, as a result of the settlement with the IRS for a
lesser amount, a non-recurring adjustment was recorded to reverse
the tax reserve in excess of the payment made. The reversal of
the reserve had no impact on liquidity or cash flows due to the
non-cash impact of this adjustment. See "Taxes on Income" in the
Notes to Consolidated Financial Statements.
Taxes other than income taxes reflect various state and local
business and payroll related taxes. The state and local business
taxes are generally based on gross receipts and investments in
property, plant and equipment and fluctuate accordingly.
Depreciation and Amortization Expense
Depreciation and amortization expense in 1995, 1994 and 1993 was
$32,373,000, $21,919,000 and $14,416,000, respectively. The
increase in depreciation expense of $10,454,000 in 1995 and
$7,503,000 in 1994 was primarily attributable to the acquisition
of gas distribution systems, previously discussed.
Effective January 1, 1994, the Company revised its estimate of
the amortization period of additional purchase cost assigned to
utility plant to its standard policy of forty years. As a result
of this change, amortization expense for 1994 was reduced by
approximately $478,000, with a corresponding increase to net
earnings, or $.05 per average common share. See "Change in
Accounting Estimate" in the Notes to Consolidated Financial
Statements.
Other Income and Expenses, Net
Other expenses, net in 1995, 1994 and 1993 were $35,073,000,
$18,470,000 and $8,176,000, respectively. The increase in other
expenses of approximately $16,603,000 in 1995 and $10,294,000 in
1994 is principally due to an increase in interest expense on
long-term debt of approximately $13,880,000 in 1995 and
$12,033,000 in 1994. The increased interest expense on long-term
debt is due to the issuance of the Senior Debt Securities which
were used, in part, to fund the Missouri Acquisition and to repay
and refinance certain outstanding debt of the Company. See
"Long-Term Debt" in the Notes to Consolidated Financial State-
ments.
As a result of the issuance of the Preferred Securities in 1995,
the Company recorded dividends on preferred securities of sub-
sidiary trust of approximately $1,159,000 in 1995. See "Business
- -- Changes in Capital Structure" and "Preferred Securities of
Subsidiary Trust" in the Notes to the Consolidated Financial
Statements.
Other income of $5,970,000 in 1995 included rental income from
Lavaca Realty of approximately $2,647,000; approximately
$2,619,000 related to the deferral of interest expense associated
with the Missouri Gas Energy Safety Program (see "Utility Regula-
tion and Rates" in the Notes to the Consolidated Financial State-
ments); investment interest and interest on notes receivable of
approximately $960,000; and approximately $244,000 from gas
appliance merchandising. This was partially offset by approxi-
mately $750,000 for the write-down to estimated fair market value
of certain real estate held for sale.
Other income increased in 1994 over 1993 by approximately
$1,423,000. Other income increased by approximately $500,000 as
a result of gas appliance merchandising related to the acquisi-
tion of the gas distribution systems, previously discussed.
Rental income earned by Lavaca Realty increased by approximately
$450,000 in 1994 as compared to 1993. In addition, Missouri Gas
Energy recorded other income in 1994 of approximately $276,000
related to the deferral of interest expense associated with the
Missouri Gas Energy Safety Program.
As a result of the change in the Company's year-end to June 30,
both the 1994 and 1993 results of operations were impacted by the
recording of a non-recurring adjustment of approximately
$2,489,000 to reverse a tax reserve upon the final settlement of
prior period federal income tax audits as previously discussed.
The reversal of the reserve had no impact on liquidity or cash
flows due to the non-cash impact of this adjustment. Other
income and expense items recorded during the period in common in
1994 and 1993 included the recognition of a pre-tax gain of
approximately $494,000 on the sale of undeveloped real estate and
the write-off of approximately $357,000 of acquisition-related
costs as a result of the termination of negotiations for various
acquisitions.
Other income items recorded in 1993 also included rental income
from Lavaca Realty of approximately $1,835,000; interest income
on notes receivable of approximately $830,000; and a pre-tax gain
of approximately $494,000 on the sale of undeveloped real estate.
Interest expense on short-term debt was $1,787,000, $1,412,000
and $1,836,000 in 1995, 1994 and 1993, respectively. The average
short-term debt outstanding during 1995, 1994 and 1993 was
$27,159,000, $26,369,000 and $33,021,000, respectively, at an
average interest rate of 6.5%, 5.1% and 5.3%, respectively. The
variance in the average amounts outstanding coupled with a
general fluctuation in interest rates resulted in the change in
other interest expense in each of the years.
Liquidity and Capital Resources
The Company's liquidity is impacted by its ability to generate
funds from operations and to access capital markets. The gas
utility operations are seasonal in nature with a significant per-
centage of the Company's annual revenues and earnings occurring
in the traditional heating-load months. This seasonality results
in a high level of cash flow needs during the peak winter-heating
season months, resulting from the required payments to natural
gas suppliers in advance of the receipt of cash payments from the
Company's customers. The Company has historically used its
revolving credit facility and internally-generated funds to pro-
vide funding for its seasonal working capital, continuing con-
struction and maintenance programs and operational requirements.
Operating Activities
Net cash generated from operating activities in 1995, 1994 and
1993 was $41,642,000, $95,329,000 and $15,017,000 respectively.
The change in net cash generated from operations in each of these
years was primarily impacted by the Missouri Gas Energy Acquisi-
tion and the Rio Grande Acquisition in which net working capital
assets of $50,999,000 were acquired in 1994. Subsequent to these
acquisitions, significant collections on accounts receivable and
payments on accounts payable have occurred. Additionally, these
acquisitions have contributed to increased net earnings of the
Company in 1995 and 1994.
At June 30, 1995 and 1994, the Company's primary sources of
liquidity included cash, cash equivalents and short-term invest-
ments of $58,597,000 and $5,881,000, respectively, and borrowings
available under its $100,000,000 revolving credit facility, as
described below. No amounts under the revolving credit facility
were outstanding at June 30, 1995 or 1994.
Financing Activities
On May 17, 1995, Southern Union Financing I (the "Subsidiary
Trust"), a consolidated wholly-owned subsidiary of Southern
Union, issued $100,000,000 of 9.48% Trust Originated Preferred
Securities (the "Preferred Securities"). In connection with the
Subsidiary Trust's issuance of the Preferred Securities and the
related purchase by Southern Union of all of the Subsidiary
Trust's common securities (the "Common Securities"), Southern
Union issued to the Subsidiary Trust $103,092,800 principal
amount of its 9.48% Subordinated Deferrable Interest Notes,
due 2025 (the "Subordinated Notes"). The sole assets of the
Subsidiary Trust are and will be the Subordinated Notes. The
interest and other payment dates on the Subordinated Notes
correspond to the distribution and other payment dates on the
Preferred Securities and the Common Securities. Under certain
circumstances, the Subordinated Notes may be distributed to
holders of the Preferred Securities and holders of the Common
Securities in liquidation of the Subsidiary Trust. The Sub-
ordinated Notes are redeemable at the option of the Company
on or after May 17, 2000, at a redemption price of $25 per
Subordinated Note plus accrued and unpaid interest. The
Preferred Securities and the Common Securities will be
redeemed on a pro rata basis to the same extent as the Sub-
ordinated Notes are repaid, at $25 per Preferred Security
and Common Security plus accumulated and unpaid distribu-
tions. Southern Union's obligations under the Subordinated
Notes and related agreements, taken together, constitute a
full and unconditional guarantee by Southern Union of pay-
ments due on the Preferred Securities. As of June 30, 1995,
4,000,000 shares of Preferred Securities were outstanding.
Southern Union has the right under the Subordinated Notes to
extend interest payment periods up to 20 consecutive quarters,
and, as a consequence, quarterly distributions on the Preferred
Securities may be deferred (but will continue to accrue with
interest thereon at a rate of 9.48% per annum compounded quar-
terly) by the Subsidiary Trust during any such extended interest
payment period. If interest payments are deferred by Southern
Union, the Company: (i) may not pay cash dividends, or redeem,
purchase or acquire, or make a liquidation payment with respect
to, any of its capital stock or the capital stock of any sub-
sidiary of Southern Union; and (ii) shall not make any payment of
interest, principal or premium, if any, on or repay, repurchase
or redeem any debt securities issued by Southern Union that rank
pari passu with or junior to the subordinate debentures.
The issuance of the Preferred Securities was part of a
$300,000,000 shelf registration filed with the Securities and
Exchange Commission on March 29, 1995. Southern Union may sell a
combination of preferred securities of financing trusts and
senior and subordinated debt securities of Southern Union of up
to $196,907,200 (the remaining shelf) from time to time, at
prices determined at the time of any offering. The net proceeds
from the $100,000,000 Preferred Securities offering have been
used to repurchase $35,000,000 of 7.60% Senior Debt Securities
through July 1995. The remaining proceeds will be used to repur-
chase additional long-term debt, provide working capital for sea-
sonal needs or for other business opportunities. See "Preferred
Securities of Subsidiary Trust" and "Long-Term Debt" in the Notes
to the Consolidated Financial Statements.
On April 28, 1995, Southern Union entered into an amendment to
their existing $100,000,000 revolving credit facility (the
"Revolving Credit Facility") underwritten by Texas Commerce Bank,
N.A. and syndicated to four additional banks. The amended
Revolving Credit Facility eliminates certain covenants, is
uncollaterized and has no borrowing base limitations as long as
the Company's Senior Debt Securities meet certain rating
criteria. Borrowings under the Revolving Credit Facility are
available for Southern Union's working capital and letter of
credit requirements. The Revolving Credit Facility can also be
used in part, but not to exceed $40,000,000, to fund acquisitions
and capital expenditures. The Revolving Credit Facility contains
certain financial covenants that, among other things, restrict
cash or asset dividends, share repurchases, certain investments
and additional debt. The facility expires on December 31, 1997
but may be extended annually for periods of one year beginning on
September 30, 1994 with the consent of each of the banks. The
revolving credit facility is subject to a commitment fee based on
the rating of the Company's Senior Debt Securities. As of
June 30, 1995 the commitment fee was an annualized .1875% on the
unused balance. No amounts were outstanding under the Revolving
Credit Facility at June 30, 1995 and 1994 as well as at
September 22, 1995.
On January 31, 1994, the Company completed the sale of
$475,000,000 Senior Debt Securities. In addition, on
December 31, 1993 Southern Union completed the Rights Offering to
its existing stockholders to subscribe for and purchase 2,000,000
pre-split and pre-dividend shares of the Company's common stock,
par value $1.00 per share, at a pre-split and pre-dividend price
of $25.00 per share for net proceeds of $49,351,000. The net
proceeds from the sale of the Senior Debt Securities, together
with the net proceeds from the Rights Offering and working
capital from operations, were used to: (i) fund the Missouri
Acquisition; (ii) repay approximately $59,300,000 of borrowings
under the revolving credit facility used to fund the Rio Grande
Acquisition and repurchase all outstanding preferred stock; (iii)
refinance, on January 31, 1994, $10,000,000 aggregate principal
amount of 9.45% Senior Notes due January 31, 2004, and
$25,000,000 aggregate principal amount of 10% Senior Notes due
January 31, 2012 and the related premium of approximately
$10,400,000 resulting from the early extinguishment of such
notes; (iv) refinance, on March 2, 1994, $50,000,000 aggregate
principal amount of 10.5% Sinking Fund Debentures due May 15,
2017 and the related premium of approximately $3,300,000
resulting from the early extinguishment of such debentures;
and (v) refinance, on May 16, 1994, $20,000,000 aggregate princi-
pal amount of 10 1/8% Notes.
The Company's effective rate under the current debt structure is
approximately 7.8% (including interest and the amortization of
debt issuance costs and redemption premiums on refinanced debt).
In March 1993, Southern Union retired 68,000 shares of the Series
A 10% Cumulative Preferred Stock ("Preferred Stock") at $103 per
share for $7,004,000. In April 1993, Southern Union retired
77,000 shares of Preferred Stock at $102 per share for
$7,854,000. In June 1993, Southern Union retired 4,000 shares of
Preferred Stock at $103.50 per share for $414,000 and the
remaining outstanding 100,000 shares at par for $10,000,000.
Investing Activities
As previously discussed, Southern Union acquired Missouri Gas
Energy on January 31, 1994. At closing, Southern Union paid
approximately $400,300,000 in cash, based on account balances as
of December 31, 1993. The final purchase price, which was deter-
mined through post-closing adjustments and subsequent arbitra-
tion, was approximately $401,600,000. See "Contingencies" in the
Notes to the Consolidated Financial Statements. The Missouri
Acquisition was financed through the sale of $475,000,000 of
Senior Debt Securities completed on January 31, 1994, and net
proceeds from the sale of $50,000,000 of common stock in the
Rights Offering completed on December 31, 1993. See "Long-Term
Debt" in the Notes to the Consolidated Financial Statements.
The additional purchase cost assigned to utility plant as a
result of the Missouri Acquisition of approximately $68,000,000
consists of approximately $44,200,000 of excess purchase price
over the historical book carrying value of the net assets
acquired and approximately $23,800,000 of accruals for certain
liabilities assumed and preacquisition contingencies which have
been incurred or estimates of amounts that will be incurred in
the future. The accruals reflect actual or estimated amounts
for: (i) employee severance and other costs associated with an
early retirement program for employees of Missouri Gas Energy of
approximately $11,200,000; (ii) underwriting, legal and
accounting fees associated with the Missouri Acquisition; and
(iii) other preacquisition contingencies. Amortization of the
additional purchase cost assigned to utility plant is provided on
a straight-line basis over forty years.
In September 1993, the Company completed the Rio Grande Acquisi-
tion for approximately $30,500,000. Rio Grande presently serves
approximately 75,000 customers in the south Texas counties of
Willacy, Cameron and Hidalgo, including the cities of Harlingen,
McAllen and Brownsville (the southernmost city in the continental
U.S.). The Company initially funded the purchase with borrowings
from its Revolving Credit Facility. The Rio Grande Acquisition
was accounted for as a purchase.
In July 1993, the Company completed the Eagle Pass Acquisition
for approximately $2,000,000. During May 1993, the Company com-
pleted the Berry Gas Acquisition which system serves the Texas
cities and towns of Nome, Raywood, Hull and Devers for approxi-
mately $274,000. Combined, these operations collectively serve
approximately 4,400 customers. These acquisitions were also
accounted for as purchases.
In March 1993, Southern Union Exploration Company ("SX"), pursu-
ant to a purchase and sale agreement entered into in February
1993, sold substantially all of its oil and gas leasehold
interests and associated production, for $22,000,000 effective
January 1, 1993.
In July 1995, Southern Union Company entered into a letter of
intent to sell WGI, exclusive of certain WGI assets in El Paso,
Texas and WGI's Del Norte interconnect operation which transmits
natural gas into Mexico, and to sell certain gas distribution
operations of Southern Union Gas in the panhandle areas of Texas
and Oklahoma for approximately $14,800,000. The sale is subject
to approval by the FERC and the Oklahoma Corporation Commission
and must be reported to the Railroad Commission of Texas. These
operations will remain consolidated with those of the Company
until the sale has received regulatory approval.
During 1995, 1994 and 1993, the Company expended approximately
$554,157,000 on capital projects including acquisitions. Of that
total, $112,556,000 was incurred on normal expansion of its dis-
tribution system as well as relocation and replacement. For 1995
and 1994, the Company spent approximately $63,139,000 and
$41,300,000 for capital expenditures, respectively, exclusive of
the acquisitions of natural gas distribution properties, which
was used for normal distribution system replacement and expan-
sion. Capital expenditures included $24,476,000 and $9,505,000
related to the Missouri Safety Program in 1995 and 1994, respec-
tively. See "Utility Regulation and Rates" in the Notes to Con-
solidated Financial Statements.
Other Matters
Contingencies
The Company has been named as a potentially responsible party in
a special notice letter from the United States Environmental Pro-
tection Agency for costs associated with removing hazardous sub-
stances from the site of a former coal gasification plant in
Vermont. The Company also assumed responsibility for certain
environmental matters in connection with the Missouri Acquisi-
tion. See "Commitments and Contingencies" in the Notes to
Consolidated Financial Statements.
Regulatory
The Company is continuing to pursue certain changes to rates and
rate structures that are intended to reduce the sensitivity of
earnings to weather including weather normalization clauses and
higher minimum monthly service charges.
On February 10, 1993, the Company's South Texas service area
received an annualized rate increase of $777,000. On July 1,
1993, rates for Austin were changed to provide: (i) an approxi-
mate $1,700,000 base revenue increase; (ii) new and increased
fees that will add approximately $250,000 annually; and (iii)
weather normalization clause revisions. On November 1, 1993, El
Paso rates changed to provide an approximate revenue increase of
$463,000. These rate increases contributed significantly to
Southern Union Gas' earnings in 1994. In addition, on October 5,
1993, the MPSC issued a rate order increasing Missouri Gas
Energy's natural gas rates by $9,750,000 annually effective
October 15, 1993. Southern Union Gas also received several
annual cost of service adjustments in fiscal 1995 and 1994.
Pursuant to a 1989 MPSC order, Missouri Gas Energy is engaged in
a major gas safety program in its service territories. This pro-
gram includes replacement of company- and customer-owned gas ser-
vice and yard lines, the movement and resetting of meters, the
replacement of cast iron mains and the replacement and cathodic
protection of bare steel mains (the "Missouri Safety Program").
In recognition of the significant capital expenditures associated
with this safety program, the MPSC permits the deferral, and sub-
sequent recovery through rates, of depreciation expense, property
taxes and associated carrying costs, related to the Missouri
Safety Program. Missouri Gas Energy was required to continue the
Missouri Safety Program and has deferred depreciation expense,
property taxes and carrying costs of approximately $4,154,000 and
$600,000 for 1995 and 1994, respectively.
Accounting Pronouncements
In March 1995, the Financial Accounting Standards Board ("FASB")
issued Statement of Financial Accounting Standards ("SFAS") No.
121, Accounting for the Impairment of Long-Lived Assets and for
----------------------------------------------------------
Long-Lived Assets To Be Disposed Of, which is effective for
- -----------------------------------
fiscal years beginning after December 15, 1995. SFAS No. 121
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 addi-
tion, SFAS No. 121 requires that regulatory assets meet the
recovery criteria of SFAS No. 71, Accounting for the Effects of
-----------------------------
Certain Types of Regulation, on an ongoing basis in order to con-
- ---------------------------
tinue to defer applicable costs. SFAS No. 121 will be imple-
mented by Southern Union in 1996 and is not expected to have an
impact on the Company since the carrying amount of all assets,
including regulatory assets, is considered recoverable. However,
as the Company enters a more competitive environment, some assets
could potentially be subject to impairment, thereby necessitating
write-downs or write-offs, which could have a material adverse
effect on the Company's future results of operations and finan-
cial position.
The Company adopted the provisions of SFAS No. 112, Employers'
----------
Accounting for Postemployment Benefits, as of January 1, 1994.
- --------------------------------------
This statement requires that the cost of benefits, such as dis-
ability and health care continuation coverage provided to former
or inactive employees after employment but before retirement, be
accrued if attributable to an employee's previously rendered ser-
vice. The Company had previously recognized such postemployment
benefit costs when paid and was allowed recovery in rates as pay-
ments were incurred. Consequently, the Company records a regula-
tory asset and related liability to the extent it intends to file
rate applications to include such costs in rates and such costs
are considered probable of recovery.
The Company also adopted the provisions of SFAS No. 106,
"Employers' Accounting for Postretirement Benefits Other Than
- -------------------------------------------------------------
Pensions," effective as of January 1, 1993. SFAS No. 106
- --------
requires an accrual of postretirement medical and other benefit
liabilities on an actuarial basis during the years an employee
provides services as compared to the pay-as-you-go method. The
Company, excluding Missouri Gas Energy, records a regulatory
asset for the difference between the postretirement costs cur-
rently included in rates and SFAS No. 106 expense to the extent
the Company files, or intends to file, a rate application to
include SFAS No. 106 expense in rates. The Company believes that
it is probable that the relevant regulatory authorities will
allow such expenses in future rates. The Company's adoption,
except for Missouri Gas Energy, of the provisions of SFAS No. 106
resulted in a transition obligation of approximately $9,328,000
which was subsequently reduced to $4,084,000 at June 30, 1994,
primarily as a result of certain plan amendments in 1993. The
Company amortizes the transition obligation over the allowed 20-
year period. Consequently, earnings were not adversely impacted
by the adoption of this statement.
The seller of the Missouri operations also adopted the provisions
of SFAS No. 106 as of January 1, 1993 and filed an application
with the MPSC for an order permitting the deferral of SFAS No.
106 expense and proposed inclusion in the future computation of
cost of service the actual SFAS No. 106 expense and an income
stream generated from a corporate-owned life insurance ("COLI")
owned by the seller. To the extent SFAS No. 106 expense exceeds
income from the COLI program, this excess would be deferred (as
allowed by the FASB Emerging Issues Task Force Issue No. 92-12)
and offset by income generated through the deferral period by the
COLI program. Subsequent to the Missouri Acquisition, the Com-
pany filed an application with the MPSC for an order to permit
the deferral of SFAS No. 106 expense and also proposes the inclu-
sion in the future computation of cost of service the actual SFAS
No. 106 expense and income stream generated from a COLI. As a
result of the MPSC's approval of the application, Missouri Gas
Energy has recorded a regulatory asset and a liability repre-
senting the accumulated benefit obligation as of June 30, 1995
and 1994.
The U.S. House of Representatives is currently considering a
proposal which would phase-out the tax deductibility of interest
on loans under a COLI. The current proposal, if passed, would
be effective on January 1, 1996 and would phase-out the deduc-
tion over a five-year period. The Company anticipates to the
extent that the COLI, as impacted by the Legislature, does not
offset the SFAS No. 106 expense, the Company would be able to
recover the shortfall in rates.
ITEM 8. Financial Statements and Supplementary Data.
Reference is made to the Consolidated Financial Statements of
Southern Union and its consolidated subsidiaries beginning with
the index thereto on page F-1.
ITEM 9. Changes in and Disagreements with Accountants on
Accounting and Financial Disclosure.
None.
<PAGE>
PART III
ITEM 10. Directors and Executive Officers of Registrant.
There is incorporated in this Item 10 by reference the informa-
tion in the Company's definitive proxy statement for the 1995
Annual Meeting of Stockholders under the captions "Election of
Directors," "Executive Officers Who Are Not Directors" and "The
Board of Directors."
ITEM 11. Executive Compensation.
There is incorporated in this Item 11 by reference the informa-
tion in the Company's definitive proxy statement for the 1995
Annual Meeting of Stockholders under the captions "Management
Compensation," "Board of Directors Report on Executive Compensa-
tion," "Company Performance Chart" and "Certain Relationships."
ITEM 12. Security Ownership of Certain Beneficial Owners and
Management.
There is incorporated in this Item 12 by reference the informa-
tion in the Company's definitive proxy statement for the 1995
Annual Meeting of Stockholders under the caption "Security
Ownership."
ITEM 13. Certain Relationships and Related Transactions.
There is incorporated in this Item 13 by reference the informa-
tion in the Company's definitive proxy statement for the 1995
Annual Meeting of Stockholders under the caption "Certain Rela-
tionships."
PART IV
ITEM 14. Exhibits, Financial Statement Schedules and Reports on
Form 8-K.
(a)(1) Financial Statements. Reference is made to the Index on
--------------------
page F-1 for a list of all financial statements filed as
part of this Report.
(a)(2) Financial Statement Schedules. Reference is made to the
-----------------------------
Index on page F-1 for a list of all financial statement
schedules filed as a part of this Report.
(a)(3) Exhibits. Reference is made to the Exhibit Index on
--------
pages E-1, E-2 and E-3 for a list of all exhibits filed
as a part of this Report.
(b) Reports on Form 8-K. Southern Union filed no current
-------------------
reports on Form 8-K during the three months ended
June 30, 1995.
<PAGE>
SOUTHERN UNION COMPANY
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
AND FINANCIAL STATEMENT SCHEDULES
Page(s)
-------
Consolidated financial statements:
Report of independent accountants.....................
Statement of consolidated operations -- years ended
June 30, 1995 and 1994 and December 31, 1993........
Consolidated balance sheet -- June 30, 1995 and 1994..
Statement of consolidated cash flows -- years ended
June 30, 1995 and 1994 and December 31, 1993........
Notes to consolidated financial statements............
Financial statement schedules:
All schedules are omitted as the required information is not
applicable or the information is presented in the consolidated
financial statements or related notes.
<PAGE>
REPORT OF INDEPENDENT ACCOUNTANTS
To the Stockholders and
Board of Directors of
Southern Union Company:
We have audited the consolidated financial statements of Southern
Union Company and Subsidiaries listed in the index on page F-1 of
this Form 10-K. These financial statements are the responsi-
bility of the Company's management. Our responsibility is to
express an opinion on these 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 financial statements are free of material misstatement. An
audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An
audit also includes assessing the accounting principles used and
significant estimates made by management, as well as evaluating
the overall financial statement presentation. We believe that
our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above
present fairly, in all material respects, the consolidated finan-
cial position of Southern Union Company and Subsidiaries as of
June 30, 1995 and 1994, and the consolidated results of their
operations and their cash flows for each of the three years
ended June 30, 1995 and 1994 and December 31, 1993 in
conformity with generally accepted accounting principles.
As discussed in the notes to the consolidated financial state-
ments, the Company changed its method of accounting for
postemployment benefits effective January 1, 1994.
COOPERS & LYBRAND L.L.P.
Austin, Texas
September 5, 1995
<PAGE>
SOUTHERN UNION COMPANY AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED OPERATIONS
Years Ended
-----------------------------------
June 30, December 31,
1995 1994 1993
-------- -------- ------------
(thousands of dollars, except
shares and per share amounts)
Operating revenues.......... $480,046 $374,516 $209,005
Gas purchase costs.......... 241,839 211,127 110,384
-------- -------- --------
Operating margin.......... 238,207 163,389 98,621
-------- -------- --------
Operating expenses:
Operating, maintenance
and general............. 104,072 79,667 50,076
Taxes, other than on
income.................. 39,646 29,770 14,365
Depreciation and
amortization............ 32,373 21,919 14,416
-------- -------- --------
Total operating
expenses.............. 176,091 131,356 78,857
-------- -------- --------
Net operating revenues.. 62,116 32,033 19,764
-------- -------- --------
Other income (expenses):
Interest on long-term
debt.................... (37,448) (23,568) (11,535)
Other interest............ (2,436) (1,896) (2,212)
Dividends on preferred
securities of subsid-
iary trust.............. (1,159) -- --
Other, net................ 5,970 6,994 5,571
-------- -------- --------
Total other expenses,
net................... (35,073) (18,470) (8,176)
-------- -------- --------
Earnings before income
taxes..................... 27,043 13,563 11,588
Federal and state income
taxes..................... 10,974 5,185 3,855
-------- -------- --------
Earnings before preferred
dividends................. 16,069 8,378 7,733
Preferred dividends......... -- -- (843)
-------- -------- --------
Net earnings available
for common stock.......... $ 16,069 $ 8,378 $ 6,890
======== ======== ========
Net earnings per common
share..................... $ 1.40 $ .85 $ .83
======== ======== ========
Weighted average shares
outstanding...............11,478,591 9,865,967 8,286,260
========== ========= =========
See accompanying notes to the consolidated financial statements.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
ASSETS
June 30,
-----------------------
1995 1994
---------- ----------
(thousands of dollars)
Property, plant and equipment:
Plant in service...................... $ 882,769 $ 819,656
Construction work in progress......... 14,670 15,390
---------- ---------
897,439 835,046
Less accumulated depreciation and
amortization........................ (303,327) (279,120)
---------- ---------
594,112 555,926
Additional purchase cost assigned to
utility plant, net of accumulated
amortization of $16,561,000 and
$12,342,000, respectively........... 154,534 167,374
---------- ---------
Net property, plant and equipment... 748,646 723,300
---------- ---------
Current assets:
Cash and cash equivalents............. 39,015 5,881
Short-term investments................ 19,582 --
Accounts receivable, billed and
unbilled............................ 35,465 48,273
Inventories, principally at average
cost................................ 23,561 30,374
Deferred gas purchase costs due from
customers........................... 7,641 --
Prepayments and other................. 1,349 1,621
---------- ---------
Total current assets................ 126,613 86,149
---------- ---------
Deferred charges........................ 114,167 74,367
Real estate............................. 10,742 11,983
Other................................... 2,334 1,913
---------- ---------
Total................................. $1,002,502 $ 897,712
========== ==========
See accompanying notes to the consolidated financial statements.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET (Continued)
STOCKHOLDERS' EQUITY AND LIABILITIES
June 30,
-----------------------
1995 1994
---------- ----------
(thousands of dollars)
Common stockholders' equity:
Common stock, $1 par value;
authorized 50,000,000 shares;
issued 11,570,247 shares at
June 30, 1995...................... $ 11,570 $ 11,497
Premium on capital stock............. 198,819 198,272
Less treasury stock: 51,625 shares
at cost............................ (794) (794)
Retained earnings.................... 16,069 --
---------- ---------
Total common stockholders' equity.. 225,664 208,975
Company-obligated mandatorily
redeemable preferred securities of
subsidiary trust holding solely
$103,093,000 principal amount of
9.48% subordinated notes of
Southern Union due 2025.............. 100,000 --
Long-term debt......................... 462,503 479,048
---------- ---------
Total capitalization............... 788,167 688,023
Current liabilities:
Long-term debt due within one year... 770 889
Accounts payable..................... 28,784 39,039
Federal, state and local taxes....... 6,310 8,706
Accrued interest..................... 15,194 15,579
Customer deposits.................... 14,166 13,029
Deferred gas purchase costs due
to customers....................... -- 15,271
Other................................ 13,621 18,027
---------- ---------
Total current liabilities.......... 78,845 110,540
---------- ---------
Deferred credits and other
liabilities.......................... 99,434 69,437
Accumulated deferred income taxes...... 36,056 29,712
Commitments and contingencies.......... -- --
---------- ---------
Total.............................. $1,002,502 $ 897,712
========== =========
See accompanying notes to the consolidated financial statements.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED CASH FLOWS
Years Ended
--------------------------------
June 30, December 31,
------------------ ------------
1995 1994 1993
-------- -------- ------------
(thousands of dollars)
Cash flows from operating
activities:
Net earnings................ $ 16,069 $ 8,378 $ 7,733
Adjustments to reconcile
net earnings to net cash
flows from operating
activities:
Depreciation and
amortization............. 32,373 21,919 14,416
Deferred income taxes..... 5,909 8,943 1,368
Provision for bad debts... 4,162 2,897 478
Other, net................ (957) (1,316) (1,573)
Changes in assets and
liabilities, net of
acquisitions and dis-
positions:
Decrease (increase) in
accounts receivable,
billed and unbilled.... 11,051 63,059 (1,967)
Decrease in accounts
payable................ (7,225) (4,152) (7,514)
Increase (decrease) in
taxes and other
liabilities............ (7,187) 6,518 6,812
Increase (decrease) in
customer deposits...... 1,137 (75) (3,214)
Decrease in deferred gas
purchase costs......... (22,537) (4,586) (1,473)
Decrease (increase) in
inventories............ 7,975 (9,240) 673
Decrease (increase) in
other accounts......... 902 2,984 (722)
-------- -------- --------
Net cash flows from
operating activities. 41,642 95,329 15,017
-------- -------- --------
Cash flows from investing
activities:
Additions to property,
plant and equipment....... (67,442) (38,237) (18,532)
Acquisition of operations,
net of cash received...... (750) (440,666) (35,559)
Increase in short-term
investments, net.......... (19,582) -- --
Increase (decrease) in
customer advances......... 725 (3,079) 718
Increase (decrease) in
deferred charges and
credits................... (3,868) 5,603 (993)
Proceeds from sale of
discontinued operation.... -- -- 16,493
Proceeds from notes
receivable................ -- 6,368 --
Other, net................. 1,801 (644) (1,979)
-------- -------- --------
Net cash flows used in
investing activities..... (89,116) (470,655) (39,852)
-------- -------- --------
Cash flows from financing
activities:
Repayment of debt.......... (16,212) (107,052) (938)
Net borrowings (payments)
under revolving credit
facility.................. -- (28,200) 6,200
Issuance of debt........... -- 475,000 --
Premium on early
extinguishment of debt.... -- (13,715) --
Debt issuance cost......... -- (5,450) --
Proceeds from rights
offering, net............. -- 49,351 49,351
Proceeds from issuance of
preferred securities of
subsidiary trust.......... 100,000 -- --
Issuance cost of preferred
securities of subsidiary
trust..................... (3,799) -- --
Redemption of preferred
stock including related
premiums.................. -- -- (25,272)
Other, net................. 619 (905) (1,677)
-------- -------- --------
Net cash flows from
financing activities..... 80,608 369,029 27,664
-------- -------- --------
Increase (decrease) in cash
and cash equivalents........ 33,134 (6,297) 2,829
Cash and cash equivalents at
beginning of year........... 5,881 12,178 89
-------- -------- --------
Cash and cash equivalents at
end of year................. $ 39,015 $ 5,881 $ 2,918
======== ======== ========
See accompanying notes to the consolidated financial statements.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
June 30, 1995 and 1994 and December 31, 1993
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Operations and Principles of Consolidation
Southern Union Company ("Southern Union" and, together with its
wholly-owned subsidiaries, the "Company"), is an investor-owned
public utility primarily engaged in the distribution and sale of
natural gas to residential, commercial, industrial, agricultural
and other customers as a public utility in the states of Texas,
Missouri and Oklahoma. See "Acquisitions and Divestitures."
Subsidiaries of Southern Union also market natural gas to end-
users, sell natural gas as a vehicular fuel, operate intrastate
and interstate natural gas pipeline systems, sell commercial gas
air conditioning and other gas-fired engine-driven applications
and convert vehicles to operate on natural gas. Certain subsidi-
aries own or hold interests in real estate and other assets,
which are primarily used in the Company's utility business. Sub-
stantial operations of the Company are subject to regulation.
The consolidated financial statements include the accounts of
Southern Union and its wholly-owned subsidiaries. All significant
intercompany accounts and transactions are eliminated in consoli-
dation. All dollar amounts in the tables in the notes to con-
solidated financial statements, except per share amounts, are
stated in thousands unless otherwise indicated. Certain reclas-
sifications have been made to prior years' financial statements
to conform with the current year's presentation.
Property, Plant and Equipment
Utility plant in service and construction work in progress are
stated at original cost of construction, less contributions in
aid of construction, which includes, where appropriate, payroll-
related costs such as taxes, pensions, other employee benefits,
general and administrative costs and an allowance for funds used
during construction. Gain or loss is recognized upon the dispo-
sition of significant utility properties and other property con-
stituting operating units. Gain or loss from minor dispositions
of property is charged or credited to accumulated depreciation
and amortization. The Company capitalizes the cost of signifi-
cant internally-developed computer software systems.
Acquisitions are recorded at the historical book carrying value
of utility plant. Additional purchase cost assigned to utility
plant is the excess of the purchase price over the book carrying
value of the net assets acquired. In general, the Company has
not been allowed direct recovery of additional purchase cost
assigned to utility plant in rates. Periodically, the Company
evaluates the carrying value of its additional purchase cost
assigned to utility plant by comparing the anticipated future
operating income from the businesses giving rise to the addi-
tional purchase cost with the unamortized balance.
In March 1995, the Financial Accounting Standards Board ("FASB")
issued Statement of Financial Accounting Standards ("SFAS") No.
121, Accounting for the Impairment of Long-Lived Assets and for
----------------------------------------------------------
Long-Lived Assets To Be Disposed Of, which is effective for fis-
- -----------------------------------
cal years beginning after December 15, 1995. SFAS No. 121
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 addi-
tion, SFAS No. 121 requires that regulatory assets meet the
recovery criteria of SFAS No. 71, Accounting for the Effects of
-----------------------------
Certain Types of Regulation, on an ongoing basis, in order to
- ---------------------------
continue to defer applicable costs. SFAS No. 121 will be imple-
mented by Southern Union in 1996 but is not expected to have an
impact on the Company since the carrying amount of all assets,
including regulatory assets, is considered recoverable. As the
Company enters a more competitive environment, some assets could
potentially be subject to impairment, thereby necessitating
write-downs or write-offs, which could have a material adverse
effect on the Company's future results of operations and finan-
cial position.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Depreciation and Amortization
Depreciation of utility plant is provided at an average
straight-line rate of approximately 3% per annum of the cost of
such depreciable properties less applicable salvage. Franchises
are amortized over their respective lives. Depreciation and
amortization of other property is provided at straight-line rates
estimated to recover the costs of the properties, after allowance
for salvage, over their respective lives. Amortization of addi-
tional purchase cost assigned to utility plant is provided on a
straight-line basis over forty years unless the Company has
obtained, or filed to obtain, a specific provision in a rate
application providing for the recovery of this amortization in
rates collected from customers over a different period. In those
cases where the Company's regulators have provided for, or are
expected to provide for, the recovery of the amortization of
additional purchase cost assigned to utility plant in rates, the
Company's policy is to utilize the amortization period which fol-
lows the rate recovery period. See "Change in Accounting Esti-
mate."
Long-Term Debt
Debt issuance costs and premiums on the early extinguishment of
debt are amortized over the lives of the new or replacement debt
issues.
Gas Utility Revenues and Gas Purchase Costs
Gas utility customers are billed on a monthly-cycle basis. The
related cost of gas is matched with cycle-billed revenues through
operation of purchased gas adjustment provisions in tariffs
approved by the regulatory agencies having jurisdiction.
The Company recognizes an estimate of unbilled revenues on a
monthly-cycle basis which include sales from the cycle-billing
dates to the end of the month, unbilled gas purchase costs and
revenue-related taxes. The accrual for unbilled revenues is
included in operating revenues in the statement of consolidated
operations.
Employee Postretirement Benefits
The Company, excluding Missouri Gas Energy, records a regulatory
asset for the difference between the postretirement costs cur-
rently included in rates and postretirement expense to the extent
the Company has filed, or intends to file, a rate application to
include such expense in rates and it is probable that the regula-
tor will allow this expense in future rates. Subsequent to the
Missouri Acquisition (as hereinafter defined), the Company filed
an application with the Missouri Public Service Commission
("MPSC") for an order to permit the deferral of postretirement
expense and also proposed the inclusion in rates billed to custo-
mers in the future for the actual postretirement expense and
income stream generated from a company-owned life insurance
("COLI") plan. As a result of the MPSC's approval of the appli-
cation, Missouri Gas Energy has recorded a regulatory asset and a
liability representing the accumulated benefit obligation as of
June 30, 1995 and 1994. The U.S. House of Representatives is
currently considering a proposal which would phase-out the tax
deductibility of interest on loans under a COLI. The current
proposal, if passed, would be effective on January 1, 1996 and
would phase-out the deduction over a five-year period. The
Company anticipates to the extent that the COLI, as impacted
by the Legislature, does not offset the SFAS No. 106 expense,
the Company would be able to recover the shortfall in rates.
Postemployment Benefits
The Company adopted the provisions of SFAS No. 112, Employers'
----------
Accounting for Postemployment Benefits, as of January 1, 1994.
- --------------------------------------
This statement requires that the cost of benefits, such as dis-
ability and health care continuation coverage provided to former
or inactive employees after employment but before retirement, be
accrued if attributable to an employee's previously rendered ser-
vice. The Company had previously recognized such postemployment
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
benefit costs when paid and was allowed recovery in rates as pay-
ments were incurred. Consequently, the Company records a regula-
tory asset and related liability to the extent it intends to file
rate applications to include such costs in rates and such costs
are considered probable of recovery.
Taxes on Income
The Company accounts for income taxes utilizing the liability
method which bases the amounts of current and future tax assets
and liabilities on events recognized in the financial statements
and on income tax laws and rates existing at the balance sheet
date.
Cash Flows and Credit Risk
Cash Flows. The Company considers all highly liquid investments
- ----------
with an original maturity of three months or less to be cash
equivalents. Short-term investments are highly liquid invest-
ments with maturities of more than three months when purchased,
and are carried at cost, which approximates market. The Company
places its temporary cash investments with a high credit quality
financial institution which, in turn, invests the temporary funds
in a variety of high-quality short-term financial securities.
Credit Risk. Concentrations of credit risk in trade receivables
- -----------
are limited due to the large customer base with relatively small
individual account balances. In addition, Company policy
requires a deposit from certain customers. The Company has
recorded an allowance for doubtful accounts totaling approxi-
mately $2,100,000 and $1,600,000 at June 30, 1995 and 1994,
respectively.
Fair Value of Financial Instruments
The carrying amount reported in the balance sheet for cash and
cash equivalents, short-term investments, accounts receivable and
accounts payable approximates its fair value. The fair value of
the Company's long-term debt is estimated using current market
quotes and other estimation techniques.
Inventories
Inventories are stated at cost and consist of gas in underground
storage and materials and supplies. Gas in underground storage
of approximately $15,427,000 and $23,099,000 at June 30, 1995 and
1994, respectively, consists of approximately 9,701,000 and
10,834,000 MMBtu's, respectively.
Earnings Per Share
Earnings per common share is based on net earnings available for
common stock using the weighted average shares outstanding during
each period. Fully diluted earnings per share are not presented
because the relevant stock options and warrants are not signifi-
cant.
CHANGE IN FISCAL YEAR
On May 25, 1994, Southern Union's Board of Directors approved a
change in the Company's fiscal year-end from December 31 to
June 30. The new fiscal year more closely conforms the reporting
of the Company's financial condition and results of operations to
its seasonal business cycle.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
ACQUISITIONS AND DIVESTITURES
Missouri Gas Energy
Missouri Asset Purchase Agreement. On July 9, 1993, Southern
- ---------------------------------
Union entered into an Agreement for the Purchase of Assets (the
"Missouri Asset Purchase Agreement") with Western Resources, Inc.
("Western Resources" or the "seller" of the Missouri properties),
pursuant to which Southern Union purchased certain Missouri
natural gas distribution operations (the "Missouri Acquisition")
which Southern Union operates as Missouri Gas Energy, a division
of Southern Union headquartered in Kansas City, Missouri. The
acquisition was consummated on January 31, 1994 and was accounted
for as a purchase. The assets of Missouri Gas Energy were
included in the consolidated balance sheet of the Company at
January 31, 1994 and income from operations of Missouri Gas
Energy has been included in the Company's statement of consoli-
dated operations since February 1, 1994. Missouri Gas Energy
serves approximately 478,000 customers in central and western
Missouri, including Kansas City, St. Joseph, Joplin and Monett.
Purchase Price. At closing, Southern Union paid approximately
- --------------
$400,300,000, based on account balances as of December 31, 1993.
The final purchase price, which was determined through post-
closing adjustments and subsequent arbitration was approximately
$401,600,000. See "Contingencies". The Missouri Acquisition was
financed through the sale of $475,000,000 of 7.60% Senior Notes
due 2024 (the "Senior Debt Securities") completed on January 31,
1994 and net proceeds from a $50,000,000 common stock subscrip-
tion rights offering (the "Rights Offering") completed on
December 31, 1993. See "Long-Term Debt" and "Stockholders
Equity."
Missouri Public Service Commission. The approval of the Missouri
- ----------------------------------
Acquisition by the Missouri Public Service Commission ("MPSC")
was subject to the terms of a stipulation and settlement agree-
ment (the "MPSC Stipulation") among Southern Union, the seller,
the MPSC Staff and others. Among other things, the MPSC Stipula
tion: (i) provides that the Company attain a total debt to total
capital ratio that does not exceed Standard and Poor's Corpora-
tion's Utility Financial Benchmark ratio for the lowest invest-
ment grade (BBB) investor-owned natural gas distribution company
(which currently is approximately 58%) in order for Missouri Gas
Energy to implement any general rate increase; (ii) prohibits
Missouri Gas Energy from implementing a general rate increase in
Missouri before January 31, 1997 except in certain unusual
events; (iii) required the seller to contribute an additional
$9,000,000 to Missouri Gas Energy's employees' and retirees'
qualified defined benefit plan assets transferred to the Company;
(iv) requires the Company to contribute an additional $3,000,000
to the Company's qualified defined benefit plan for the benefit
of Missouri Gas Energy's employees and retirees in excess of the
minimum required contribution under the Internal Revenue Code,
Section 412, as determined by the plan's actuary; and (v)
requires Missouri Gas Energy to reduce rate base by $30,000,000
(amortized over a ten year period on a straight-line basis) to
compensate rate payers for rate base reductions that were elimi
ated as a result of the Missouri Acquisition.
Liabilities Assumed. Southern Union assumed certain liabilities
- -------------------
of the seller with respect to the Missouri properties, including
certain liabilities arising from certain specified contracts
assigned to Southern Union at closing, including gas supply and
transportation contracts, office equipment leases and real estate
leases, liabilities arising from certain contracts entered into
by the seller in the ordinary course of business, certain
liabilities that have arisen or may arise from the operations of
Missouri Gas Energy, and liabilities for certain accounts payable
of the seller pertaining to Missouri Gas Energy. See "Commit-
ments and Contingencies."
Employees. Pursuant to the terms of an Employee Agreement with
- ---------
the seller, after the closing of the Missouri Acquisition,
Southern Union employed certain employees involved in the opera
tion of Missouri Gas Energy ("Continuing Employees"). Under the
terms of the Employee Agreement, the assets and liabilities of
the seller's qualified defined benefit plans attributable to Con-
tinuing Employees and certain retired Missouri employees
("Retired Employees") were transferred to a qualified defined
benefit plan of Southern Union that for at least two years will
provide benefits to Continuing Employees and Retired Employees
substantially similar in aggregate to those provided by the
seller's qualified defined benefit plans. Southern Union amended
its qualified defined benefit plan to cover
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
the Continuing Employees and Retired Employees and provide Con-
tinuing Employees and Retired Employees with certain welfare,
separation and other benefits.
Additional Purchase Cost Assigned to Utility Plant. The addi-
- --------------------------------------------------
tional purchase cost assigned to utility plant as a result of the
Missouri Acquisition is approximately $68,000,000 consisting of
approximately $44,200,000 of excess purchase price over the his
torical book carrying value of the net assets acquired and
approximately $23,800,000 of accruals for certain liabilities
assumed and preacquisition contingencies which have been incurred
or estimates of amounts that will be incurred in the future. The
accruals reflect actual or estimated amounts for: (i) employee
severance and other costs associated with an early retirement
program offered to certain employees of Missouri Gas Energy in
1994 of approximately $11,200,000; (ii) underwriting, legal and
accounting fees associated with the Missouri Acquisition; and
(iii) other preacquisition contingencies. Amortization of the
additional purchase cost assigned to utility plant is provided on
a straight-line basis over forty years.
Rio Grande Valley
In September 1993, the Company acquired the Rio Grande Valley Gas
Company ("Rio Grande") for approximately $30,500,000. The Rio
Grande system currently serves approximately 75,000 customers in
the south Texas counties of Willacy, Cameron and Hidalgo. Rio
Grande's service area includes 32 towns and cities along the
Mexico border, including Harlingen, McAllen and Brownsville (the
southernmost city in the continental U.S.). The Company
initially funded the Rio Grande purchase with borrowings from its
revolving credit facility which were subsequently repaid with
proceeds from the sale of the Senior Debt Securities and the
Rights Offering. The assets of Rio Grande were included in the
Company's consolidated balance sheet at September 30, 1993 and
the earnings from operations of Rio Grande has been included in
the Company's statement of consolidated operations since
October 1, 1993. The acquisition was accounted for using the
purchase method. The additional purchase cost assigned to
utility plant of approximately $12,000,000 reflects the excess of
the purchase price over the historical book carrying value of the
net assets acquired. The additional purchase cost assigned to
utility plant is amortized on a straight-line basis over forty
years.
Other Acquisitions and Divestitures
In July 1993, the Company acquired the natural gas distribution
facilities serving the city of Eagle Pass, Texas for approxi-
mately $2,000,000. In May 1993, the Company acquired the natural
gas distribution facilities of Berry Gas Company which serves the
Texas cities and towns of Nome, Raywood, Hull and Devers for
approximately $274,000. Combined, these operations collectively
serve approximately 4,400 customers. These acquisitions were
accounted for as purchases.
In February 1993, Southern Union Exploration Company ("SX"), a
former wholly-owned subsidiary of Southern Union, entered into a
purchase and sale agreement to sell substantially all of its oil
and gas leasehold interests and associated production for
approximately $22,000,000, which sale was completed on March 31,
1993, effective January 1, 1993. SX, engaged in the development
and production of oil and gas, held varying interests in pro-
ducing oil and gas wells located primarily in New Mexico and
Texas. The Company accounted for SX as a business held for sale
wherein adjustments were made to reflect the valuation of this
business to an estimated net realizable value. At December 31,
1992, the Company recorded a book loss on future disposal of
$4,400,000. In addition, the Company recorded a tax liability of
approximately $6,960,000 resulting from the recognition of a tax
basis gain of approximately $18,800,000.
The results of operations of the Company for the periods subse-
quent to these acquisitions and divestiture are not comparable to
those periods prior to the acquisitions and divestiture nor are
the 1995 and 1994 results of operations comparable with previous
periods.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
During July 1995, Southern Union Company entered into a letter of
intent to sell Western Gas Interstate Company ("WGI"), a wholly-
owned subsidiary of the Company, exclusive of certain WGI assets
in El Paso, Texas and WGI's Del Norte interconnect operation
which transmits natural gas into Mexico, and to sell certain gas
distribution operations of Southern Union Gas in the panhandle
areas of Texas and Oklahoma for approximately $14,800,000. The
sale is subject to approval by the Federal Regulatory Energy Com-
mission ("FERC") and the Oklahoma Corporation Commission and must
be reported to the Railroad Commission of Texas.
PRO FORMA CONDENSED STATEMENT OF CONSOLIDATED OPERATIONS
The following unaudited pro forma condensed statement of consoli-
dated operations for the twelve months ended June 30, 1994 is
presented as though the following events had been consummated as
of July 1, 1993: (i) the Missouri and Rio Grande Acquisitions;
(ii) the sale of the Senior Debt Securities; (iii) the completion
of the Rights Offering; and (iv) the refinancing of certain
short-term and long-term debt. The pro forma financial informa-
tion is not necessarily indicative of the results which would
have actually been obtained had the acquisitions of Missouri
Gas Energy and Rio Grande, the Rights Offering, the sale of
Senior Debt Securities or the refinancings been completed as of
the assumed date for the periods presented or which may be
obtained in the future.
The pro forma condensed statement of consolidated operations
includes adjustments that are based on assumptions and estimates
made by the Company's management regarding anticipated
efficiencies resulting from the combined operations, reductions
in costs planned by management, accruals for certain preacquisi-
tion contingencies and the fair market value of certain assets
acquired in the Missouri Acquisition.
Twelve Months Ended
June 30, 1994
-------------------
(unaudited)
Operating revenues........................... $ 604,962
Gas purchase costs........................... 360,706
----------
Operating margin........................... 244,256
Operating expenses........................... 195,045
----------
Net operating revenues....................... 49,211
Interest on long-term debt................... (37,345)
Other income, net............................ 4,663
----------
Earnings before income taxes............... 16,529
Federal and state income taxes............... 6,281
----------
Net earnings available for common stock...... $ 10,248
==========
Net earnings per common share................ $ .90
==========
Weighted average shares outstanding.......... 11,433,000
==========
CHANGE IN ACCOUNTING ESTIMATE
On February 6, 1990, Southern Union and SU Acquisition, Inc. com-
pleted a cash merger in accordance with an agreement among
Southern Union, Metro Mobile CTS, Inc., and SU Acquisition, Inc.
This merger was accounted for as a purchase and resulted in the
recording of additional purchase cost assigned to utility plant
of approximately $94,000,000. At the time of the merger, the
Company had anticipated the inclusion of this additional purchase
price in future rates. Accordingly, amortization of the addi-
tional purchase cost assigned to utility plant had been provided
on a straight-line basis over thirty years which was consistent
with the period over which rate recovery was requested. Subse-
quent to the merger, the Company filed rate applications with
several of its significant regulatory jurisdictions requesting
the inclusion of the additional purchase cost assigned to utility
plant in rates. Since such requests for rate recovery have not
yet been granted, the Company revised its estimate of the
amortization period of additional
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
purchase cost assigned to utility plant to its standard policy of
forty years. As a result of this change, amortization expense
for the year ended June 30, 1994 was reduced by approximately
$478,000, with a corresponding increase to net earnings, or $.05
per average common share.
OTHER INCOME
Other income, net in 1995, 1994 and 1993 was $5,970,000,
$6,994,000 and $5,571,000, respectively.
Other income of $5,970,000 in 1995 included: rental income from
Lavaca Realty Company ("Lavaca Realty"), the Company's real
estate subsidiary, of approximately $2,647,000; approximately
$2,619,000 related to the deferral of interest expense associated
with the Missouri Gas Energy Safety Program (see "Utility Regula-
tion and Rates"); investment interest and interest on notes
receivable of approximately $960,000; and approximately $244,000
from gas appliance merchandising. This was partially offset by
approximately $750,000 for the write-down to estimated fair
market value of certain real estate held for sale.
As a result of the change in the Company's year-end to June 30,
certain other income items are included in both the 1994 and 1993
results of operations. In September 1993, the Company recorded a
non-recurring accounting adjustment of approximately $2,489,000
to reverse a tax reserve upon the final settlement of prior
period federal income tax audits and the filing of amended
federal income tax returns. In July 1993, the Company paid the
Internal Revenue Service ("IRS") approximately $1,266,000 in
settlement for federal income taxes and interest related to the
tax years 1984 through 1989. The Company had previously esti-
mated and accrued an amount for the tax deficiencies and related
interest and, as a result of the settlement with the IRS for a
lesser amount, a non-recurring adjustment was recorded to reverse
the tax reserve in excess of the payment made. The reversal of
the reserve had no impact on liquidity or cash flows due to the
non-cash impact of this adjustment. Other items recorded during
the period in common to both 1994 and 1993 were a pre-tax gain of
approximately $494,000 on the sale of undeveloped real estate and
the write-off of approximately $357,000 of acquisition-related
costs as a result of the termination of negotiations related to
various acquisitions.
Other income of $6,994,000 recorded in 1994 also included:
rental income from Lavaca Realty of approximately $2,200,000;
investment interest and interest on notes receivable of approxi-
mately $950,000; approximately $500,000 from gas appliance
merchandising; and approximately $276,000 related to the deferral
of interest expense associated with the Missouri Gas Energy
Service Line Replacement Program.
Other income of $5,571,000 recorded in 1993 also included: rental
income from Lavaca Realty of approximately $1,835,000; interest
on notes receivable of approximately $830,000; and a pre-tax gain
of approximately $494,000 on the sale of undeveloped real estate.
CASH FLOW INFORMATION
1995 1994 1993
---------- ---------- ----------
Cash paid during the year
for:
Interest................. $ 38,987 $ 12,001 $ 12,820
Income taxes............. 2,533 5,820 9,691
Non-cash assets
(liabilities) acquired:
Working capital.......... $ -- $ 50,999 $ (718)
Property, plant and
equipment, net......... 750 385,650 36,376
Other noncurrent assets.. -- 46,988 72
Noncurrent liabilities... -- (42,971) (171)
-------- -------- --------
$ 750 $440,666 $ 35,559
======== ======== ========
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Excluded from the statement of consolidated cash flows were the
following effects of non-cash investing and financing activities:
1995 1994 1993
---------- ---------- ----------
Pension liability adjustment
to retained earnings....... $ -- $ -- $ 2,051
======== ======== ========
Other obligations incurred... $ -- $ 2,354 $ 588
======== ======== ========
PROPERTY, PLANT AND EQUIPMENT
A financial classification for utility plant in service at
June 30, 1995 and 1994 was as follows:
June 30,
----------------------
1995 1994
---------- ----------
Distribution............................ $831,401 $770,268
General................................. 70,713 63,966
Intangible.............................. 8,512 10,803
Transmission............................ 11,194 10,765
Production and gathering................ 2,618 2,716
-------- --------
Total utility plant................... 924,438 858,518
Less contributions in aid of
construction.......................... (41,669) (38,862)
-------- --------
Plant in service...................... 882,769 819,656
Construction work in progress........... 14,670 15,390
-------- --------
897,439 835,046
Less accumulated depreciation and
amortization.......................... (303,327) (279,120)
-------- --------
594,112 555,926
Additional purchase cost assigned to
utility plant, net.................... 154,534 167,374
-------- --------
Net property, plant and equipment..... $748,646 $723,300
======== ========
REAL ESTATE
In February 1993, Southern Union entered into a settlement agree-
ment with the Resolution Trust Corporation ("RTC") with respect
to Southern Union's former subsidiary, First Bankers Trust &
Savings Association. As part of the settlement, in return for
payment by the Company of $4,792,000, the RTC: dismissed a
$6,174,000 judgment for specific performance of a contract to
purchase real estate; canceled notes in the principal amount of
$1,600,000; permitted the Company to terminate a $2,000,000
letter of credit; deeded the Company a 21-acre tract in Austin,
Texas; and released certain other claims asserted in the settled
litigation. This settlement had no impact on earnings since the
Company had previously recorded a reserve for the related loss
contingency. Subsequently, the Company sold this land for
approximately $794,000 resulting in an after-tax gain of approxi-
mately $320,000.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
STOCKHOLDERS' EQUITY
The changes in common stockholders' equity and cumulative pre-
ferred stock were as follows:
Common Stockholders' Equity
-------------------------------------------
Trea- Cumulative
Common Premium sury Preferred
Stock, on Stock, Retained Stock $100
$1 Par Capital at Earnings Stated
Value Stock Cost (Deficit) Total Value
------- -------- ------ --------- --------- ----------
Balance
January 1,
1993...... $ 5,289 $144,748 $(794) $ (1,240) $148,003 $ 24,900
Net
earn-
ings.... -- -- -- 7,733 7,733 --
Dividends
on pre-
ferred
stock.,, -- -- -- (843) (843) --
Rights
Offering
for
2,000,000
shares of
common
stock... 2,000 47,351 -- -- 49,351 --
Exercise
of stock
options. 17 199 -- -- 216 --
Pension
liability
adjust-
ment.... -- -- -- (2,051) (2,051) --
Redemp-
tion of
preferred
stock... -- -- -- (471) (471) (24,900)
------- -------- ----- -------- -------- --------
Balance
Decem-
ber 31,
1993...... $ 7,306 $192,298 $(794) $ 3,128 $201,938 $ --
======= ======== ===== ======== ======== ========
Balance
at
July 1,
1993
(see
"Change
in
Fiscal
Year").... $ 5,302 $144,902 $(794) $ 1,744 $151,154 $ --
Net
earn-
ings.... -- -- -- 8,378 8,378 --
Rights
offering
for
2,000,000
shares of
common
stock... 2,000 47,351 -- -- 49,351 --
Three-
for-two
stock
split... 3,628 (3,628) -- -- -- --
Stock
divi-
dend.... 545 9,524 -- (10,069) -- --
Exercise
of stock
options. 22 186 -- -- 208 --
Stock
issuance
costs
and
other... -- (63) -- (53) (116) --
------- -------- ----- -------- -------- --------
Balance
June 30,
1994...... 11,497 198,272 (794) -- 208,975 --
Net
earn-
ings.... -- -- -- $ 16,069 $ 16,069 $ --
Exercise
of stock
options. 73 547 -- -- 620 --
------- -------- ----- -------- -------- --------
Balance
June 30,
1995...... $11,570 $198,819 $(794) $ 16,069 $225,664 $ --
======= ======== ===== ======== ======== ========
Stock Dividend and Split
On May 25, 1994, Southern Union's Board of Directors declared a
5% stock dividend, distributed on June 30, 1994 to stockholders
of record on June 14, 1994. A portion of the 5% stock dividend
was characterized as a distribution of capital due to the level
of the Company's retained earnings available for distribution as
of the declaration date. The June 1994 stock dividend was consis-
tent with the Board of Directors' decision in February 1994 to
commence regular stock dividends of approximately 5% annually.
In addition, on February 11, 1994, the Board of Directors
declared a three-for-two stock split distributed in the form of a
50% stock dividend on March 9, 1994, to stockholders of record on
February 23, 1994. Unless otherwise stated, all per share data
included in the accompanying consolidated financial statements
and in these Notes to Consolidated Financial Statements have been
restated to give effect to the stock dividend and stock split.
Rights Offering
On December 31, 1993, Southern Union consummated a Rights
Offering to its existing stockholders to subscribe for and pur-
chase 2,000,000 pre-split and pre-dividend shares of the Com-
pany's common stock, par value $1.00 per share, at a pre-split
and pre-dividend price of $25.00 per share for net proceeds of
$49,351,000. The proceeds from
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
the Rights Offering, together with the proceeds from the sale of
the Senior Debt Securities, were used to fund the Missouri and
Rio Grande Acquisitions and to retire or refinance certain out-
standing debt. See "Acquisitions and Divestitures" and "Long-
Term Debt."
Common Stock
The Company has an incentive stock option plan (the "1982 Plan")
pursuant to which the ability to grant options expired on
December 31, 1991. Under the terms of the 1982 Plan, options to
purchase up to an aggregate of 787,500 post-split and post-
dividend shares of common stock were granted to officers and key
employees at prices not less than fair market value on the date
of grant. Options granted under the 1982 Plan are exercisable
for periods of ten years from the date of grant or such lesser
period as may be designated for particular options, and become
exercisable after a specified time from the date of grant in
cumulative annual installments. Upon exercise of an option, the
1982 Plan permitted the Company to elect, instead of issuing
shares, to make a cash payment equal to the difference at the
date of exercise between the option price and the market price of
the shares as to which such option is being exercised.
The 1992 Long-Term Stock Incentive Plan (the "1992 Long-Term
Plan") was approved at the annual meeting of stockholders held on
May 12, 1993. Under the 1992 Long-Term Plan, options to purchase
819,000 post-split and post-dividend shares may be granted to
officers and key employees at prices not less than the fair mar-
ket value on the date of grant. Options granted under the 1992
Long-Term Plan are exercisable for periods of ten years from the
date of grant or such lesser period as may be designated for
particular options, and become exercisable after a specified
period of time from the date of grant in cumulative annual
installments. The 1992 Long-Term Plan also allows for the
granting of stock appreciation rights, dividend equivalents,
performance shares and restricted stock.
Information regarding the 1982 Plan and the 1992 Long-Term Plan,
as adjusted for the stock dividend and stock split, is summarized
below:
1992
1982 Long-Term
Plan Plan
-------- ---------
Outstanding January 1, 1993................. 384,300 241,763
Exercised................................. (20,475) (5,513)
Canceled.................................. (14,175) (6,300)
------- -------
Outstanding December 31, 1993............... 349,650 229,950
Granted................................... -- 222,075
Exercised................................. (20,475) --
------- -------
Outstanding June 30, 1994................... 329,175 452,025
Exercised................................. (72,075) (1,103)
Canceled.................................. -- (2,837)
------- -------
Outstanding June 30, 1995................... 257,100 448,085
======= =======
Average price of options exercised
during the year ended:
1993...................................... $ 7.78 $ 10.13
1994...................................... $ 7.78 --
1995...................................... $ 8.44 $ 10.13
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
At June 30, 1995 and 1994 and December 31, 1993, options under
the 1982 Plan for 209,850, 222,075 and 204,750 shares were
exercisable at prices ranging from $7.78 to $8.73. At June 30,
1995 and 1994 and December 31, 1993, options for 136,552, 40,320
and 40,320 shares ranging from $8.71 to $17.63 were exercisable
under the 1992 Long-Term Plan. No shares were available for
future option grants under the 1982 Plan at June 30, 1995 and
1994 and December 31, 1993. There were 364,299, 361,462 and
583,537 shares available for future option grants under the 1992
Long-Term Plan at June 30, 1995 and 1994 and December 31, 1993,
respectively. The shares granted in the year ended June 30, 1994
were repriced on April 4, 1994 from an originally granted
exercise price of $21.82 per share to a new exercise price of
$17.63 per share.
On February 10, 1994, Southern Union granted to Fleischman and
Walsh L.L.P., legal counsel to the Company, a warrant which was
also repriced amended on April 4, 1994 and which expires on
February 10, 2004, to purchase up to 39,375 shares of Common
Stock at an exercise price of $17.63, as adjusted for the 5%
stock dividend and three-for-two stock split.
Retained Earnings
Under the most restrictive provisions in effect, as a result of
the sale of Senior Debt Securities, Southern Union will not
declare or pay any cash or asset dividends on common stock (other
than dividends and distributions payable solely in shares of its
common stock or in rights to acquire its common stock) or acquire
or retire any shares of Southern Union's common stock, unless no
event of default exists and the Company meets certain financial
ratio requirements. In addition, Southern Union's charter
relating to the issuance of preferred stock limits the payment of
cash or asset dividends on capital stock.
Cumulative Preferred Stock
During March 1993, Southern Union retired 68,000 shares of the
Series A 10% Cumulative Preferred Stock ("Preferred Stock") at
$103 per share for $7,004,000. In April 1993, Southern Union
retired 77,000 shares of Preferred Stock at $102 per share for
$7,854,000. In June 1993, Southern Union retired 4,000 shares of
Preferred Stock at $103.50 per share for $414,000 and the
remaining outstanding 100,000 shares at par for $10,000,000.
PREFERRED SECURITIES OF SUBSIDIARY TRUST
On May 17, 1995, Southern Union Financing I (the "Subsidiary
Trust"), a consolidated wholly-owned subsidiary of Southern
Union, issued $100,000,000 of 9.48% Trust Originated Preferred
Securities (the "Preferred Securities"). In connection with the
Subsidiary Trust's issuance of the Preferred Securities and the
related purchase by Southern Union of all of the Subsidiary
Trust's common securities (the "Common Securities"), Southern
Union issued to the Subsidiary Trust $103,092,800 principal
amount of its 9.48% Subordinated Deferrable Interest Notes,
due 2025 (the "Subordinated Notes"). The sole assets of the
Subsidiary Trust are and will be the Subordinated Notes. The
interest and other payment dates on the Subordinated Notes
correspond to the distribution and other payment dates on the
Preferred Securities and the Common Securities. Under certain
circumstances, the Subordinated Notes may be distributed to
holders of the Preferred Securities and holders of the Common
Securities in liquidation of the Subsidiary Trust. The Sub-
ordinated Notes are redeemable at the option of the Company
on or after May 17, 2000, at a redemption price of $25 per
Subordinated Note plus accrued and unpaid interest. The
Preferred Securities and the Common Securities will be
redeemed on a pro rata basis to the same extent as the Sub-
ordinated Notes are repaid, at $25 per Preferred Security
and Common Security plus accumulated and unpaid distribu-
tions. Southern Union's obligations under the Subordinated
Notes and related agreements, taken together, constitute a
full and unconditional guarantee by Southern Union of pay-
ments due on the Preferred Securities. As of June 30, 1995,
4,000,000 shares of Preferred Securities were outstanding.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
LONG-TERM DEBT
First mortgage bonds, debentures and other long-term debt
outstanding, including current maturities, were as follows:
June 30,
----------------------
1995 1994
---------- ----------
First mortgage bonds:
11.5% due 2000 -- collateralized by
certain utility plant in service..... $ 1,200 $ 1,700
Other long-term debt:
7.60% Senior notes due 2024............ 460,000 475,000
Other.................................. 2,073 3,237
-------- --------
Total long-term debt..................... $463,273 $479,937
======== ========
The maturities of long-term debt for each of the next five years
ended June 30 are: 1996 -- $770,000; 1997 -- $812,000; 1998 --
$824,000; 1999 -- $467,000; 2000 -- $400,000; and thereafter --
$460,000,000.
On June 29, 1995 $5,000,000 of Senior Debt Securities at $993 per
$1,000 note were repurchased and on June 30, 1995 $10,000,000 at
$995 per $1,000 note were repurchased with proceeds from the Pre-
ferred Securities. Subsequent to year-end, an additional
$20,000,000 of Senior Debt Securities were repurchased at prices
ranging from $963 to $985 per $1,000 note. No significant gains
or losses were recognized on these transactions.
On January 31, 1994, Southern Union completed the sale of the
Senior Debt Securities. The net proceeds from the sale of the
Senior Debt Securities, together with the net proceeds from the
Rights Offering and working capital from operations, were used
to: (i) fund the Missouri Acquisition; (ii) repay approximately
$59,300,000 of borrowings under the $100,000,000 revolving credit
facility used to fund the Rio Grande Acquisition and repurchase
all outstanding Preferred Stock; (iii) refinance, on January 31,
1994, $10,000,000 aggregate principal amount of 9.45% notes due
January 31, 2004 and $25,000,000 aggregate principal amount of
10% notes due January 31, 2012 and the related premium of
approximately $10,400,000 resulting from the early extinguishment
of such notes; (iv) refinance, on March 2,1994, $50,000,000
aggregate principal amount of 10.5% Sinking Fund Debentures due
May 15, 2017 and the related premiums of approximately $3,300,000
resulting from the early extinguishment of such debentures; and
(v) refinance, on May 16, 1994, $20,000,000 aggregate principal
amount of 10-1/8% notes.
The Senior Debt Securities traded at approximately $995 and $993
(per $1,000 note) on June 30 and September 22, 1995, respec-
tively, as quoted by a major brokerage firm. The carrying amount
of long-term debt at June 30, 1995 and 1994 was $463,273,000 and
$479,937,000, respectively. The fair value of long-term debt at
June 30, 1995 and 1994 was $460,973,000 and $419,137,000,
respectively.
Notes Payable
The Company has availability under a $100,000,000 revolving
credit facility with a three-year term (the "facility") under-
written by Texas Commerce Bank, N.A. and syndicated to four addi-
tional banks. Borrowings under the facility are available for
Southern Union's working capital, letter of credit requirements
and other general corporate purposes. On April 28, 1995,
Southern Union entered into an amendment to the facility. The
amended facility eliminates certain covenants, is uncol-
lateralized and has no borrowing base limitations as long as the
Company's Senior Debt Securities meet certain rating criteria.
The Company may use up to $40,000,000 of this facility to finance
future acquisitions. This facility contains covenants with
respect to financial parameters and ratios, total debt limita-
tions, restrictions as to dividend payments, stock reacquisi-
tions, certain investments and additional liens. The facility
expires on December 31, 1997 but may be extended annually for
periods of one year beginning on September 30, 1994 with the con-
sent of each of the banks. The revolving credit facility is sub-
ject to a commitment fee based on the rating of the Company's
Senior Debt Securities. As of June 30, 1995 the commitment fee
was an annualized .1875% on
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
the unused balance. The interest rate on borrowings on the
revolving credit facility is calculated based on a formula using
the LIBOR and prime interest rates. The average interest rate
under the revolving credit facility was 6.5% and 5.1% for the
year ended June 30, 1995 and 1994, respectively. No balance was
outstanding under the facility as of June 30, 1995 and 1994.
EMPLOYEE BENEFITS
Defined Benefit Plan
The Company maintains two trusteed non-contributory defined bene-
fit retirement plans which cover substantially all employees.
Benefits are based on years of service and the employee's compen-
sation during the last ten years of employment. Plan A covers
those Company employees who are not employed by Missouri Gas
Energy and Plan B covers those employees who are employed by
Missouri Gas Energy. The Company funds the plans' cost in
accordance with federal regulations, not to exceed the amounts
deductible for income tax purposes. The plans' assets are
invested in cash, bond and stock funds.
The components of net pension expense of Plan A for the years
ended June 30, 1995 and 1994 and December 31, 1993 consisted of
the following:
1995 1994 1993
-------- -------- --------
Service cost of benefits earned
during the year.................. $ 1,220 $ 1,233 $ 1,067
Interest cost on projected
benefit obligations.............. 2,394 2,269 2,358
Actual return on plan assets....... (2,768) 14 (1,099)
Net amortization and deferral...... 949 (1,633) (632)
------- ------- -------
Net pension expense................ $ 1,795 $ 1,883 $ 1,694
======= ======= =======
Plan B did not exist prior to January 31, 1994. The components
of net pension expense of Plan B for the year ended June 30, 1995
and five-month period ended June 30, 1994 consisted of the
following:
Five Months
Year Ended Ended
June 30, 1995 June 30, 1994
------------- -------------
Service cost of benefits
earned during the year........... $ 1,125 $ 550
Interest cost on projected
benefit obligations.............. 7,289 2,957
Actual return on plan assets....... (10,318) 3,303
Net amortization and deferral...... 3,363 (6,464)
-------- -------
Net pension expense................ $ 1,459 $ 346
======== =======
With respect to Plan A, the actuarial computations for the deter-
mination of accumulated and projected benefit obligations, at
June 30, 1995, using the projected unit credit actuarial cost
method, assumed a discount rate of 7.5% and a weighted average
annual salary increase of 5.62% over the average remaining ser-
vice lives of employees. A discount rate of 8.25% and 7.5% and a
weighted average annual salary increase of 5.8% were assumed as
of June 30, 1994 and December 31, 1993, respectively. An
expected long-term rate of return on plan assets of 8% was
assumed in all periods presented. The discount rate assumption
as of June 30, 1995 and 1994 and the salary increase assumption
as of June 30, 1994 for Plan B were identical to Plan A. A
weighted average annual salary increase of 5.8% was assumed for
Plan B as of June 30, 1995.
As a result of decreasing the discount rate effective January 1,
1994, from 9% to 7.5%, the provisions of SFAS No. 87, Employers
----------
Accounting for Pensions required the recognition in the balance
- -----------------------
sheet of an additional minimum liability representing the excess
of accumulated benefits over plan assets. A corresponding amount
was recognized
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
as an intangible asset to the extent of any unrecognized prior
service cost and any remainder as a reduction of stockholders'
equity. Accordingly, at December 31, 1993, the Company recorded
a liability of $4,917,000, an intangible asset of $1,809,000 and
a reduction in stockholders' equity of $2,051,000, net of an
income tax benefit of $1,057,000. These amounts were subse-
quently reversed during the last quarter of the fiscal year ended
June 30, 1994 as a result of increasing the discount rate,
effective July 1, 1994, from 7.5% to 8.25%.
The following is a reconciliation of the funded status of the
pension plans and accrued retirement plan liabilities as of
June 30, 1995 and 1994:
Plan A Plan B
------------------ ------------------
June 30, June 30, June 30, June 30,
1995 1994 1995 1994
-------- -------- -------- --------
Actuarial present
value of benefit
obligations:
Vested benefits..... $ 25,893 $ 21,521 $ 87,542 $ 82,876
Nonvested benefits.. 1,107 983 2,138 1,262
-------- -------- -------- --------
Accumulated benefit
obligations........... 27,000 22,504 89,680 84,138
Effect of future salary
increases............. 7,731 5,262 5,203 6,235
-------- -------- -------- --------
Projected benefit
obligation............ 34,731 27,766 94,883 90,373
Plan assets at fair
value................. (26,624) (23,364) (92,884) (90,285)
-------- -------- -------- --------
Projected benefit
obligations in
excess of plan
assets................ 8,107 4,402 1,999 88
Unrecognized net
transition asset...... 621 719 -- --
Unrecognized prior
service cost.......... (1,796) (1,733) -- --
Unrecognized net gain
(loss)................ (4,838) (1,249) (1,808) 258
-------- -------- -------- --------
Accrued retirement
plan liabilities...... $ 2,094 $ 2,139 $ 191 $ 346
======== ======== ======== ========
Prior service cost is being amortized on a straight-line basis
over the average remaining expected future service of partici-
pants present at the time of amendment.
During the six-month period ended June 30, 1994, the Company
recorded an accrual and associated increase in the additional
purchase cost assigned to utility plant of approximately
$11,200,000 reflecting employee severance and other special early
termination benefit costs associated with an early retirement
program for employees of Missouri Gas Energy. As of June 30,
1995 the accrued balance was $9,905,000. Of an eligible 133
employees, 81 accepted the 1994 early retirement program. In
addition, during 1993, the Company completed an early retirement
program for certain of the Company's employees. Of an eligible
109 employees, 75 accepted the 1993 early retirement program
which resulted in the Company recognizing expenses of approxi-
mately $702,000 associated with special termination benefits.
The Company also maintains a supplemental non-contributory
defined benefit retirement plan which covers certain employees
whose annual earnings exceed $50,000. The purpose of the supple-
mental plan is to provide part or all of those defined benefit
plan benefits which are not payable to certain employees under
the primary plan. The net pension cost of the supplemental plan
for the years ended June 30, 1995 and 1994 and December 31, 1993
was not significant.
Pursuant to the terms of an Employee Agreement with the seller of
Missouri Gas Energy, Southern Union employed certain employees of
the seller involved in the operation of the Missouri business
("Continuing Employees") after the closing of the Missouri
Acquisition. Under the terms of the Employee Agreement, the
assets and liabilities under the seller's qualified defined bene-
fit plans attributable to Continuing Employees and retired
Missouri employees ("Retired Employees") were transferred to a
separate qualified defined benefit plan of Southern Union that
will provide benefits to Continuing Employees and Retired
Employees substantially similar to those provided for under the
seller's qualified defined benefit plans (referred to as Plan B
above). Southern Union amended its qualified defined benefit
plan to create a separate plan to cover the Continuing Employees
and Retired Employees and provide Continuing
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Employees and Retired Employees with certain other benefits. In
addition, pursuant to the MPSC Stipulation, the Company is
required to contribute approximately $3,000,000 to the Company's
employee's qualified defined benefits plan applicable to Missouri
Gas Energy's employees and retirees earlier than what would be
required under the Internal Revenue Code, Section 412, as deter-
mined by the plan's actuaries. As of June 30, 1995 the Company
has contributed approximately $1,600,000 of such amount.
Defined Contribution Plan
The Company provides a Savings Plan available to all employees.
Under the provisions of the plan, the Company contributes $.50
for each $1.00 contributed by a participant up to 7% of the
employees' salary. Company contributions are 100% vested after
six years of continuous service. Company contributions to the
plan during 1995, 1994 and 1993, were approximately $1,344,000,
$859,000 and $374,000, respectively. The increase in contribu-
tions in 1995 and 1994 is mainly attributable to the Missouri
Acquisition whose employees were allowed to participate effective
February 1, 1994.
Postretirement Benefits Other than Pensions
The Company, excluding Missouri Gas Energy, adopted the provision
of SFAS No. 106, Employers' Accounting for Postretirement Bene-
----------------------------------------------
fits Other Than Pensions, effective as of January 1, 1993 which
- ------------------------
resulted in a transition obligation of approximately $9,328,000
which was subsequently reduced primarily as a result of certain
plan amendments during 1993. The balance at June 30, 1995 and
1994 was $3,860,000 and $4,084,000, respectively. The Company,
excluding Missouri Gas Energy, amortizes the remaining transition
obligation over an allowed 20-year period. SFAS No. 106 requires
an accrual of postretirement medical and other benefit
liabilities on an actuarial basis during the years an employee
provides services. The Company, excluding Missouri Gas Energy,
records a regulatory asset for the difference between the
postretirement cost currently included in rates and the SFAS No.
106 expense to the extent the Company, excluding Missouri Gas
Energy, has filed, or intends to file, a rate application to
include SFAS No. 106 expense in rates and it is probable that the
regulator will allow such expense in future rates. The total
postretirement costs deferred and recorded as a regulatory asset
by the Company, excluding Missouri Gas Energy, at both June 30,
1995 and 1994 were approximately $18,000.
The seller of Missouri Gas Energy adopted the provisions of SFAS
No. 106 as of January 1, 1993. To mitigate the impact of SFAS
No. 106 expense, the seller filed an application with the MPSC,
which was approved, for an order permitting the deferral of SFAS
No. 106 expense and proposed inclusion in rates collected in the
future of the actual SFAS No. 106 expense and an income stream
generated from a COLI. To the extent SFAS No. 106 expense
exceeds income from the COLI program, this excess would be
deferred (as allowed by the FASB Emerging Issues Task Force Issue
No. 92-12) and offset by income generated through the deferral
period by the COLI program. Missouri Gas Energy has recorded a
regulatory asset and related liability of approximately
$41,200,000 and $38,300,000 representing the accumulated benefit
obligation at June 30, 1995 and 1994, respectively. Addi-
tionally, the State of Missouri recently passed legislation which
provides for prospective recognition by the MPSC of postretire-
ment medical and benefit costs on an accrual basis. Thus, to the
extent that Missouri Gas Energy's COLI does not offset its SFAS
106 liability such expenses should be recoverable in future
rates.
The significant features of the substantive plan include the
payment for life of a portion of the medical benefit costs for
individuals (and their dependents) who are: (i) employees or
retirees of Missouri Gas Energy; (ii) non-Missouri Gas Energy
retirees who retired prior to January 1, 1993; and (iii) non-
Missouri Gas Energy employees (and their dependents) who elected
to retire during the first quarter of 1993. For active non-
Missouri Gas Energy employees hired prior to January 1, 1993,
benefits are provided only to retirees and only until eligibility
for Medicare (age 65). The cost-sharing provisions for medical
care benefits include an escalation in the non-Missouri Gas
Energy retirees' share of claims obligations that is expected to
follow the trend of claims net of Medicare reimbursements. The
non-Missouri Gas Energy employees substantive plan was amended
during 1993 to substantially modify the cost-sharing provisions
to decrease the employer's share of expected future claims and
make certain other plan changes. The
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
substantive plan for Missouri Gas Energy employees and retirees
provides payment of a portion of the medical benefit costs for
individuals and their dependents. The cost sharing provisions
include an escalation in the Missouri Gas Energy retirees share
of claims that is expected to follow the trend of claims net of
Medicare, subject to an overall limit on employer expenditures.
The funding policy for the non-Missouri Gas Energy plan is to pay
claims as they arise from a tax-exempt trust through 1999. In
addition, contributions are currently being made to a separate
account within the pension plan to accumulate assets sufficient
to fund claims arising after 1999. The funding policy for the
Missouri Gas Energy plan is to pay claims as they arise through a
tax exempt trust. Assets held in the tax-exempt trust include
primarily short-term obligations. Assets held in the separate
account within the retirement plan include cash, bond and stock
funds. Non-benefit liabilities are limited to expenses asso-
ciated with plan operation and administration.
The components of net postretirement benefit cost consisted of
the following:
Non-Missouri Gas Energy
---------------------------------------
Year Ended June 30, Year Ended
-------------------
1995 1994 December 31, 1993
-------- -------- -----------------
Service cost of
benefits earned
during the year....... $ 22 $ 32 $ 36
Interest cost on
benefit obligations... 227 378 609
Actual return on plan
assets................ (21) (11) (4)
Amortization of transi-
tion obligation....... 224 224 349
----- ------ ------
Net postretirement
benefit cost.......... 452 623 990
Regulatory deferrals.... -- -- (501)
----- ------ ------
Net expense............. $ 452 $ 623 $ 489
===== ====== ======
Missouri Gas Energy
--------------------------------
Year Ended Five Months Ended
June 30, 1995 June 30, 1994
------------- -----------------
Service cost of benefits
earned during the period
ended........................ $ 281 $ 127
Interest cost on benefit
obligations.................. 3,162 1,251
Net amortization and deferral.. -- 892
------- -------
Net postretirement benefit
cost......................... 3,443 2,270
Regulatory deferrals........... (1,319) (1,815)
------- -------
Net expense.................... $ 2,124 $ 455
======= =======
The following is a reconciliation of the funded status of the
Company's postretirement benefit plans and accrued postretirement
liabilities as of June 30, 1995 and 1994.
June 30,
------------------
1995 1994
-------- --------
Accumulated postretirement benefit
obligation:
Retirees................................ $37,211 $37,121
Other fully eligible participants....... 1,249 1,243
Other active participants............... 5,475 4,403
------- -------
Accumulated benefit obligation.............. 43,935 42,767
Plan assets at fair value................... (305) (272)
------- -------
Accumulated benefit obligations in excess
of plan assets............................ 43,630 42,495
Unrecognized net transition obligation...... (3,860) (4,084)
Unrecognized net gain....................... 3,833 3,807
------- -------
Accrued postretirement benefit cost......... $43,603 $42,218
======= =======
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
For purposes of computing the 1995 and 1994 net periodic cost,
the assumed health care cost trend rate used to measure expected
cost benefits covered by the plan was 10% per year for seven
years, gradually decreasing thereafter to 7% in year 18 of the
projection. For purposes of the June 30, 1995 benefit obliga-
tions, the health care cost trend rate was 8% for the first year
and 10% for year two through five, thereafter decreasing by .25%
per year, reaching 7% in year 18 of the projection. For pur-
poses of the June 30, 1994 benefit obligations, the health care
cost trend rate was 10% for the first seven years of the projec-
tion, thereafter decreasing by .25% per year, reaching 7% in year
18 of the projection.
The weighted average assumed discount rate was 8.25% for purposes
of the year ended June 30, 1995 net periodic cost. The weighted
average assumed discount rate was 7.5% for purposes of the six-
month period ended June 30, 1994 net periodic cost and the
December 31, 1993 computation of the accumulated postretirement
benefit obligation. The weighted average assumed discount rate
was 7.5% and 8.25% for purposes of the 1996 and 1995 net periodic
costs, respectively. The June 30, 1995 and 1994 weighted average
assumed discount rate was 7.5% and 8.25%, respectively, for the
accumulated postretirement benefit obligation. The weighted
average expected long-term rate of return on plan assets was
assumed to be 8% on an after tax basis. In addition, prior ser-
vice cost is amortized on a straight-line basis over the average
remaining years of service to full eligibility for benefits of
the active plan participants.
A one percentage point increase in the assumed health care cost
trend rates for each future year would increase the aggregate of
the service and interest cost components of the net periodic
postretirement health care benefit cost by approximately $276,000
and would increase the accumulated postretirement benefit obliga-
tion for health care benefits by approximately $3,025,000.
Postemployment Benefits
The Company adopted the provisions of SFAS No. 112, Employers'
----------
Accounting for Postemployment Benefits, as of January 1, 1994.
- --------------------------------------
This statement requires that the cost of benefits, such as dis-
ability and health care continuation coverage provided to former
or inactive employees after employment but before retirement, be
accrued if attributable to an employee's previously rendered
service. The Company had previously recognized such
postemployment benefit costs when paid and was allowed recovery
in rates as payments were incurred. Consequently, the Company
has recorded a regulatory asset to the extent it intends to file
rate applications to include such costs in rates and such
recovery is probable. As of both June 30, 1995 and 1994, the
adoption of SFAS No. 112 has resulted in the recognition of a
regulatory asset and a related liability of approximately
$1,100,000.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
TAXES ON INCOME
The components of taxes on income relating to continuing
operations were as follows:
Year Ended June 30, 1995
------------------------------
Current Deferred
Tax Tax Total
------- -------- -------
Federal.......................... $ 4,694 $ 5,218 $ 9,912
State............................ 371 691 1,062
------- ------- -------
$ 5,065 $ 5,909 $10,974
======= ======= =======
Year Ended June 30, 1994
------------------------------
Current Deferred
Tax Tax Total
------- -------- -------
Federal.......................... $(3,592) $ 8,389 $ 4,797
State............................ (166) 554 388
------- ------- -------
$(3,758) $ 8,943 $ 5,185
======= ======= =======
Year Ended December 31, 1993
------------------------------
Current Deferred
Tax Tax Total
------- -------- -------
Federal.......................... $ 2,417 $ 1,368 $ 3,785
State............................ 70 -- 70
------- ------- -------
$ 2,487 $ 1,368 $ 3,855
======= ======= =======
Deferred credits and other liabilities also include $701,000 and
$737,000 of unamortized deferred investment tax credit as of
June 30, 1995 and 1994, respectively.
Deferred income taxes result from temporary differences between
the financial statement carrying amounts and the tax basis of
existing assets and liabilities. The source of these differences
and the tax effect of each is as follows:
June 30, December 31,
----------------------
1995 1994 1993
---------- ---------- ------------
Deferred tax assets:
Postretirement benefits.. $ 791 $ 464 $ 1,513
Note receivable.......... -- -- 921
Bad debt reserves........ 713 450 --
Estimated alternative
minimum tax credit..... 2,044 -- --
Insurance accruals....... 558 1,071 540
Other.................... 555 360 571
-------- -------- --------
Total deferred tax
assets................. 4,661 2,345 3,545
-------- -------- --------
Deferred tax liabilities:
Property, plant and
equipment.............. (31,234) (23,175) (21,004)
Unamortized debt expense. (6,333) (6,505) (1,372)
Other.................... (2,263) (1,889) (559)
-------- -------- --------
Total deferred tax
liabilities............ (39,830) (31,569) (22,935)
-------- -------- --------
Net deferred tax liability. (35,169) (29,224) (19,390)
Less current tax asset..... 887 488 219
-------- -------- --------
Accumulated deferred
income taxes............. $(36,056) $(29,712) $(19,609)
======== ======== ========
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
On August 10, 1993, the United States Congress passed and the
President signed into law, the Omnibus Budget Reconciliation Act
of 1993 (the "Act"). Among other provisions in the Act, effec-
tive January 1, 1993, the corporate federal income tax rate was
increased to 35% on corporate taxable income in excess of
$10,000,000. Total income tax expense differed from the amount
computed by applying the applicable federal income tax rate of
35% in 1995, 1994 and 1993 to earnings before taxes on income as
follows:
Year Ended
---------------------------------
June 30, December 31,
------------------
1995 1994 1993
-------- -------- ------------
Computed "expected" tax
expense..................... $ 9,465 $ 4,747 $ 4,056
Changes in taxes resulting
from:
State income taxes,
net of federal income
tax benefit............. 690 254 46
Amortization of
acquisition adjustment.. 920 941 1,060
Amortization of excess
deferred income taxes... (175) (190) (191)
Adjustments to tax
reserve................. -- (615) (1,095)
Other..................... 74 48 (21)
------- ------- --------
Actual tax expense............ $10,974 $ 5,185 $ 3,855
======= ======= ========
UTILITY REGULATION AND RATES
Pursuant to a 1989 MPSC order, Missouri Gas Energy is engaged in
a major gas safety program in its service territories. This pro-
gram includes replacement of company- and customer-owned gas ser-
vice and yard lines, the movement and resetting of meters, the
replacement of cast iron mains and the replacement and cathodic
protection of bare steel mains (the "Missouri Safety Program").
In recognition of the significant capital expenditures associated
with this safety program, the MPSC permits the deferral, and sub-
sequent recovery through rates, of depreciation expense, property
taxes and associated carrying costs, related to the Missouri
Safety Program. Missouri Gas Energy was required to continue the
Missouri Safety Program and has deferred depreciation expense,
property taxes and carrying costs of approximately $4,154,000 and
$600,000 for 1995 and 1994, respectively.
The continuation of the Missouri Safety Program will result in
significant levels of future capital expenditures. The Company
estimates incurring capital expenditures of approximately
$20,021,000 in fiscal 1996 related to this program.
Under the order of the FERC docket Nos. RP 94-296 and PR 95-3,
Williams Natural Gas Company, a supplier of gas to Missouri Gas
Energy, is allowed recovery of certain unrecovered deferred gas
costs of approximately $27,700,000. These costs were related to
gas deliveries prior to April 30, 1994. Missouri Gas Energy
filed a mechanism to recover these costs under case GR 95-33
with the MPSC which was approved and allows recovery of these
costs from its Missouri customers. The receivable and
liability associated with these costs have been recorded as a
deferred charge and a deferred liability, respectively, on the
balance sheet as of June 30, 1995.
LEASES
The Company leases certain facilities, equipment and office space
under cancelable and noncancelable operating leases. The minimum
annual rentals under operating leases for the next five years
ended June 30 are as follows: 1996 -- $6,147,000; 1997 --
$5,030,000; 1998 -- $3,499,000; 1999 -- $2,613,000; 2000 --
$2,051,000; and thereafter $10,215,000. Rental expense was
approximately $7,268,000, $3,605,000 and $2,061,000 for the years
ended June 30, 1995 and 1994 and December 31, 1993.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
COMMITMENTS AND CONTINGENCIES
Southern Union is aware of the possibility that it may become a
defendant in an action brought by the United States Environmental
Protection Agency ("EPA") under 42 U.S.C. Section 9607(a) for
reimbursement of costs associated with removing hazardous sub-
stances from the site of a former coal gasification plant (the
"Pine Street Canal Site") in Burlington, Vermont. This knowledge
arises out of the existence of a prior action, United States v.
----------------
Green Mountain Power Corp., et al, Civil No. 88-307 (D. Vt.), in
- ---------------------------------
which Southern Union became involved as a third-party defendant
in January 1989. Green Mountain Power was an action under 42
U.S.C. Section 9607(a) by the federal government to recover
clean-up costs associated with the "Maltex Pond", which is part
of the Pine Street Canal Site. Two defendants in Green Mountain
Power, Vermont Gas Systems and Green Mountain Power Corp.,
claimed that Southern Union is the corporate successor to
People's Light and Power Corporation, an upstream corporate
parent of Green Mountain Power Corp. during the years 1928-1931.
Green Mountain Power was settled without admission or determina-
tion of liability with respect to Southern Union by order dated
December 26, 1990. The EPA has since conducted studies of the
clean-up costs for the remainder of the Pine Street Canal Site,
but the ultimate costs are unknown at this time. On November 30,
1992, Southern Union was named as a potentially responsible party
in a special notice letter from the EPA. The Company has denied
liability for any clean-up costs for various reasons, including
the fact that it is not a successor to any entity that owned or
operated the site in question. Should Southern Union be made
party to any action seeking recovery of remaining clean-up costs,
the Company intends to vigorously defend against such an action.
The Company has made demands of the appropriate insurers that
they assume the defense of and liability for any such claim that
may be asserted. The Company does not believe the outcome of
this matter will have a material adverse effect on its financial
position, results of operations or cash flows.
Southern Union and Western Resources entered into an Environ-
mental Liability Agreement (the "Environmental Liability Agree-
ment") at the closing of the Missouri Acquisition. Subject to
the accuracy of certain representations made by Western Resources
in the Missouri Asset Purchase Agreement, the Environmental
Liability Agreement provides for a tiered approach to the alloca-
tion of certain liabilities under environmental laws that may
exist or arise with respect to Missouri Gas Energy. The
Environmental Liability Agreement contemplates Southern Union
first seeking reimbursement from other potentially responsible
parties, or recovery of such costs under insurance or through
rates charged to customers. To the extent certain environmental
liabilities are discovered by Southern Union prior to January 31,
1996, and are not so reimbursed or recovered, Southern Union will
be responsible for the first $3,000,000, if any, of out-of-pocket
costs and expenses incurred to respond to and remediate any such
environmental claim. Thereafter, Western Resources would share
one-half of the next $15,000,000 of any such costs and expenses,
and Southern Union would be solely liable for any such costs and
expenses in excess of $18,000,000. Missouri Gas Energy owns or
is otherwise associated with a number of sites where manufactured
gas plants were previously operated. These plants were commonly
used to supply gas service in the late 19th and early 20th cen
turies, in certain cases by corporate predecessors to Western
Resources. By-products and residues from manufactured gas could
be located at these sites and at some time in the future may
require remediation by the EPA or delegated state regulatory
authority. By virtue of notice under the Missouri Asset Purchase
Agreement and its preliminary, non-invasive review, the Company
became aware prior to closing of eleven such sites in the service
territory of Missouri Gas Energy. Based on information reviewed
thus far, it appears that neither Western Resources nor any
predecessor in interest ever owned or operated at least three of
those sites. Subsequent to the closing of the Missouri Acquisi-
tion, as a result of an environmental audit, the Company has
discovered the existence of possibly six additional sites in the
service territory of Missouri Gas Energy. Southern Union has so
informed Western Resources. The Company does not know if any of
these additional sites were ever owned or operated by Western
Resources or any of its predecessors in interest. Western
Resources has informed the Company that it was notified in 1991
by the EPA that it was evaluating one of the sites (in St.
Joseph, Missouri) for any potential threat to human health and
the environment. Western Resources has also advised the Company,
as of September 15, 1994, the EPA had not notified it that any
further action may be required. Evaluation of the remainder of
the sites by appropriate federal and state regulatory authorities
may occur in the future. At the present time and based upon
information available to management, the Company believes that
the costs of any remediation efforts that may be required for
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
these sites for which it may ultimately have responsibility will
not exceed the aggregate amount subject to substantial sharing by
Western Resources.
On June 1, 1994 Southern Union filed two lawsuits in the United
States District Court for the Western District of Missouri, one
against The Bishop Group, Ltd. and related entities ("The Bishop
Group"), the other against both The Bishop Group and Western
Resources. The primary subject of the lawsuits were certain gas
transportation and supply agreements for the Missouri properties.
Disputed purchase price items under the Missouri Asset Purchase
Agreement (the "Purchase Agreement") were also made part of the
litigation with Western Resources. The Bishop Group had
responded with claims for damages and alleged a preliminary com-
putation of damages in the range of $196,000,000 to $270,000,000
against Southern Union and Western. The litigation against The
Bishop Group was dismissed February 24, 1995 as a result of a
settlement between The Bishop Group and Southern Union with no
material adverse affect on the Company's financial position,
results of operations or cash flows. The issues involving
disputed purchase price items in the litigation against Western
Resources were resolved by court-ordered arbitration. Pursuant
to the arbitrator's decision on April 17, 1995, Southern Union
made an additional payment of $3,300,000 plus interest in final
payment of the purchase price. The only remaining issues in the
litigation are the Company's claims for damages against Western
Resources for fraudulent misrepresentation, breach of contract,
breach of covenant and other grounds. Southern Union is seeking
damages in excess of $50,000,000. Trial by jury is currently
scheduled for November 1995.
Southern Union and its subsidiaries are parties to other legal
proceedings that its management considers to be the normal kinds
of actions to which an enterprise of its size and nature might be
subject, and not to be material to the Company's overall business
or financial condition, results of operations or cash flows.
In the Missouri Acquisition, the Company assumed the Missouri
portion of certain obligations related to a 1990 settlement of a
Wyoming Tight Sands anti-trust claim. To secure the refund of
the settlement proceeds, the MPSC authorized the establishment of
an independently administered trust to collect cash receipts
under the Tight Sands settlement and repay credit-facility bor-
rowings used for the lump sum payment. In the event the trust
does not receive cash payments from the gas suppliers as provided
by the Tight Sands settlement agreements, the Company is com-
mitted to pay its applicable portion of the amount owed the
lender of the credit-facility borrowings. The Company's allo-
cable unpaid portion of the amount the trust owes the lender at
June 30, 1995 was approximately $8,204,000.
The Company is committed under various agreements to purchase
certain quantities of gas in the future. At June 30, 1995, the
Company has purchase commitments for nominal quantities of gas at
fixed prices. These fixed price commitments have an annual value
of approximately $2,500,000 for Southern Union Gas. Missouri Gas
Energy currently does not have any fixed price commitment con-
tracts for the 1995/1996 winter heating season. At June 30,
1995, the Company also has purchase commitments for certain
quantities of gas at variable, market-based prices. These
market-based priced commitments have an annual value of approxi-
mately $37,000,000 for Southern Union Gas and $66,000,000 for
Missouri Gas Energy. The Company's purchase commitments may
extend over a period of several years depending upon when the
required quantity is purchased. The Company has in place pur-
chase gas tariffs on file in all jurisdictions that provide for
full recovery of its purchase costs.
The Company had standby letters of credit outstanding of
$2,947,000 and $4,947,000 at June 30, 1995 and 1994, respec-
tively, which guarantee payment of various insurance premiums,
state taxes and gas purchases.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
TRANSITION PERIOD INFORMATION
The Company's Statement of Consolidated Operations for the six-
month periods ended June 30, 1994 and 1993 appear below.
STATEMENT OF CONSOLIDATED OPERATIONS
Six Months Ended June 30,
-------------------------
1994(a) 1993
------------- ----------
(unaudited)
(thousands of dollars,
except shares and per
share amounts)
Operating revenues................... $ 268,964 $ 104,236
Gas purchase costs................... 154,274 53,530
--------- ---------
Operating margin................... 114,690 50,706
--------- ---------
Operating expenses:
Operating, maintenance and general. 53,383 23,793
Taxes, other than on income........ 22,811 7,405
Depreciation and amortization...... 14,284 6,782
--------- --------
Total operating expenses......... 90,478 37,980
--------- --------
Net operating revenues........... 24,212 12,726
--------- --------
Other income (expenses):
Interest on long-term debt......... (17,836) (5,803)
Other, net......................... 1,774 (748)
--------- --------
Total other expenses, net........ (16,062) (6,551)
--------- --------
Income before income taxes........... 8,150 6,175
Federal and state income taxes....... 3,259 1,929
--------- --------
Earnings before preferred dividends.. 4,891 4,246
Preferred dividends.................. -- (843)
--------- --------
Net earnings available for common
stock.............................. $ 4,891 $ 3,403
========= ========
Earnings (loss) per common share..... $ .43 $ .41
========= ========
Weighted average shares
outstanding........................ 11,438,396 8,253,052
========== =========
- --------------------------
(a) Missouri Gas Energy was acquired on January 31, 1994 and Rio
Grande was acquired on September 30, 1993. Accordingly, the
operating results of Missouri Gas Energy and Rio Grande were
included in the Company's consolidated results of operations
subsequent to the dates of acquisition.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The Company's Condensed Statements of Consolidated Cash Flows for
the six-month periods ended June 30, 1994 and 1993 appear below.
CONDENSED STATEMENT OF CONSOLIDATED CASH FLOWS
Six Months Ended June 30,
-------------------------
1994(a) 1993
------------- ----------
(unaudited)
(thousands of dollars)
Net cash flows from operating
activities....................... $ 101,177 $ 17,090
--------- --------
Cash flows from investing
activities:
Additions to property, plant
and equipment................ (28,133) (6,424)
Acquisition of operations,
net of cash received......... (405,292) (274)
Purchase of and improvements
to real estate............... -- (906)
Proceeds from sale of
discontinued operation....... -- 16,273
Other, net..................... 6,215 (1,261)
--------- --------
Net cash flows (used in)
provided by investing
activities................. (427,210) 7,408
--------- --------
Cash flows from financing
activities:
Repayment of debt.............. (106,846) (478)
Issuance of debt............... 475,000 14,489
Premiums on early extinguish-
ment of debt................. (13,715) --
Debt issuance costs............ (5,439) --
Net payments under revolving
credit facility.............. (20,100) --
Exercise of common stock
options....................... 96 167
Redemption of preferred stock.. -- (25,370)
Payment of dividends on
preferred stock.............. -- (843)
Other, net..................... -- (374)
--------- --------
Net cash flows from (used
in) financing activities... 328,996 (12,409)
--------- --------
Increase in cash and cash
equivalents...................... 2,963 12,089
Cash and cash equivalents at
beginning of period.............. 2,918 89
--------- --------
Cash and cash equivalents at end
of period........................ $ 5,881 $ 12,178
========= ========
- --------------------------
(a) Missouri Gas Energy was acquired on January 31, 1994 and Rio
Grande was acquired on September 30, 1993. Accordingly, the
operating results of Missouri Gas Energy and Rio Grande were
included in the Company's consolidated results of operations
subsequent to the dates of acquisition.
SOUTHERN UNION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
QUARTERLY OPERATIONS (UNAUDITED)
Year Ended Quarter Ended
-----------------------------------------
June 30, 1995 September 30 December 31 March 31 June 30 Total
- ------------- ------------ ----------- -------- ------- --------
Total
operating
revenues.... $69,114 $145,497 $181,370 $84,065 $480,046
Operating
margin...... 40,289 67,863 81,621 48,434 238,207
Net operating
revenues.... (956) 19,460 34,562 9,050 62,116
Net earnings
(loss)
available
for common
stock....... (6,168) 6,558 16,153 (474) 16,069
Net earnings
(loss) per
common
share....... (.54) .57 1.41 (.04) 1.40
Year Ended Quarter Ended
--------------------------------------------
June 30,
1994(1) September 30 December 31 March 31(2) June 30 Total
- ---------- ------------ ----------- ----------- ------- --------
Total
operating
revenues... $31,087 $ 74,465 $175,454 $93,510 $374,516
Operating
margin..... 16,751 31,947 67,695 46,996 163,389
Net operating
revenues... (625) 8,445 23,477 736 32,033
Net earnings
(loss)
available
for common
stock...... (1,254) 4,742 9,954 (5,064) 8,378
Net earnings
(loss) per
common
share....... (.15) .57 .87 (.44) .85
Year Ended Quarter Ended
-----------------------------------------
December 31,
1993 March 31 June 30 September 30 December 31 Total
- ------------ -------- ------- ------------ ----------- --------
Total
operating
revenues.... $67,026 $36,427 $ 31,087 $ 74,465 $209,005
Operating
margin...... 31,095 18,828 16,751 31,947 98,621
Net operating
revenues.... 11,252 692 (625) 8,445 19,764
Earnings
(loss)
before
preferred
dividends... 5,169 (924) (1,254) 4,742 7,733
Net earnings
(loss)
available
for common
stock....... 4,575 (1,173) (1,254) 4,742 6,890
Net earnings
(loss) per
common
share....... .55 (.14) (.15) .57 .83
- ---------------------------
(1) On May 25, 1994, the Company's Board of Directors approved
a change in the Company's fiscal year-end from December 31
to June 30. See Change in Fiscal Year.
(2) Missouri Gas Energy was purchased effective January 31,
1994. See Acquisitions and Divestitures.
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the
Securities Exchange Act of 1934, Southern Union has duly caused
this report to be signed by the undersigned, thereunto duly
authorized, on September 20, 1995.
SOUTHERN UNION COMPANY
By PETER H. KELLEY
------------------------
Peter H. Kelley
President and Chief
Operating Officer
Pursuant to the requirements of the Securities Exchange Act of
1934, this report has been signed by the following persons on
behalf of Southern Union and in the capacities indicated as of
September 20, 1995.
Signature/Name Title
-------------- -----
GEORGE L. LINDEMANN* Chairman of the Board, Chief Executive
Officer and Director
JOHN E. BRENNAN* Director
FRANK W. DENIUS* Director
AARON I. FLEISCHMAN* Director
KURT A. GITTER, M.D.* Director
PETER H. KELLEY Director
- ---------------
Peter H. Kelley
ADAM M. LINDEMANN* Director
ROGER J. PEARSON* Director
GEORGE ROUNTREE, III* Director
DAN K. WASSONG* Director
RONALD J. ENDRES Senior Vice President - Administration
- ----------------
Ronald J. Endres and Chief Financial Officer
DAVID J. KVAPIL Vice President and Controller
- ---------------
David J. Kvapil (Principal Accounting Officer)
*By PETER H. KELLEY
------------------
Peter H. Kelley
Attorney-in-fact
<PAGE>
EXHIBIT INDEX
Exhibit Filed
No. Description Herein
- ------- -------------------------------------------------- ------
3(a) Restated Certificate of Incorporation of Southern
Union Company. (Filed as Exhibit 3(a) to Southern
Union's Transition Report on Form 10-K for the
year ended June 30, 1994 and incorporated herein
by reference.)
3(b) Southern Union Company Bylaws, as amended. (Filed
as Exhibit 3(b) to Southern Union's Transition
Report on Form 10-K for the year ended June 30,
1994 and incorporated herein by reference.)
4(a) Specimen Common Stock Certificate. (Filed as
Exhibit 4(a) to Southern Union's Annual Report on
Form 10-K for the year ended December 31, 1989
and incorporated herein by reference.)
4(b) Indenture between Chase Manhattan Bank, N.A., as
trustee, and Southern Union Company dated
January 31, 1994. (Filed as Exhibit 4.1 to
Southern Union's Current Report on Form 8-K dated
February 15, 1994 and incorporated herein by
reference.)
4(c) Officers' Certificate dated January 31, 1994
setting forth the terms of the 7.60% Senior Debt
Securities due 2024. (Filed as Exhibit 4.2 to
Southern Union's Current Report on Form 8-K dated
February 15, 1994 and incorporated herein by
reference.)
4(d) Certificate of Trust of Southern Union Financing I.
(Filed as Exhibit 4-A to Southern Union's Regis-
tration Statement on Form S-3 (No. 33-58297) and
incorporated herein by reference.)
4(e) Certificate of Trust of Southern Union Financing II.
(Filed as Exhibit 4-B to Southern Union's Regis-
tration Statement on Form S-3 (No. 33-58297) and
incorporated herein by reference.)
4(f) Certificate of Trust of Southern Union Financing
III. (Filed as Exhibit 4-C to Southern Union's
Registration Statement on Form S-3 (No. 33-58297)
and incorporated herein by reference.)
4(g) Form of Amended and Restated Declaration of Trust
of Southern Union Financing I. (Filed as Exhibit
4-D to Southern Union's Registration Statement on
Form S-3 (No. 33-58297) and incorporated herein by
reference.)
4(h) Form of Subordinated Debt Securities Indenture
among Southern Union Company and The Chase
Manhattan Bank, N. A., as Trustee. (Filed as
Exhibit 4-G to Southern Union's Registration State-
ment on Form S-3 (No. 33-58297) and incorporated
herein by reference.)
4(i) Form of Supplemental Indenture to Subordinated Debt
Securities Indenture with respect to the Subor-
dinated Debt Securities issued in connection with
the Southern Union Financing I Preferred Securities.
(Filed as Exhibit 4-H to Southern Union's Regis-
tration Statement on Form S-3 (No. 33-58297) and
incorporated herein by reference.)
4(j) Form of Southern Union Financing I Preferred
Security (included in 4(g) above.) (Filed as
Exhibit 4-I to Southern Union's Registration State-
ment on Form S-3 (No. 33-58297) and incorporated
herein by reference.)
4(k) Form of Subordinated Debt Security (included in 4(i)
above.) (Filed as Exhibit 4-J to Southern Union's
Registration Statement on Form S-3 (No. 33-58297)
and incorporated herein by reference.)
4(l) Form of Guarantee with respect to Southern Union
Financing I Preferred Securities. (Filed as Exhibit
4-K to Southern Union's Registration Statement on
Form S-3 (No. 33-58297) and incorporated herein by
reference.)
4(m) The Company is a party to other debt instruments,
none of which authorizes the issuance of debt
securities in an amount which exceeds 10% of the
total assets of the Company. The Company hereby
agrees to furnish a copy of any of these instru-
ments to the Commission upon request.
10(a) Revolving Credit Agreement, Revolving Note and Loan
Documents between Southern Union Company and the
Banks named therein dated September 30, 1993. (Filed
as Exhibit 99.2 to Southern Union's Current Report on
Form 8-K dated October 13, 1993 and incorporated
herein by reference.)
10(b) First Amendment to Revolving Credit Agreement,
Revolving Notes and Loan Documents dated as of
November 15, 1993. (Filed as Exhibit 10.1 to
Southern Union's Registration Statement on Form S-3
(No. 33-70604) and incorporated herein by reference.)
10(c) Second Amendment to Revolving Credit Agreement dated
August 31, 1994. (Filed as Exhibit 10(c) to Southern
Union's Transition Report on Form 10-K for the year
ended June 30, 1994 and incorporated herein by
reference.)
10(d) Third Amendment to Revolving Credit Agreement dated
April 28, 1995. (Filed as Exhibit 10.1 to Southern
Union's Quarterly Report on Form 10-Q for the quar-
ter ended March 31, 1995 and incorporated herein by
reference.)
10(e) Asset Purchase Agreement between Southern Union
Company and Western Resources, Inc. dated July 9,
1993. (Filed as Exhibit 10.1 to the Company's
Current Report on Form 8-K dated July 12, 1993 and
incorporated herein by reference.)
10(f) Southern Union Company 1982 Incentive Stock Option
Plan and form of related Stock Option Agreement.
(Filed as Exhibits 4.1 and 4.2 to Form S-8, File
No. 2-79612 and incorporated herein by reference.)
(1)
10(g) Form of Indemnification Agreement between Southern
Union Company and each of the Directors of Southern
Union Company. (Filed as Exhibit 10(i) to Southern
Union's Annual Report on Form 10-K for the year
ended December 31, 1986 and incorporated herein by
reference.)
10(h) Southern Union Company 1992 Long-Term Stock Incen-
tive Plan. (Filed as Exhibit 10(i) to Southern
Union's Annual Report on Form 10-K for the year
ended December 31, 1992 and incorporated herein by
reference.)(1)
10(i) Southern Union Company Director's Deferred Compen-
sation Plan. (Filed as Exhibit 10(g) to Southern
Union's Annual Report on Form 10-K for the year
ended December 31, 1993 and incorporated herein by
reference.)(1)
10(j) Southern Union Company Supplemental Deferred Compen-
sation Plan. (Filed as Exhibit 10(h) to Southern
Union's Annual Report on Form 10-K for the year
ended December 31, 1993 and incorporated herein by
reference.)(1)
10(k) Form of warrant granted to Fleischman and Walsh
L.L.P. (Filed as Exhibit 10(j) to Southern Union's
Transition Report on Form 10-K for the year ended
June 30, 1994 and incorporated herein by reference.)
10(l) Renewal Promissory Note Agreement between
Peter H. Kelley and Southern Union Company dated
May 31, 1995.
11 Computation of Per Share Earnings.
21 Subsidiaries of Southern Union Company.
23 Consent of Independent Accountants.
24 Power of Attorney with Respect to Certain Signatures.
27 Financial Data Schedule.
- ---------------------
(1) Indicates a Management Compensation Plan.
<PAGE>
EXHIBIT 10(l)
RENEWAL PROMISSORY NOTE AGREEMENT
<PAGE>
RENEWAL PROMISSORY NOTE AGREEMENT Exhibit 10(l)
This Agreement is made and entered into between Peter H. Kelley
("Mr. Kelley") and Southern Union Company (the "Company") this
31st day of May, 1995. Reference is made to that certain Renewal
Promissory Note of even date in the principal sum of Two Hundred
Ninety-One Thousand Six Hundred Seventy-Three and 40/100 Dollars
($291,673.40) made by Mr. Kelley to the Company (the "Note").
For valuable consideration, receipt of which is acknowledged,
Mr. Kelley and the Company agree that notwithstanding anything to
the contrary contained in the Note, the Note shall be immediately
canceled and any amount of principal or interest then due or
accrued but unpaid shall be deemed paid in full or otherwise
forgiven, with no further obligation or liability hereunder upon
Mr. Kelley, upon either of the following:
1) Mr. Kelley ceasing to be an employee of Southern Union
Company or its successor-in-interest (if not as a result of
a "Change in Control" as defined below) or suffering any
diminution in base compensation or capacity of employment as
such an employee, for any reason whatsoever other than his
voluntary resignation, retirement or his removal due to
fraud, misappropriation or embezzlement; or
2) A Change in Control, which shall mean the occurrence of any
of the following events: (i) there shall be consummated (x)
any consolidation, merger, tender offer for, or exchange of
securities of the Company in which the Company is not the
continuing or surviving corporation or pursuant to which
shares of the Company's Common Stock would be converted into
cash, securities of another entity or other property, other
than such a transaction in which the holders of the Com-
pany's Common Stock immediately prior to such transaction
have the same proportionate equity ownership of the sur-
viving entity immediately thereafter, or in which a majority
of the individuals constituting the Board of Directors of
the surviving entity were directors of the Company immedi-
ately preceding the transaction, or (y) any sale, lease,
exchange or other transfer (in one transaction or a series
of related transactions) of all, or substantially all, of
the assets of the Company, (ii) the stockholders of the Com-
pany approve any plan or proposal for the liquidation or
dissolution of the Company, (iii) any group (as such term is
used in Rule 13d-5 under the Securities Exchange Act of
1934, as amended) shall hereafter become the beneficial
owner (within the meaning of Rule 13d-3 under that Act) of
20% or more of the Company's outstanding Common Stock, or
(iv) during any period of two consecutive years, individuals
who at the beginning of such period constituted the entire
Board of Directors cease for any reason to constitute a
majority of the directors unless the election, or the
nomination for election by the Company's stockholders, of
each new director was approved by a vote of at least two-
thirds of the directors then still in office who were
directors at the beginning of the period.
IN WITNESS WHEREOF, the parties have executed this Agreement the
day and year first above written.
PETER H. KELLEY RONALD J. ENDRES
- ---------------------------- -----------------------------
Peter H. Kelley Southern Union Company
By: Ronald J. Endres
Senior Vice President and
Chief Financial Officer
<PAGE>
EXHIBIT 11
COMPUTATION OF PER SHARE EARNINGS
COMPUTATION OF PER SHARE EARNINGS Exhibit 11
Years Ended
--------------------------------
June 30, December 31,
------------------
1995 1994 1993
-------- -------- ------------
(thousands of dollars,
except per share amounts)
Net earnings available for
common stock................. $16,069 $ 8,378 $ 6,890
======= ======= =======
Primary earnings per share:
Average shares outstanding
at year end................ 11,479 9,866 8,286
Stock options issued or
granted.................... 255 269 183
------- ------- -------
Average shares outstanding... 11,734 10,135 8,469
======= ======= =======
Primary earnings per share... $ 1.37 $ 0.83 $ 0.81
======= ======= =======
Fully diluted earnings per
share:
Average shares out-
standing at year end..... 11,479 9,866 8,286
Stock options issued or
granted.................. 271 269 264
------- ------- -------
Average shares outstanding. 11,750 10,135 8,550
======= ======= =======
Fully diluted earnings
per share................ $ 1.37 $ 0.83 $ 0.81
======= ======= =======
- ----------------------
Note: All periods have been adjusted for the 5% stock dividend
distributed on June 30, 1994 and the three-for-two stock
split distributed in the form of a 50% stock dividend on
March 9, 1994.
<PAGE>
EXHIBIT 21
SUBSIDIARIES OF SOUTHERN UNION COMPANY
SUBSIDIARIES OF SOUTHERN UNION COMPANY Exhibit 21
Name State of Incorporation
- --------------------------------------- ----------------------
KellAir Aviation Company Delaware
Lavaca Realty Company Delaware
Mercado Gas Services Inc. Delaware
Southern Union Econofuel Company Delaware
Southern Union Energy International, Inc. Delaware
Southern Union Energy Products and
Services Company Delaware
Southern Union Financing I Delaware
Southern Union Financing II Delaware
Southern Union Financing III Delaware
Southern Transmission Company Delaware
Western Gas Interstate Company Delaware
- ---------------------------
Note: Two other wholly-owned subsidiaries of Southern Union
Company, Southern Union Gas Company, Inc. (a Delaware
corporation) and Southern Union Gas Company, Inc. (a
Texas corporation), conduct no business except to the
extent necessary to hold the Corporate name.
<PAGE>
EXHIBIT 23
CONSENT OF INDEPENDENT ACCOUNTANTS
CONSENT OF INDEPENDENT ACCOUNTANTS Exhibit 23
We consent to the incorporation by reference in the registration
statements of Southern Union Company and Subsidiaries (the
"Company") on Form S-3 (File No. 33-58297) and Form S-8 (File
Nos. 2-79612, 33-37261, 33-61558, 33-69596 and 33-69598) of our
report, which includes an explanatory paragraph concerning the
Company's change in accounting method for postemployment bene-
fits, dated September 5, 1995 on our audits of the consolidated
financial statements of the Company as of June 30, 1995 and 1994,
and for the years ended June 30, 1995 and 1994 and December 31,
1993, which report is included in this Annual Report on Form
10-K.
COOPERS & LYBRAND L.L.P.
Austin, Texas
September 25, 1995
<PAGE>
EXHIBIT 24
POWER OF ATTORNEY WITH RESPECT TO CERTAIN SIGNATURES
POWER OF ATTORNEY Exhibit 24
KNOW ALL PERSONS BY THESE PRESENTS that each person whose
signature appears below constitutes and appoints Peter H. Kelley,
Ronald J. Endres and David J. Kvapil, or any of them, as such
person's true and lawful attorney-in-fact and agent, with full
power of substitution and revocation, for such person and in such
person's name, place and stead, in any and all capacities, to
sign the Annual Report on Form 10-K for the fiscal year ended
June 30, 1995 of Southern Union Company, a Delaware corporation,
and any amendments thereto, and to file the same with all
exhibits thereto, and other documents in connection therewith,
with the Securities and Exchange Commission and the New York
Stock Exchange.
Dated: September 20, 1995
JOHN E. BRENNAN GEORGE L. LINDEMANN
- ----------------------------- -------------------------------
John E. Brennan George L. Lindemann
FRANK W. DENIUS ROGER J. PEARSON
- ----------------------------- -------------------------------
Frank W. Denius Roger J. Pearson
AARON I. FLEISCHMAN GEORGE ROUNTREE, III
- ----------------------------- -------------------------------
Aaron I. Fleischman George Rountree, III
ADAM M. LINDEMANN DAN K. WASSONG
- ----------------------------- -------------------------------
Adam M. Lindemann Dan K. Wassong
KURT A. GITTER, M.D.
- -----------------------------
Kurt A. Gitter
<TABLE> <S> <C>
<ARTICLE> UT
<FISCAL-YEAR-END> JUN-30-1995
<PERIOD-END> JUN-30-1995
<PERIOD-TYPE> YEAR
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> $ 748,646,000
<OTHER-PROPERTY-AND-INVEST> $ 10,742,000
<TOTAL-CURRENT-ASSETS> $ 126,613,000
<TOTAL-DEFERRED-CHARGES> $ 114,167,000
<OTHER-ASSETS> $ 2,334,000
<TOTAL-ASSETS> $1,002,502,000
<COMMON> $ 11,570,000
<CAPITAL-SURPLUS-PAID-IN> $ 198,819,000
<RETAINED-EARNINGS> $ 16,069,000
<TOTAL-COMMON-STOCKHOLDERS-EQ> $ 225,664,000
$ 0
$ 100,000,000
<LONG-TERM-DEBT-NET> $ 462,503,000
<SHORT-TERM-NOTES> $ 0
<LONG-TERM-NOTES-PAYABLE> $ 0
<COMMERCIAL-PAPER-OBLIGATIONS> $ 0
<LONG-TERM-DEBT-CURRENT-PORT> $ 770,000
$ 0
<CAPITAL-LEASE-OBLIGATIONS> $ 0
<LEASES-CURRENT> $ 0
<OTHER-ITEMS-CAPITAL-AND-LIAB> $ 213,565,000
<TOT-CAPITALIZATION-AND-LIAB> $1,002,502,000
<GROSS-OPERATING-REVENUE> $ 480,046,000
<INCOME-TAX-EXPENSE> $ 10,974,000
<OTHER-OPERATING-EXPENSES> $ 104,072,000
<TOTAL-OPERATING-EXPENSES> $ 176,091,000
<OPERATING-INCOME-LOSS> $ 62,116,000
<OTHER-INCOME-NET> $ 5,970,000
<INCOME-BEFORE-INTEREST-EXPEN> $ 55,953,000
<TOTAL-INTEREST-EXPENSE> $ 39,884,000
<NET-INCOME> $ 16,069,000
$ 1,159,000
<EARNINGS-AVAILABLE-FOR-COMM> $ 16,069,000
<COMMON-STOCK-DIVIDENDS> $ 0
<TOTAL-INTEREST-ON-BONDS> $ 0
<CASH-FLOW-OPERATIONS> $ 41,642,000
<EPS-PRIMARY> $ 1.37
<EPS-DILUTED> $ 1.37
</TABLE>
