SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-K
X ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 1996
OR
_____ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ______________ to ___________
Commission Registrant; IRS Employer
State of Incorporation;
File Number Address and Telephone No. Identification No.
1-11603 SIGCORP, Inc. 35-1940620
(An Indiana Corporation)
20 N. W. Fourth Street
Evansville, Indiana 47741-0001
(812) 465-5300
1-3553 Southern Indiana Gas and
Electric Company 35-0672570
(An Indiana Corporation)
20 N. W. Fourth Street
Evansville, Indiana 47741-0001
(812) 465-5300
Securities registered pursuant to Section 12(b) of the Act:
<TABLE>
<CAPTION> Name of each exchange
Registrant Title of each class on which registered
<S> <C> <C>
SIGCORP, Inc. Common Stock, Without Par Value New York Stock Exchange
Rights to Purchase Common Stock New York Stock Exchange
Southern Indiana Gas None
and Electric Company
</TABLE>
Securities registered pursuant to Section 12(g) of the Act:
<TABLE>
<CAPTION>
Name of each exchange
Registrant Title of each class on which registered
<S> <C> <C>
SIGCORP, Inc. None
Southern Indiana
Gas and Electric Cumulative Preferred Stock, New York Stock Exchange
Company $100 Par Value
</TABLE>
Indicate by check mark if disclosure of delinquent filers
pursuant to Item 405 of Regulation S-K is not contained
herein, and will not be contained, to the best of
registrants' 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
Indicate by check mark whether all Registrants (1) have
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
registrants were required to file such reports), and (2)
have been subject to such filing requirements for the past
90 days: Yes X No
At February 28, 1997, the aggregate market values of
SIGCORP, Inc. Common Stock, Without Par Value, and Southern
Indiana Gas and Electric Company Cumulative Preferred Stock,
$100 Par Value, 185,895 shares, held by non-affiliates were
$551,418,910 and $15,432,859, respectively.
As of February 28, 1997, the number of shares outstanding of
each of the Registrants' classes of common stock were:
SIGCORP, Inc.: Common stock, no par value,
15,754,826 shares
Southern Indiana Gas
and Electric Company: Common stock, no par value,
15,754,826 shares outstanding
and held by SIGCORP, Inc.
Documents Incorporated by Reference
The Joint Proxy Statement of SIGCORP, Inc. and Southern
Indiana Gas and Electric Company dated March 21, 1997 is
incorporated by reference into Part III of this report.
This combined Form 10-K is separately filed by SIGCORP, Inc.
and Southern Indiana Gas and Electric Company.
<PAGE> 3
<TABLE>
<CAPTION>
Table of Contents
Item Page
Number Number
Part I
<S> <C> <C>
1 Business 4
2 Properties 14
3 Legal Proceedings 15
4 Submission of Matters to Vote of Security Holders 15
Part II
5 Market for Registrant's Common Equity
and Related Security Holder Matters 16
6 Selected Financial Data 17
7 Management's Discussion and Analysis
of Results of Operations and Financial Condition 18
8 Financial Statements and Supplementary Data 24
9 Disagreements on Accounting and Financial
Disclosure 56
Part III
10 Directors and Executive Officers of
the Registrants 56
11 Executive Compensation and Transactions 56
12 Security Ownership of Certain Beneficial
Owners and Management 57
13 Certain Relationships and Related
Transactions 57
Part IV
14 Exhibits, Financial Statement Schedules and
Reports on Form 8-K 57
15 Subsidiaries of the Registrant 63
16 Signatures 64
</TABLE>
<PAGE> 4
PART I
Item 1. BUSINESS
SIGCORP and SIGECO
ORGANIZATION
SIGCORP, Inc. (SIGCORP) is a holding company
incorporated October 19, 1994 under the laws of the State of
Indiana. SIGCORP has nine wholly-owned subsidiaries:
Southern Indiana Gas and Electric Company (SIGECO), a gas
and electric utility, and eight nonregulated subsidiaries.
On December 20, 1994, SIGECO's Board of Directors
authorized the steps required for a corporate reorganization
in which a holding company would become the parent of
SIGECO. SIGECO's shareholders approved the reorganization
at SIGECO's March 28, 1995 annual meeting, and approval by
the Federal Energy Regulatory Commission and the Securities
and Exchange Commission was granted November 7, 1995 and
December 14, 1995, respectively.
Effective January 1, 1996, the new holding company,
SIGCORP, became the parent of SIGECO, which accounts for
over 90% of SIGCORP's net income, and four of SIGECO's
former wholly-owned nonregulated subsidiaries: Energy
Systems Group, Inc., Southern Indiana Minerals, Inc.,
Southern Indiana Properties, Inc. and ComSource, Inc.
Because of the significance of SIGECO, the operating results
of all nonregulated subsidiaries are included in Other
Income in the consolidated financial statements of SIGCORP.
All of the shares of SIGECO's common stock were exchanged on
a one-for-one basis for shares of SIGCORP, while all of
SIGECO's debt securities and all of its outstanding shares
of preferred stock remain securities of SIGECO and are
unaffected. (See "Nonregulated Subsidiaries - General" and
Note 1 of the Notes To Consolidated Financial Statements,
page 40, for further discussion.)
The reorganization is in response to the changes
created in the electric industry by the Energy Policy Act of
1992 and the need to respond quickly to the more competitive
business environment. The new structure will buffer SIGECO
and its customers from the effects of pursuing nonregulated
opportunities while allowing SIGCORP to engage in closely
related, but historically nonregulated, businesses.
Providing gas and electric utility service to customers
through SIGECO will remain the core business and primary
focus of SIGCORP.
SIGECO - GENERAL
SIGECO is an operating public utility incorporated
June 10, 1912, under the laws of the State of Indiana,
engaged in the generation, transmission, distribution and
sale of electric energy and the purchase of natural gas and
its transportation, distribution and sale in a service area
which covers ten counties in southwestern Indiana.
Electric service is supplied directly to Evansville
and 74 other cities, towns and communities, and adjacent
rural areas. Wholesale electric service is supplied to an
additional eight communities. At December 31, 1996, SIGECO
served 122,195 electric customers and was also obligated to
provide for firm power commitments to the City of Jasper,
Indiana and to maintain spinning reserve margin requirements
under an agreement with the East Central Area Reliability
Group (ECAR).
At December 31, 1996, SIGECO supplied gas service to
106,237 customers in Evansville and 64 other nearby
communities and their environs. Since 1986, SIGECO has
purchased its natural gas supply requirements from numerous
suppliers. During 1996, thirty-one suppliers were used.
Until November 1993, Texas Gas Transmission Corporation
(TGTC) was SIGECO's primary contract supplier. In November
1993, TGTC restructured its services so that its gas
supplies are sold separately from its interstate
transportation services. SIGECO assumed full responsibility
for the purchase of all its natural gas supplies. (See Note
2 of the Notes to Consolidated Financial Statements, page
46, for a discussion of the restructuring of interstate
pipelines.)
<PAGE> 5
The principal industries served by SIGECO include
polycarbonate resin (Lexan) and plastic products, aluminum
smelting and recycling, aluminum sheet products, appliance
manufacturing, pharmaceutical and nutritional products,
automotive glass, gasoline and oil products and coal mining.
The only property SIGECO owns outside of Indiana is
approximately eight miles of 138,000 volt electric
transmission line which is located in Kentucky and which
interconnects with Louisville Gas and Electric Company's
transmission system at Cloverport, Kentucky. The original
cost of the property is less than $425,000. SIGECO does not
distribute any electric energy in Kentucky.
SIGECO - LINES OF BUSINESS
The percentages of operating revenues and operating
income before income taxes attributable to the electric and
gas operations of SIGECO for the five years ended December
31, 1996, were as follows:
<TABLE>
<CAPTION>
Year Ended December 31,
1992 1993 1994 1995 1996
<S> <C> <C> <C> <C> <C>
Operating Revenues:
Electric 79.2% 78.4% 79.1% 81.3% 74.2%
Gas 20.8 21.6 20.9 18.7 25.8
Operating Income Before Income Taxes:
Electric 99.0% 99.5% 90.9% 96.4% 89.0%
Gas 1.0 0.5 9.1 3.6 11.0
</TABLE>
Reference is made to Note 10 of the Notes to
Consolidated Financial Statements, page 53, for Segments of
Business data.
SIGECO - ELECTRIC BUSINESS
SIGECO supplies electric service to 122,195 customers,
including 106,605 residential, 15,391 commercial, 176
industrial, 19 public street and highway lighting, and four
municipal customers.
SIGECO's installed generating capacity as of December
31, 1996 was rated at 1,236,000 kilowatts (Kw). Coal-fired
generating units provide 1,021,000 Kw of capacity and gas or
oil-fired turbines used for peaking or emergency conditions
provide 215,000 Kw.
In addition, SIGECO has interconnections with
Louisville Gas and Electric Company, Cinergy Services, Inc.,
Indianapolis Power & Light Company, Hoosier Energy Rural
Electric Cooperative, Inc., Big Rivers Electric
Corporation, Wabash Valley Power Association, and the City
of Jasper, providing an ability to simultaneously
interchange approximately 750,000 Kw.
Record-breaking peak conditions occurred on August 17,
1995, when SIGECO's system summer peak load reached
1,021,000 Kw. The 1996 system peak load of 999,800 Kw was
2% lower than the 1995 peak. SIGECO's total load,
<PAGE> 6
including its firm power commitments to the City of Jasper,
Indiana, for each of the years 1992 through 1996 at the time
of the system summer peak, and the related reserve margin,
are presented below.
<TABLE>
<CAPTION>
<S> <C> <C> <C> <C> <C>
Date of Summer
Peak Load 7-13-92 7-28-93 7-20-94 8-17-95 8-21-96
Company System
Peak Load (Kw) 916,700 1,012,700 992,000 1,021,000 999,800
Firm Power
Commitments at
Peak 46,300 55,300 42,000 60,800 53,500
Total at Peak 963,000 1,068,000 1,034,000 1,081,800 1,053,300
Total Generating
Capability (Kw) 1,238,000 1,238,000 1,238,000 1,236,000 1,236,000
Reserve Margin
at Peak 29% 16% 20% 14% 17%
</TABLE>
An all-time record winter peak load of 783,700 Kw
occurred during the 1995-1996 season on February 2, 1996,
and was 1.5% greater than the previous winter peak of
772,000 Kw reached on January 19, 1994.
SIGECO, primarily as agent of Alcoa Generating
Corporation (AGC), operates the Warrick Generating Station,
a coal-fired steam electric plant which interconnects with
SIGECO's system and provides power for the Aluminum Company
of America's Warrick Operations, which includes aluminum
smelting and fabricating facilities. Of the four turbine
generators at the plant, Warrick Units 1, 2 and 3, with a
capacity of 144,000 Kw each, are owned by AGC. Warrick Unit
4, with a rated capacity of 270,000 Kw, is owned by SIGECO
and AGC as tenants in common, each having shared equally in
the cost of construction and sharing equally in the cost of
operation and in the output.
SIGECO (a summer peaking utility) has an agreement with
Hoosier Energy Rural Electric Cooperative, Inc. (Hoosier
Energy) for the sale of firm peaking power to Hoosier Energy
during the annual winter heating season (November 15-March
15). The contract made available 200 Mw during the 1996-
1997 winter season, and allows for a possible increase to
250 Mw by November 15, 1998. The contract will terminate
March 15, 2000.
Electric generation for 1996 was fueled by coal (99.6%)
and natural gas (0.4%). Oil was used only for testing of
gas/oil fired peaking units.
Historically, coal for SIGECO's Culley Generating
Station and Warrick Unit 4 has been purchased from operators
of nearby Indiana strip mines pursuant to long-term
contracts. During 1991, SIGECO pursued negotiations for new
contracts with these mine operators and while doing so,
purchased coal from the respective operators under interim
agreements. In October 1992, SIGECO finalized a new supply
agreement effective through 1995 and retroactive to 1991,
with one of the operators under which coal is supplied to
both locations. Included in the agreement was a provision
whereby the contract could be reopened by SIGECO for
modification of certain coal specifications. In early 1993,
SIGECO reopened the contract for such modifications.
Effective July 1, 1993, SIGECO bought out the remainder of
its contractual obligations with the supplier, enabling
SIGECO to acquire lower-priced spot market coal. SIGECO
estimates the savings in coal costs during the 1991-1995
period, net of the total buy out costs, approximate $59
million. The net savings were passed back to SIGECO's
electric customers through the fuel adjustment clause. The
coal supplier retained the right of first refusal to supply
Warrick Unit 4 and the Culley plant during the years 1996-
2000. The coal used in these plants is blended, when
necessary, to meet specifications set in conformance with
the requirements of the Indiana State Implementation Plan
for sulfur dioxide issued under Federal laws regulating air
quality (Clean Air Act). Approximately 1,620,000 tons of
coal were used during 1996 in the generation of electricity
at the Culley Station and Warrick Unit 4. Culley Units 2
and 3 were recently equipped with flue gas desulfurization
equipment as part of the Clean Air Act Compliance Plan.
(See "Environmental Matters", page 11, for further
discussion.) SIGECO's remaining long-term contract coal
supplier supplied the A. B. Brown Generating Station. On
April 10, 1995, SIGECO reached an agreement with this coal
supplier, effective July 16, 1995, to buy out the remainder
of SIGECO's contractual obligations, enabling it to acquire
lower-priced spot market coal for all coal-fired generation.
SIGECO estimates the total savings in coal costs resulting
from the buyout, net of total buyout costs, will approximate
$58 million through December 31, 1998, the term of the
original contract. The net savings from this coal contract
renegotiation are also being passed back to SIGECO's
electric customers through the fuel adjustment clause. The
amount of coal burned at A. B. Brown Generating Station
during 1996 was approximately 1,149,000 tons. Both units at
the generating station are equipped with flue gas
<PAGE> 7
desulfurization equipment so that coal with a higher sulfur
content can be used. There are substantial coal reserves in
the southern Indiana area. The average cost (including
contract buyout costs) of coal consumed in generating
electrical energy for the years 1992 through 1996 was as
follows:
<TABLE>
<CAPTION>
Average Cost
Average Cost Average Cost Per Kwh
Year Per Ton Per MMBTU (In Mills)
<S> <C> <C> <C> <C>
1992 $32.04 $1.42 15.30
1993 32.56 1.46 15.66
1994 31.86 1.42 14.91
1995 30.02 1.33 14.10
1996 26.01 1.16 12.40
</TABLE>
The Broadway Turbine Units 1 and 2, Northeast Gas
Turbines and A. B. Brown Gas Turbine, when used for peaking,
reserve or emergency purposes, use natural gas for fuel.
Number 2 fuel oil can also be used in the Broadway Turbine
Units and the Brown Gas Turbine.
All metered electric rates contain a provision for
adjustment in charges for electric energy to reflect changes
in the cost of fuel and the net energy cost of purchased
power through the operation of a fuel adjustment clause
unless certain criteria contained in the regulations are not
met. Effective April 26, 1995, the principal restriction to
recovery of fuel cost increases is that such recovery is not
allowed to the extent that total operating income for the
60-month period including the twelve-month period provided
in the fuel cost adjustment filing exceeds the total
operating income authorized by the Indiana Utility
Regulatory Commission (IURC) during the same 60-month
period. Prior to April 26, 1995, the operating income test
period was the twelve-month period provided in the fuel cost
adjustment filing. During 1994-1996, neither restriction
affected SIGECO. As prescribed by order of the IURC, the
adjustment factor is calculated based on the estimated cost
of fuel and the net energy cost of purchased power in a
designated future quarter. The order also provides that any
over- or underrecovery caused by variances between estimated
and actual cost in a given quarter will be included in the
second succeeding quarter's adjustment factor. This
continuous reconciliation of estimated incremental fuel
costs billed with actual incremental fuel costs incurred
closely matches revenues to expenses.
See "Rate and Regulatory Matters" in Item 7,
MANAGEMENT'S DISCUSSION AND ANALYSIS OF RESULTS OF
OPERATIONS AND FINANCIAL CONDITION, page 20, and Note 2 of
the Notes to Consolidated Financial Statements, page 46, for
discussion of SIGECO's general adjustments in electric
rates.
SIGECO participates in research and development in
which the primary goal is cost savings through the use of
new technologies. This is accomplished, in part, through
the efforts of the Electric Power Research Institute (EPRI).
In 1996,
SIGECO paid $1,004,000 to EPRI to help fund research and
development programs such as advanced clean coal burning
technology.
SIGECO is participating with 14 other electric utility
companies through Ohio Valley Electric Corporation (OVEC) in
arrangements with the United States Department of Energy
(DOE), to supply the power requirements of the DOE plant
near Portsmouth, Ohio. The sponsoring companies are
entitled to receive from OVEC, and are obligated to pay for,
any available power in excess of the DOE contract demand.
The proceeds from the sale of power by OVEC are designed to
be sufficient to meet all of its costs and to provide for a
return on its common stock. During 1996, SIGECO's
participation in the OVEC arrangements was 1.5%.
SIGECO participates with 32 other utilities and other
affiliated groups located in eight states comprising the
east central area of the United States, in the East Central
Area Reliability group, the purpose of which is to
strengthen the area's electric power supply reliability.
<PAGE> 8
SIGECO - GAS BUSINESS
SIGECO supplies natural gas service to 106,237
customers, including 96,741 residential, 9,274 commercial
and 222 industrial customers, through 2,799 miles of gas
transmission and distribution lines.
SIGECO owns and operates three underground gas storage
fields with an estimated ready delivery from storage of 3.9
million Dth of gas. Natural gas purchased from SIGECO's
suppliers is injected into these storage fields during
periods of light demand which are typically periods of lower
prices. The injected gas is then available to supplement
the contracted volumes during periods of peak requirements.
It is estimated that approximately 119,000 Dth of gas per
day can be withdrawn from the three storage fields during
peak demand periods on the system.
The gas procurement practices of SIGECO and several of
its major customers have been altered significantly during
the past ten years as a result of changes in the natural gas
industry. In 1985 and prior years, SIGECO purchased nearly
its entire gas requirements from TGTC compared to 1996 when
a total of 31 suppliers sold gas to SIGECO. In total,
SIGECO purchased 19,375,378 Dth in 1996. In November 1993,
TGTC restructured its services so that its gas supplies are
sold separately from its interstate transportation services,
and SIGECO assumed full responsibility for the purchase of
all its natural gas supplies. (See subsequent reference in
this section to the restructuring of interstate pipelines.)
During 1996, twenty-seven of SIGECO's major gas customers
took advantage utilized SIGECO's gas transportation program
to procure a portion of their gas supply needs from
suppliers other than SIGECO. A total of 11,801,376 Dth, 38%
of total gas throughput, was transported for these major
customers in 1996 compared to 12,083,838 Dth transported in
1995. SIGECO receives fees for the use of its facilities in
transporting such gas.
See "Rate and Regulatory Matters" in Item 7,
MANAGEMENT'S DISCUSSION AND ANALYSIS OF RESULTS OF
OPERATIONS AND FINANCIAL CONDITION, page 20, for discussion
of SIGECO's general adjustment in gas rates, and refer to
Note 2 of the Notes to Consolidated Financial Statements,
page 46, for discussion of FERC Order No. 636, which
required interstate pipelines to restructure their services
so that gas supplies are sold separately from interstate
transportation services.
The all-time record send out occurred during the 1993-
1994 winter season on January 18, 1994, when 247,449 Dth of
gas were delivered to SIGECO's customers. Of this amount,
97,946 Dth was purchased, 106,558 Dth was taken out of
SIGECO's three underground storage fields, and 42,945 Dth
was transported to customers under transportation
agreements. The 1995-1996 winter season peak day send out
was 230,505 Dth on February 2, 1996.
The average cost per Dth of gas purchased by SIGECO
during the past five calendar years was as follows: 1992,
$2.77; 1993, $2.85; 1994, $2.54, 1995, $2.48; and 1996,
$3.47.
The State of Indiana has established procedures which
result in SIGECO passing on to its customers the changes in
the cost of gas sold unless certain criteria contained in
the regulations are not met. Effective April 26, 1995, the
principal restriction to recovery of gas cost increases is
that such recovery is not allowed to the extent that total
operating income for the 60-month period including the
twelve-month period provided in the gas cost adjustment
filing exceeds the total operating income authorized by the
IURC during the same 60-month period. Prior to April 26,
1995, the operating income test period was the twelve-month
period provided in the gas cost adjustment filing. During
1994-1996, neither restriction affected SIGECO.
Additionally, these procedures provide for scheduled
quarterly filings and IURC hearings to establish the amount
of price adjustments for a designated future quarter. The
procedures also provide for inclusion in a later quarter of
any variances between estimated and actual costs of gas sold
in a given quarter. This reconciliation process with regard
to changes in the cost of gas sold closely matches revenues
to expenses. SIGECO's rate structure does not include a
weather normalization-type clause whereby a utility would be
authorized to recover the gross margin on sales established
in its last general rate case, regardless of actual weather
patterns.
<PAGE> 9
Natural gas research is supported by SIGECO through the
Gas Research Institute in cooperation with the American Gas
Association. Since passage of the Natural Gas Act of 1978,
a major effort has gone into promoting gas exploration by
both conventional and unconventional sources. Efforts
continue through various projects to extract gas from tight
gas sands, shale and coal. Research is also directed toward
the areas of conservation, safety and the environment.
On December 23, 1993, SIGECO entered into a definitive
agreement to acquire Lincoln Natural Gas Company, Inc.
(LNG), a small gas distribution company serving
approximately 1,400 customers contiguous to the eastern
boundary of SIGECO's gas service territory. On June 30,
1994, SIGECO completed its acquisition of LNG after
receiving the necessary regulatory and shareholder
approvals, and in July 1996, merged LNG into SIGECO. The
applicable financial data in this filing has been restated
to reflect this acquisition.
SIGCORP
NONREGULATED SUBSIDIARIES - GENERAL
In addition to its wholly-owned utility subsidiary,
SIGECO, SIGCORP has eight wholly-owned nonutility
subsidiaries, of which six were active by December 1996.
Southern Indiana Properties, Inc., formed in 1986, invests
principally in partnerships (primarily real estate),
leveraged leases and marketable securities. Energy Systems
Group, Inc., incorporated in April 1994, provides equipment
and related design services to industrial and commercial
customers. Southern Indiana Minerals, Inc., incorporated in
May 1994, processes and markets coal combustion by-products.
ComSource, Inc., incorporated in June 1995, markets
telecommunications services. SIGCORP Energy Services, Inc.,
incorporated in October 1996, provides natural gas, pipeline
management, storage service and other natural gas-related
services to SIGECO and other customers. SIGCORP Capital,
Inc., also incorporated in October 1996, will be the primary
financing vehicle for SIGCORP's nonregulated subsidiaries.
SIGCORP Fuels, Inc., incorporated in December 1996, was
formed to provide coal supply procurement and related
services, such as transportation of coal, to SIGECO and
other customers. SIGCORP Power Marketing, Inc., also
incorporated in December 1996, was formed to procure
electric power supplies for SIGECO and other customers, and
will market SIGECO's excess electric generation capacity.
SIGCORP and SIGECO
PERSONNEL
The holding company, SIGCORP, had no employees as of
December 31, 1996.
SIGECO's network of gas and electric operations
directly involves 785 employees with an additional 166
employed at Alcoa's Warrick Power Plant. Alcoa reimburses
SIGECO for the entire cost of the payroll and associated
benefits at the Warrick Plant, with the exception of one-
half of the payroll costs and benefits allocated to Warrick
Unit 4, which is jointly owned by SIGECO and Alcoa. The
total payroll and benefits for SIGECO employees in 1996
(including all Warrick Plant employees) were $53.4 million.
In 1995, total payroll and benefits were $50.7 million.
On July 1, 1994, SIGECO signed a new four-year contract
with Local 702 of the International Brotherhood of
Electrical Workers. The contract provides for annual wage
increases of 3.5%, 3.5%, 3.75% and 4.0%. Improvements in
productivity, work practices and the pension plan are also
included, along with initiatives to increase
labor/management cooperation. Additionally, SIGECO's
Hoosier Division signed a five-year labor contract with
Local 135 of the Teamsters, Chauffeurs, Warehousemen and
Helpers. The contract provides for annual wage increases of
3.5%, 3.5%, 3.75%, 4.0% and 4.0%. Also included are
improvements in health care coverage costs and pension
benefits.
<PAGE> 10
As of December 31, 1996, Southern Indiana Properties,
Inc. had 2 employees; Energy Systems Group, Inc. had 19
employees; Southern Indiana Minerals, Inc. had 9 employees;
ComSource, Inc. had 13 employees; and SIGCORP Energy
Services, Inc. had 3 employees. SIGCORP Capital, Inc.,
SIGCORP Power, Inc. and SIGCORP Fuels, Inc. had no
employees as of December 31, 1996. There were no labor
organizations representing employees of the nonregulated
entities.
CONSTRUCTION PROGRAM AND FINANCING
SIGCORP's demand for capital is primarily related to
SIGECO's construction of utility plant and equipment
necessary to meet customers' electric and gas energy needs,
as well as environmental compliance requirements. See
"Liquidity and Capital Resources" in Item 7, MANAGEMENT'S
DISCUSSION AND ANALYSIS OF RESULTS OF OPERATIONS AND
FINANCIAL CONDITION, page 22, for discussion of construction
expenditures and financing during 1996.
For 1997, SIGECO's construction expenditures are
presently estimated to be $55.6 million, which includes $1.8
million for demand side management (DSM) programs.
Expenditures in the power production area are expected to
total $11.2 million. The balance of the 1997 construction
program consists of $21.5 million for additions and
improvements to other electric system facilities, $10.5
million for additions and improvements to the gas system,
and $10.6 million for several strategic information systems
and for common utility plant buildings and equipment.
In keeping with SIGECO's objective to bring new
facilities on line as needed, the construction program and
amount of scheduled expenditures are reviewed periodically
to factor in load growth projections, system planning
requirements, environmental compliance and other
considerations. As a result of this program of periodic
review, construction expenditures may change in the future
from the program as presented herein.
Currently it is estimated that SIGECO's construction
expenditures will total about $260 million, including
allowance for funds used during construction, for the years
1997-2001 as follows: 1997 - $55 million; 1998 - $66
million; 1999 - $46 million; 2000 - $44 million and 2001 -
$49 million. This construction program reflects
approximately $25 million for the design and implementation
of several comprehensive information systems initiated in
1996 and $9 million for DSM programs. While SIGCORP expects
the majority of SIGECO's construction requirements to be
provided by internally generated funds, external financing
requirements of $60-70 million are anticipated and will be
used primarily to redeem an estimated $57 million of the
total $69.8 million of SIGCORP long-term debt redemptions
anticipated during the five year period.
REGULATION
Because of its ownership of SIGECO, SIGCORP is a
"Holding Company" as defined by the Public Utility Holding
Company Act of 1935 (PUHCA). Furthermore, SIGECO is also a
"Holding Company" as defined by PUHCA due to SIGECO's
ownership of 33% of Community Natural Gas Company. Both
SIGCORP and SIGECO are exempt from regulation under the
PUHCA except for the provisions of Section 9(A)(2), which
pertain to acquisitions of other utilities.
Operating as a public utility under the laws of
Indiana, SIGECO is subject to regulation by the Indiana
Utility Regulatory Commission as to its rates, services,
accounts, depreciation, issuance of securities, acquisitions
and sale of utility properties or securities, and in other
respects as provided by the laws of Indiana. See subsequent
discussion under "Competition" regarding the restructuring
of the electric utility industry and possible deregulation
of certain segments or functions of electric utility
service.
In addition, SIGECO is subject to regulation by the
Federal Energy Regulatory Commission with respect to the
sale and transmission of electric energy in interstate
commerce, its rates for sales for resale, interconnection
agreements with other utilities, the classification of its
accounts and the acquisition and sale of utility property in
certain circumstances as provided by the Federal Power Act.
<PAGE> 11
See "SIGECO-Electric Business", page 5 and "SIGECO-Gas
Business", page 8 for further discussion regarding
regulatory matters.
SIGECO is subject to regulations issued pursuant to
federal and state laws, pertaining to air and water
pollution control. The economic impact of compliance with
these laws and regulations is substantial, as discussed in
detail under "Environmental Matters." SIGECO is also
subject to multiple regulations issued by both federal and
state commissions under the Federal Public Utility
Regulatory Policies Act of 1978.
COMPETITION
As part of its efforts to develop a national energy
strategy, Congress amended PUHCA and the Federal Power Act
by enacting the National Energy Policy Act of 1992 (NEPA),
which will affect the traditional structure of the electric
utility industry. As a result of changes brought about by
NEPA, SIGECO may be required to compete (or have the
opportunity to compete) with other utilities and wholesale
generators for sales of electricity to existing wholesale
customers of SIGECO and other potential wholesale customers.
SIGECO currently competes with other utilities in connection
with intersystem bulk power sales. SIGECO does not
presently compete for retail electric or gas customers with
the other utilities within its assigned service areas.
However, various federal and state legislators, including
members of the Indiana General Assembly, have introduced
proposed legislation addressing retail wheeling and other
related issues. Under the proposed legislation, the
electric generation function (and the marketing function
under some proposals) would be subject to competition and
deregulated, while other functions such as transmitting and
distributing power, would continue to be regulated. See
"National Energy Policy Act of 1992" in Item 7, MANAGEMENT'S
DISCUSSION AND ANALYSIS OF RESULTS OF OPERATIONS AND
FINANCIAL CONDITION, page 20, for discussion of the major
changes effected by NEPA and FERC Orders 888 and 889, issued
during 1996. The new Orders mandate the filing of open
access transmission tariffs and stipulate that the tariffs
and other transmission service information be made available
to all potential customers through an Open Access Same-time
Information System, among other requirements.
Some of SIGECO's gas customers have, or in the future
could acquire, access to energy sources other than those
available through SIGECO. (See "SIGECO-Gas Business", page
8, for discussion of gas transportation.) Although federal
statute allows for bypass of a local distribution company,
Indiana law disallows bypass in most cases and SIGECO would
likely litigate such an attempt in the Indiana courts.
There is also increasing interest in research on the
development of sources of energy other than those in general
use. Such competition from other energy sources has not
been a material factor to SIGECO in the past. SIGECO is
unable, however, to predict the extent of competition in the
future or its potential effect on SIGECO's operations.
ENVIRONMENTAL MATTERS
Testing of five of the six sites utilized for the
manufacture of gas by predecessors of SIGECO was
substantially completed in 1995. The sixth, and last, site
is currently being investigated. Under current regulations,
no remedial action is necessary or required unless the soil
is disturbed. If remediation efforts are required in the
future, SIGECO estimates the related costs would not exceed
$250,000 on a current basis. At the present time, SIGECO
does not anticipate that remediation efforts will be
required at any of these sites and therefore has not
provided for such costs. If, however, significant remedial
action is required on the sixth, or any other sites, SIGECO
will seek recovery of all related costs in excess of amounts
recovered from other potentially responsible parties or
insurance carriers through rates. SIGECO has not been named
a potentially responsible party by the Environmental
Protection Agency (EPA) for these, or any other, sites.
SIGECO is subject to federal, state and local
regulations with respect to environmental matters,
principally air, solid waste and water quality. Pursuant to
environmental regulations, SIGECO is required to obtain
operating permits for the electric generating plants which
it owns or operates and construction permits for any new
plants which it might propose to build. Regulations
concerning air quality establish standards with respect to
both ambient air quality and emissions from SIGECO's
facilities, including particulate matter, sulfur dioxide and
nitrogen oxides. Regulations
<PAGE> 12
concerning water quality establish standards relating to
intake and discharge of water from SIGECO's facilities,
including water used for cooling purposes in electric
generating facilities. Because of the scope and complexity
of these regulations, SIGECO is unable to predict the
ultimate effect of such regulations on its future
operations, nor is it possible to predict what other
regulations may be adopted in the future. SIGECO intends to
comply with all applicable valid governmental regulations,
but will contest any regulation it deems to be unreasonable
or impossible to comply with or which is otherwise invalid.
The implementation of federal and state regulations
designed to protect the environment, including those
hereinafter referred to, involves or may involve review,
certification or issuance of permits by federal and state
agencies. Compliance with such regulations may limit or
prevent certain operations or substantially increase the
cost of operation of existing and future generating
installations, as well as seriously delay or increase the
cost of future construction. Such compliance may also
require substantial investments above those amounts stated
under "Construction Program and Financing", page 10.
All existing SIGECO electric generation facilities have
operating permits from the Indiana Air Board or other
agencies having jurisdiction. In order to secure approval
for these permits, SIGECO has installed electrostatic
precipitators on all coal-fired units and is operating flue
gas desulfurization (FGD) units to remove sulfur dioxide
from the flue gas at its A. B. Brown Units 1 and 2
generating facilities. The FGD units at the Brown Station
remove most of the sulfur dioxide from the flue gas
emissions by way of a scrubbing process, thereby allowing
SIGECO to burn high sulfur southern Indiana coal at the
station.
In October 1990, the U.S. Congress adopted major
revisions to the Federal Clean Air Act. The revisions
require reduction in emissions of sulfur dioxide (SO2) and
nitrogen oxide (NOX) from coal-burning electric generating
facilities, including those owned and operated by SIGECO.
Two of SIGECO's principal coal-fired facilities (A. B. Brown
Units 1 and 2, totaling 500 megawatts of capacity) were
equipped with sulfur dioxide removal equipment (scrubbers)
and were not severely affected by the new legislation.
However, 523 megawatts of SIGECO's coal-fired generating
capacity were significantly impacted by the lower emission
requirements. SIGECO was required to reduce total emissions
from Culley Unit 3 (250 megawatts), Warrick Unit 4 (135
megawatts) and Culley Unit 2 (92 megawatts) by approximately
50% to 2.5 lb/MMBTU by January 1995 (Phase I) and to 1.2
lb/MMBTU by January 2000 (Phase II). SIGECO met all of the
Phase I emission requirements and some of the Phase II
requirements by January 1995 with the implementation of its
Clean Air Act Compliance Plan which includes equipping
Culley Units 2 and 3 with a sulfur dioxide scrubber, among
other provisions. Unit 1 at Culley Station (46 megawatts)
is also subject to the 1.2 lb/MMBTU restriction by January
2000. Current regulatory policy allows for the recovery
through rates of all authorized and approved pollution
control expenditures. Refer to "Clean Air Act" in Item 7,
MANAGEMENT'S DISCUSSION AND ANALYSIS OF RESULTS OF
OPERATIONS AND FINANCIAL CONDITION, page 21, for further
discussion of SIGECO's Clean Air Act Compliance Plan, and
the associated costs. SIGECO filed Title V (of the 1990
Amendments to the Federal Clean Air Act) permit applications
for all of its applicable generation facilities during the
fourth quarter of 1996. The applications have been approved
for completeness and are being processed by the Indiana Air
Board. Warrick Unit 4 (50% owned by SIGECO) is covered by
Title V permit applications filed by Alcoa Generating
Corporation, majority owner of the Warrick Generating
Station.
With the addition of the scrubber at the Culley
generating station, SIGECO is exceeding the minimum
compliance requirements of Phase I and intends, at this
time, to utilize resulting "overcompliance allowances" and
fuel blending (with low sulfur coal) strategies to meet the
remaining Phase II requirements effective January 2000. No
material capital expenditures are anticipated to meet Phase
II requirements, and thus, none are reflected in the
projected construction requirements for the years 1997-2001
discussed in "Liquidity and Capital Resources" in Item 7,
MANAGEMENT'S DISCUSSION AND ANALYSIS OF RESULTS OF
OPERATIONS AND FINANCIAL CONDITION, page 22.
In October 1996, SIGCORP received a notice of violation
(NOV) from the federal EPA for alleged violations of Indiana
air pollution regulations regarding particulate matter
emissions in October 1995 by the Unit 1 boiler of SIGECO's
Culley Station. The notice is a preliminary finding of
violation and is being discussed with the EPA.
<PAGE> 13
In December 1996 and January 1997, the federal EPA
issued proposed regulations regarding new national ambient
air quality standards for regional ozone and particulate
matter concentration levels, which could reduce SIGECO's
allowed NOx and particulate matter emissions. SIGECO is
currently evaluating the proposed regulations and the
potential impact on SIGECO if ultimately adopted.
In connection with the use of sulfur dioxide removal
equipment at the A. B. Brown Generating Station, SIGECO
operates a solid waste landfill for the disposal of
approximately 200,000 tons of residue per year from the
scrubbing process. Application for renewal of the landfill
operating permit was filed with the Indiana Department of
Environmental Management (IDEM) in August 1996. The
existing permit will remain in effect until action is taken
by IDEM on the renewal application. SIGECO also has a solid
waste landfill available for the disposal of the gypsum by-
product being produced by the new sulfur dioxide scrubber at
the Culley Generating Station. SIGECO was granted a five-
year operating permit for the landfill in June 1995, but
anticipates using this landfill only when the gypsum by-
product does not meet contract specifications. Refer to
"Clean Air Act" in Item 7, MANAGEMENT'S DISCUSSION AND
ANALYSIS OF RESULTS OF OPERATIONS AND FINANCIAL CONDITION,
page 21 of this report, for discussion of the sale of the
gypsum by-product to a wallboard manufacturer.
Under the Federal Water Pollution Control Act of 1972
and Indiana law and regulations, SIGECO is required to
obtain permits to discharge effluents from its existing
generating stations into the navigable waterways of the
United States. The State of Indiana has received
authorization from the EPA to administer the Federal
discharge permits program in Indiana. Variances from
effluent limitations may be granted by permit on a plant-by-
plant basis where the utility can establish the limitations
are not necessary to assure the protection of aquatic life
and wildlife in and on the body of water into which the
discharge is to be made. SIGECO has been granted National
Pollution Discharge Elimination System (NPDES) permits
covering miscellaneous waste water and thermal discharges
for all its generating facilities to which the NPDES is
applicable, namely the Culley Station, A. B. Brown Station,
Broadway Station (gas turbines) and Warrick Unit 4. Such
discharge permits are limited in time and must be renewed at
five-year intervals. During 1994, SIGECO submitted renewal
applications for these permits, which are currently pending,
as they are for most industries. The existing permits will
remain in effect until action is taken by IDEM on the
renewal applications. SIGECO anticipates renewal of the
permits by IDEM. At present, there are no known enforcement
proceedings concerning water quality pending or threatened
against SIGECO.
<PAGE> 14
<TABLE>
<CAPTION>
EXECUTIVE OFFICERS OF SIGCORP AND SIGECO
Age at Positions Held During
Name 12/31/96 Past Five Years Dates
<S> <C> <C> <C>
R. G. Reherman 61 Chairman of the Board of Directors,
President and Chief Executive
Officer of SIGCORP 01/96-Present
Chairman of the Board of Directors,
President and Chief Executive
Officer of SIGECO 03/92-Present
President, Chief Executive Officer
and Director of SIGECO *-03/92
A. E. Goebel 49 Secretary and Treasurer
of SIGCORP 01/96-Present
Senior Vice President,
Chief Financial Officer
and Secretary of SIGECO 10/96-Present
Senior Vice President,
Chief Financial Officer,
Secretary and Treasurer
of SIGECO *-10/96
J. G. Hurst 53 Senior Vice President and
General Manager
of Operations of SIGECO 03/92-Present
Vice President, Gas and Warrick
Operations of SIGECO *-03/92
J. L. Davis 41 Vice President of Marketing
and Customer
Service of SIGECO 07/95-Present
Director of Marketing of SIGECO *-07/95
R. G. Jochum 49 Vice President and Director
of Power Production of SIGECO 07/94-Present
Director of Power Production
of SIGECO 09/93-07/94
G. M. McManus 49 Vice President and Director
of Governmental
and Public Relations of SIGECO 03/92-Present
Director of Governmental
Affairs of SIGECO *-03/92
<FN>
* Indicates positions held at least since 1992.
</FN>
</TABLE>
Item 2. PROPERTIES
SIGCORP and SIGECO
SIGCORP has no significant properties other than common
stock of affiliates.
SIGECO's installed generating capacity as of December
31, 1996 was rated at 1,236,000 Kw. SIGECO's coal-fired
generating facilities are: the Brown Station with 500,000
Kw of capacity, located in Posey County about eight miles
east of Mt. Vernon, Indiana; the Culley Station with 386,000
Kw of capacity, and Warrick Unit 4 with 135,000 Kw of
capacity. Both the Culley and Warrick Stations are located
in Warrick County near Yankeetown, Indiana. SIGECO's gas-
fired turbine peaking units are: the 80,000 Kw Brown Gas
Turbine located at the Brown Station; two Broadway Gas
Turbines located in Evansville, Vanderburgh County, Indiana,
with a combined capacity of 115,000 Kw; and two Northeast
Gas Turbines located northeast of Evansville in Vanderburgh
County, Indiana with a combined capacity of 20,000 Kw. The
Brown and Broadway turbines are also equipped to burn oil.
Total capacity of SIGECO's five gas turbines
<PAGE> 15
is 215,000 Kw and are generally used only for reserve,
peaking or emergency purposes due to the higher per unit
cost of generation.
SIGECO's transmission system consists of 804 circuit
miles of 138,000 and 69,000 volt lines. The transmission
system also includes 31 substations with an installed
capacity of 3,866,590 kilovolt amperes (Kva). The electric
distribution system includes 3,178 pole miles of lower
voltage overhead lines and 199 trench miles of conduit
containing 1,115 miles of underground distribution cable.
The distribution system also includes 85 distribution
substations with an installed capacity of 1,587,734 Kva and
46,501 distribution transformers with an installed capacity
of 1,943,668 Kva.
SIGECO owns and operates three underground gas storage
fields with an estimated ready delivery from storage
capability of 3.9 million Dth of gas. The Oliver Field, in
service since 1954, is located in Posey County, Indiana,
about 13 miles west of Evansville. The Midway Field is
located in Spencer County, Indiana, about 20 miles east of
Evansville near Richland, Indiana, and was placed in service
in December 1966. The third field is the Monroe City Field,
located in Knox County, about 10 miles east of Vincennes,
Indiana. The field was placed in service in 1958.
SIGECO's gas transmission system includes 341 miles of
transmission mains, and the gas distribution system includes
2,458 miles of distribution mains.
SIGECO's properties are subject to the lien of the
First Mortgage Indenture dated as of April 1, 1932 between
SIGECO and Bankers Trust Company, New York, as Trustee, as
supplemented by various supplemental indentures, all of
which are exhibits to this report and collectively referred
to as the "Mortgage".
Subsidiaries other than SIGECO have no significant
properties other than investments in real estate
partnerships, leveraged leases and marketable securities.
Item 3. LEGAL PROCEEDINGS
SIGCORP and SIGECO
There are no pending legal proceedings, other than
ordinary routine litigation incidental to the business, to
which the registrant is a party.
No material legal proceedings were terminated during
the fourth quarter of 1996.
Item 4. SUBMISSION OF MATTERS TO VOTE OF SECURITY HOLDERS
SIGCORP and SIGECO
None
PART II
<PAGE> 16
Item 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND
RELATED SECURITY HOLDER MATTERS
SIGCORP and SIGECO
Effective January 1, 1996, all shares of common stock
of SIGECO were exchanged for an equal number of shares of
common stock of SIGCORP. As of February 21, 1997, SIGCORP
had 8,377 holders of record of common stock. The principal
market on which SIGCORP's common stock is traded is the New
York Stock Exchange, Inc. where the common stock is listed.
The high and low sales prices for SIGCORP's stock as
reported in the consolidated transaction reporting system
for each quarterly period during the two most recent fiscal
years were:
<TABLE>
<CAPTION>
QUARTERLY PERIOD
1 2 3 4
High Low High Low High Low High Low
<S> <C> <C> <C> <C> <C> <C> <C> <C>
1996 $37 $32-7/8 $34-7/8 $32-7/8 $35-5/8 $33-1/4 $35-3/4 $33
1995 $29-1/4 $26-3/8 $34-1/8 $28-7/8 $33-3/4 $30 $36-3/8 $32-5/8
</TABLE>
Dividends declared and paid per share of SIGCORP common
stock during the past two years were:
<TABLE>
<CAPTION>
QUARTERLY PERIOD
1 2 3 4
<S> <C> <C> <C> <C>
1996 $0.4325 $0.4325 $0.4325 $0.4325
1995 $0.4225 $0.4225 $0.4225 $0.4225
</TABLE>
The quarterly dividend on common stock was increased to
44-1/4 cents per share in January 1997, payable March 20,
1997.
DIVIDEND RESTRICTIONS
The following restrictions pertain to SIGECO but, to
the extent that the dividends of SIGCORP depend on SIGECO
earnings, may have an effect on SIGCORP.
The payment of cash dividends on SIGECO's common stock
to SIGCORP is, in effect, restricted by the Mortgage to
accumulated surplus, available for distribution to the
common stock, earned subsequent to December 31, 1947,
subject to reduction if amounts deducted from earnings for
current repairs and maintenance and provisions for renewals,
replacements and depreciation of all the property of SIGECO
are less than amounts specified in the Mortgage. (See
Section 1.02 of the Supplemental Indenture dated as of July
1, 1948, as supplemented.) No amount was restricted against
cash dividends on common stock as of December 31, 1996 under
this restriction.
The payment of cash dividends on common stock is, in
effect, restricted by SIGECO's Amended Articles of
Incorporation to accumulated surplus, available for
distribution to the common stock, earned subsequent to
December 31, 1935. The Amended Articles of Incorporation
require that, immediately after such dividends, there shall
remain to the credit of earned surplus an amount at least
equal to two times the annual dividend requirements on all
then outstanding Preferred Stock, No Par Value. (See Art.
VI, Terms of Capital Stock, General Provisions (B)). The
amount restricted against cash dividends on common stock at
December 31, 1996 under this restriction was $2,194,121,
leaving $211,493,949 unrestricted for the payment of
dividends. In addition, the Amended Articles of
Incorporation provide that surplus otherwise available for
the payment of dividends on common stock shall be restricted
to the extent that such surplus is included in a calculation
required to permit SIGECO to issue, sell or dispose of
preferred stock or other stock senior to the common stock
(Art. VI, Terms of Capital Stock, General Provisions (E)).
<PAGE> 17
An order of the Securities and Exchange Commission
dated October 12, 1944 under the Public Utility Holding
Company Act of 1935 in effect restricts the payment of cash
dividends on common stock to 75% of net income available for
distribution to the common stock, earned subsequent to
December 31, 1943, if the percentage of common stock equity
to total capitalization and surplus, as defined, is less
than 25%. At December 31, 1996, such ratio amounted to
approximately 49%.
Item 6. SELECTED FINANCIAL DATA
SIGCORP and SIGECO
<TABLE>
<CAPTION>
SIGCORP, Inc.
Year Ended December 31
(in thousands except
per share data) 1996 1995 1994 1993 1992
<S> <C> <C> <C> <C> <C>
Operating Revenues $372,730 $338,698 $330,035 $329,489 $306,905
Operating Income $ 61,041 $ 53,873 $ 52,367 $ 51,565 $ 50,895
Net Income Before
Cumulative Effect
of Accounting Change $ 43,264 $ 38,525 $ 39,920 $ 38,483 $ 35,491
Net Income $ 43,264 $ 44,819 $ 39,920 $ 38,483 $ 35,491
Average Common Shares
Outstanding 15,755 15,755 15,755 15,755 15,755
Earnings Per Share
of Common Stock Before
Cumulative Effect of
Accounting Change $ 2.75 $ 2.44 $ 2.53 $ 2.44 $ 2.25
Cumulative Effect
of Accounting Change $ - $ 0.40 $ - $ - $ -
Total Earnings Per
Share of Common Stock $ 2.75 $ 2.84 $ 2.53 $ 2.44 $ 2.25
Dividends Per Share
of Common Stock $ 1.73 $ 1.69 $ 1.65 $ 1.61 $ 1.56
Total Assets $952,653 $923,981 $917,416 $860,841 $762,133
Redeemable Preferred
Stock $ 8,424 $ 8,424 $ 8,515 $ 8,515 $ 8,515
Long-Term Obligations $266,951 $265,085 $274,467 $274,884 $213,026
</TABLE>
<TABLE>
<CAPTION>
Southern Indiana Gas And Electric Company
Year Ended December 31
(in thousands except
per share data) 1996 1995 1994 1993 1992
<S> <C> <C> <C> <C> <C>
Operating Revenues $372,730 $338,698 $330,035 $329,489 $306,905
Operating Income $ 61,041 $ 53,873 $ 52,367 $ 51,565 $ 50,895
Net Income Before
Cumulative Effect of
Accounting Change $ 42,841 $ 39,624 $ 41,025 $ 39,588 $ 36,758
Net Income Applicable
to Common Stock $ 41,744 $ 44,819 $ 39,920 $ 38,483 $ 35,491
Average Common Shares
Outstanding 15,755 15,755 15,755 15,755 15,755
Earnings Per Share of
Common Stock Before
Cumulative Effect of
Accounting Change $ 2.65 $ 2.44 $ 2.53 $ 2.44 $ 2.25
Cumulative Effect
of Accounting Change $ - $ 0.40 $ - $ - $ -
Total Earnings Per
Share of Common Stock $ 2.65 $ 2.84 $ 2.53 $ 2.44 $ 2.25
Dividends Per Share of
Common Stock $ 1.73 $ 1.69 $ 1.65 $ 1.61 $ 1.56
Total Assets $852,325 $923,981 $917,416 $860,841 $762,133
Redeemable Preferred
Stock $ 8,424 $ 8,424 $ 8,515 $ 8,515 $ 8,515
Long-Term Obligations $252,114 $265,085 $274,467 $274,884 $213,026
</TABLE>
<PAGE> 18
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF RESULTS OF
OPERATIONS AND FINANCIAL CONDITION
References to "Notes" pertain to the Notes to Consolidated
Financial Statements.
SIGCORP and SIGECO
SIGCORP, Inc. (SIGCORP) is an investor-owned holding company
with nine wholly-owned subsidiaries. Southern Indiana Gas
and Electric Company (SIGECO), a regulated gas and electric
utility, accounts for over 90% of SIGCORP's net income.
Because of the significance of SIGECO, the operating results
of all other subsidiaries, which are nonregulated, are
included in Other Income in the consolidated statements of
SIGCORP. Refer to Note 1, page 40, for further discussion
of the restructuring of SIGECO effective January 1, 1996.
Earnings per share for SIGCORP and SIGECO were $2.75 and
$2.65, respectively, in 1996, compared to 1995 earnings
before the cumulative effect of an accounting change of
$2.44 and 1994 earnings of $2.53.
The 1996 earnings were favorably impacted by a number of
items, including:
* Increased sales to retail gas and electric customers
* Higher sales margins resulting from approved increases
in gas and electric rates
* Lower maintenance expenditures
* Record high sales to other electric utilities and power
marketers
The above listed items were partially offset by:
* Increased operating expenses related to the additional
costs of postretirement benefits other than pensions
* Higher full-year operating expenses of SIGECO's new
Culley sulfur dioxide removal facility which began
operation in 1995
* Fewer sales to Alcoa Generating Corporation
SALES AND REVENUES Electric revenue increases due to
greater electric sales and full year implementation of the
third step of a three-step increase in retail electric rates
(see "Rate and Regulatory Matters") were substantially
offset by the recovery of lower unit fuel costs through
retail rates, resulting in a slight increase in electric
revenues during 1996. In 1995, electric revenues rose 5.6%
($14.6 million) due to implementation of the second and
third steps of the rate increase and to increased sales to
retail and wholesale electric customers. Total sales to
retail and firm contract wholesale customers were up 3.4% in
1996, following an increase of 3.2% in 1995, and were led by
stronger commercial and industrial sales resulting from
continued economic growth in SIGECO's service area.
Excluding sales to Alcoa Generating Corporation, which
declined after rising 53% in 1995, nonfirm wholesale
electric sales increased 22% in 1996 following a 23%
increase in 1995. These sales represented approximately 11%
of total 1996 electric sales.
Stronger sales to all retail gas customers, higher unit gas
costs recovered through retail rates (see "Cost of Gas
Sold") and the impact of approved increases in base gas
rates (see "Rate and Regulatory Matters") resulted in a 52%
($33 million) increase in 1996 gas operating revenues,
following an 8.5% ($5.9 million) decline in 1995 gas
revenues caused by the recovery of lower unit gas costs and
fewer sales to residential customers. Gas sales were up 24%
in 1996, with residential and commercial sales rising 19%
and 21%, respectively. The increased sales reflected 17%
colder winter temperatures in the region when measured in
heating degree days, and the continued economic development
in SIGECO's service area. Sales to industrial customers
rose 43% during the year due to greater sales to
transportation customers and the continued economic growth.
FUEL AND PURCHASED ELECTRIC ENERGY Fuel for electric
generation, the most significant electric operating cost,
declined 7.8% ($6.4 million) in 1996 due to 12% lower unit
coal costs resulting from SIGECO's coal contract reformation
efforts (see "Rate and Regulatory Matters"). Average coal
costs per kWh generated were $.0124, $.0141 and $.0149 for
1996, 1995 and 1994, respectively. SIGECO continues to
pursue further reductions in coal prices as a key component
of its strategy to remain a low-cost provider of electricity
and anticipates that 1997 unit coal costs will decline
further. The 1995 fuel for electric generation expense was
2.6% lower than 1994 costs due to the lower unit coal costs.
<PAGE> 19
Due to the reduced requirements of Alcoa Generating
Corporation, SIGECO decreased its purchases of electricity
from other utilities by 15% in 1996. Conversely, purchases
of electric energy in 1995 were 69% greater than in 1994.
COST OF GAS SOLD The generally downward trend of natural
gas market prices experienced over the past several years
was drastically reversed in 1996 when the combination of
greater demand for gas caused by colder winter temperatures
nationwide and fewer available natural gas supplies caused
unit gas costs to be 37% higher than those incurred in 1995.
The higher unit costs combined with the increase in sales
resulted in a 64% ($25.8 million) increase in cost of gas
sold in 1996, the major component of gas operating expenses.
The higher unit costs during the current period followed
declines in 1995 and 1994 of 7.7% and 7.9%, respectively.
Changes in the unit costs of gas sold are passed on to
customers through an Indiana Utility Regulatory Commission
(IURC) approved gas cost recovery mechanism.
OTHER OPERATION AND MAINTENANCE EXPENSES Other operation
expenses rose 11% ($5.5 million) during 1996 mainly due to
the additional costs of postretirement benefits other than
pensions applicable to retail electric and gas operations.
Those costs total about $2.8 million on an annual basis
beginning June 1995 and an additional $1.1 million on an
annual basis beginning July 1996. The costs were previously
deferred pending inclusion in electric and gas rates (see
"Rate and Regulatory Matters"). The increased operation
expenses also reflected full-year operating costs of the new
sulfur dioxide scrubber placed in commercial service
February 1, 1995 (see "Clean Air Act"), and higher other
operating expenses. In 1995, other operation expenditures
were 3.7% ($1.8 million) greater than 1994 expenses, due
primarily to the additional postretirement benefit costs
applicable to retail electric operations and to the
operating costs of the new scrubber.
No major power generation maintenance projects were
performed during 1996. As a result, power generation
maintenance expenditures were lower than in 1995, when a
scheduled major turbine generator maintenance overhaul was
performed at SIGECO's A. B. Brown Generating Station.
Additionally, on June 8, 1995, SIGECO's service area
experienced a storm requiring $3.5 million to restore
service to its customers. Of that amount, approximately $2
million was related to system repairs; the remainder
represented capital replacements. These were the chief
reasons for an 8% ($2.5 million) decrease in 1996
maintenance expenses, following a 5.9% ($1.8 million)
increase in 1995 maintenance expenditures resulting from the
storm repairs.
DEPRECIATION AND AMORTIZATION Depreciation and amortization
expense declined slightly in 1996, the result of lower
depreciation rates on electric utility plant related to
SIGECO's retail electric rate adjustment. The 1996 decrease
followed 4.2% ($1.6 million) higher expenses in 1995, due
primarily to the depreciation of SIGECO's $103 million
investment in its Clean Air Act Compliance Plan facilities
(see "Clean Air Act") beginning February 1, 1995.
Depreciation of gas plant increased slightly during 1996 and
1995 due to SIGECO's continued investment in facilities
required by new business development and improvements to the
existing gas distribution system.
While inflation has a significant impact on the replacement
cost of SIGECO's facilities, only the historical cost of
electric and gas plant investment is recoverable in revenues
as depreciation under the ratemaking principles followed by
the IURC, under whose regulatory jurisdiction SIGECO is
subject. With the exception of adjustments for changes in
fuel and gas costs and margin on sales lost under SIGECO's
demand side management programs, SIGECO's electric and gas
rates remain unchanged until a rate application is filed and
a general rate order is issued by the IURC.
TAXES Federal and state income taxes were $5.9 million
greater during 1996 due to the higher pretax operating
income and to a $1.2 million downward adjustment to income
tax reserves during 1995. Taxes other than income taxes in
1996 were comparable to 1995 costs, which were up $3.5
million from 1994. Included in 1994 was a $3.3 million
adjustment to prior years' provisions for property taxes
related to the favorable outcome of a property tax appeal.
OTHER INCOME AND INTEREST CHARGES Other income for SIGCORP
was $2.2 million lower during 1996 due primarily to lower
earnings of certain SIGCORP nonregulated subsidiaries.
Although allowance for equity funds used during construction
decreased $3.6 million in 1995 due to the completion of the
scrubber construction, the initial sale to another utility
under a five-year sales agreement of SIGECO's allotment of
"bonus" sulfur dioxide emission allowances and improved
results of certain SIGCORP nonregulated subsidiaries
partially offset the impact on Other Income. Other income
for SIGECO during 1996 was an additional $1.5 million lower
due to the absence of SIGECO's nonregulated subsidiary
earnings effective January 1, 1996.
<PAGE> 20
Interest and other charges were relatively unchanged from
1995 when such charges were $1.8 million higher than in 1994
chiefly due to lower capitalized interest resulting from
completion of the scrubber.
RATE AND REGULATORY MATTERS SIGECO complies with the
provisions of Financial Accounting Standard (FAS) 71,
"Accounting for the Effects of Certain Types of Regulation"
that allows certain costs incurred by SIGECO that have been,
or are expected to be, approved by regulatory authorities
for recovery through rates, to be deferred as regulatory
assets until recovered by SIGECO. Criteria that could give
rise to the discontinuance of FAS 71 include (1) increasing
competition that restricts SIGECO's ability to establish
prices to recover specific costs, and (2) a significant
change in the manner in which rates are set by regulators
from cost-based regulation to another form of regulation.
SIGECO periodically reviews these criteria to ensure the
continuing application of FAS 71 is appropriate. In the
event SIGECO determines that it no longer meets the criteria
for following FAS 71, the accounting impact could be an
extraordinary noncash charge to operations of an amount that
could be material. FAS 121, "Accounting for the Impairment
of Long-Lived Assets and for Long-Lived Assets to be
Disposed Of", issued in March 1995 and effective January 1,
1996, imposes a stricter criterion for these regulatory
assets by requiring that such assets be probable of future
recovery at each balance sheet date. SIGECO adopted this
new standard for 1996, which did not have a material impact
on financial position or results of operations. SIGECO
believes its regulatory assets are fully recoverable under
SIGECO's present regulatory environment and given its
competitive position in the industry (see "National Energy
Policy Act of 1992" and Note 1, page 40).
In September 1995, SIGECO petitioned the IURC seeking a
general increase in gas rates. On July 3, 1996, the IURC
issued its order, effective July 15, granting a 7.3%, or
$4.8 million, increase in annual revenues. The adjustment
in rates is necessary to recover increases in operating and
maintenance costs and additional investment in gas
distribution facilities. The adjustment includes recovery
of additional costs incurred for postretirement benefits
other than pensions related to gas operations approximating
$1.1 million annually (see Note 2, page 46).
In June 1995, the IURC approved the third of three retail
electric rate increases related to its Clean Air Act
Compliance project, representing an increase of 2.1%, or
$4.5 million, in revenues (see Note 2, page 46). The final
adjustment was necessary to cover financing costs related to
the balance of the project construction expenditures, costs
related to the operation of the scrubber, and certain
nonscrubber - related operating costs such as additional
costs incurred for postretirement benefits other than
pensions beginning in 1993 and the recovery of demand side
management program expenditures (see "Demand Side
Management").
Over the past several years, SIGECO has been actively
involved in intensive contract negotiations and legal
actions to reduce coal costs and thereby lower electric
rates. In April 1995, SIGECO reached an agreement with its
remaining long-term contract coal supplier, effective July
1995, to buy out the remainder of SIGECO's contractual
obligations, enabling it to acquire lower-priced spot market
coal. SIGECO estimates the total savings in coal costs
resulting from the buyout, net of total buyout costs, will
approximate $58 million through December 31, 1998, the term
of the original contract. The net savings are being passed
back to SIGECO's electric customers through the fuel
adjustment clause.
NATIONAL ENERGY POLICY ACT OF 1992 Key provisions of the
National Energy Policy Act of 1992 (NEPA) are causing some
of the most significant changes in the history of the
electric industry. The primary purpose of the electric
provisions is to increase competition in electric generation
by enabling virtually nonregulated entities, such as exempt
wholesale generators, to develop power plants, and by
providing the Federal Energy Regulatory Commission (FERC)
authority to require a utility to provide transmission
services, including the expansion of the utility's
transmission facilities necessary to provide such services,
to any entity selling or purchasing electricity at
wholesale. Although the FERC may not order retail wheeling
(the transmission of electricity directly to an ultimate
consumer), it may order wheeling of electricity generated by
an exempt wholesale generator or another utility to a
wholesale customer of a regulated utility.
On April 24, 1996, FERC issued Order 888 which finalized the
key provisions of its Notice of Proposed Rulemaking (Mega-
NOPR) on Open Access issued in March 1995. Order 888
provides for mandatory filing of open access
<PAGE> 21
transmission tariffs, provides for functional unbundling of
all transmission services, requires utilities to use the
tariffs for their own bulk power transactions, and allows
recovery of stranded costs in certain circumstances. In
December 1995, SIGECO filed a Point-To-Point Transmission
Service Tariff and a Network Integration Transmission
Service Tariff which closely conform to the pro forma
tariffs required by the Mega-NOPR and Order 888, under which
SIGECO will offer firm and nonfirm point-to-point
transmission service, network integration transmission
service and certain ancillary services to any entity
eligible for mandatory wholesale transmission service under
Order 888.
Also on April 24, 1996, FERC issued Order 889 which requires
each public utility that owns, controls or operates
facilities used for the transmission of electric energy in
interstate commerce to create or participate in an Open
Access Same-time Information System for posting information
about available transmission capacity, prices and other
information that will enable customers to obtain open access
nondiscriminatory transmission service. Order 889 requires
the filing of detailed Standards of Conduct defining how a
transmission provider will functionally separate its
transmission and wholesale power merchant functions. SIGECO
has implemented the necessary changes to comply with Order
889.
In addition to FERC Orders 888 and 889, various federal and
state legislators, including members of the Indiana General
Assembly, have introduced proposed legislation addressing
retail wheeling, stranded cost recovery, unbundling of
services and other related issues. Several state regulatory
commissions have adopted new regulations addressing the
above issues but most states, including Indiana, are
continuing to evaluate the issues. While the electric
generation function (and the marketing function under some
proposals) of utilities would be subject to competition
under the proposed legislation, all other functions, such as
transmitting and distributing power, would continue to be
regulated. Generally, under some versions of the proposed
legislation, customers would be able to choose their power
supplier by paying a market access charge which is designed
to recover the respective utility's stranded generation
costs; in other versions of the proposed legislation, all
customers would be assessed a charge to repay utilities for
so-called transition costs, similar to the transition costs
paid as a result of gas pipeline deregulation. SIGCORP
anticipates proposed legislation will not be enacted in
1997.
Although SIGECO is uncertain of the timing and/or final
outcome of these developments, it is committed to pursuing,
and is moving rapidly to implement, its corporate strategy
of positioning itself as a low-cost energy producer and the
provider of high-quality service to its retail as well as
wholesale customers. SIGECO has some of the lowest per-unit
administrative, operation and maintenance costs in the
industry, and with the completion of its coal supply
reformation strategy will also rank among the lowest cost
power producers (see "Rate and Regulatory Matters" for
discussion of coal contract negotiations).
SIGCORP
NEW NONREGULATED SUBSIDIARIES During the fourth quarter of
1996, four additional nonregulated subsidiaries were formed:
SIGCORP Energy Services, Inc. (Energy), SIGCORP Capital,
Inc. (Capital), SIGCORP Fuels, Inc. (Fuels) and SIGCORP
Power Marketing, Inc. (Power). Energy was established to
provide natural gas, pipeline management, storage service
and other natural gas energy-related services to SIGECO and
other customers, and is seeking regulatory approval to
become SIGECO's gas procurement and transportation manager.
Capital, a financial subsidiary, will be the primary
financing vehicle for SIGCORP's nonregulated subsidiaries.
Fuels was established to provide coal and related services,
such as transportation of coal, to SIGECO and other
customers, and will seek regulatory approval to do so.
Power was formed to procure electric power supplies for
SIGECO and other customers and will market SIGECO's excess
electric generation capacity. Power will begin operation
after FERC approval of its power marketer status.
SIGCORP and SIGECO
CLEAN AIR ACT To meet the Phase I requirements of the Clean
Air Act Amendments of 1990 (effective 1995) and some of the
Phase II requirements (effective 2000), SIGECO installed a
single sulfur dioxide scrubber at the Culley Generating
Station to serve Culley Units 2 and 3 and installed low
nitrogen oxide (NOx) burners on the two units. The
facilities were constructed at a total cost of $103 million
and began commercial operation February 1, 1995.
<PAGE> 22
By installing a scrubber, SIGECO was entitled to apply to
the federal EPA for extra allowances, called "extension
allowances." SIGECO will receive about 88,500 extension
allowances, which it has sold to another utility. SIGECO is
crediting approximately $2.5 million per year from the sale
for the period 1995 through 1999 to retail customers to
reduce the rate impact of its compliance plan.
Additionally, SIGECO is selling gypsum produced from the
scrubbing process to a major wallboard manufacturer and
reducing certain operating costs with the proceeds, further
mitigating the rate impact of the compliance plan.
With the addition of the scrubber, SIGECO is exceeding the
minimum compliance requirements of Phase I of the Clean Air
Act and has available unused allowances, called
"overcompliance allowances", for retention by SIGECO to meet
stricter post-2000 emission limitations.
ENVIRONMENTAL MATTERS In December 1996 and January 1997,
the federal EPA issued proposed regulations regarding new
national ambient air quality standards for regional ozone
and particulate matter concentration levels, which could
reduce SIGECO's allowed NOx and particulate matter
emissions. SIGECO is currently evaluating the proposed
regulations and the potential impact on SIGECO if ultimately
adopted.
DEMAND SIDE MANAGEMENT Since 1991, SIGECO has invested in
certain demand side management (DSM) programs as part of its
integrated resource planning initiatives. The primary
purpose of the DSM programs is to reduce the demand on
SIGECO's generating capacity at the time of system peak
requirements, thereby postponing or avoiding the addition of
generating capacity. For that reason, the accounting and
ratemaking treatment of DSM program expenditures generally
parallel the treatment of construction of new generating
facilities (see Note 1, page 40).
In November 1995, SIGECO filed the latest update of its
Integrated Resource Plan (IRP) with the IURC, requesting
approval to greatly reduce previously ordered future DSM
programs due to the anticipated changes precipitated by the
NEPA. In July 1996, the IURC approved the reduction of
projected DSM program expenditures during the 1997-2012
period from a total of $138 million to $39 million (see
"Liquidity and Capital Resources"). Although future DSM
expenditures will be substantially reduced, the IRP
projections indicate that by 2000, 60 megawatts of capacity
are expected to have been postponed or eliminated due to
these programs.
SIGECO will continue to monitor the benefits of its DSM
programs and additional changes are possible. Although
SIGECO is already recognized as one of the most competitive
electric utilities in the nation, the reductions were
requested by SIGECO to enable it to be even more cost
competitive in the future with very low stranded investment
exposure.
Although SIGECO does not currently anticipate the need for
future additional base-load generation, the purchase of
short-term summer peaking capacity is anticipated beginning
in 1997 due to the continuing strong economic growth in
SIGECO's service area.
LIQUIDITY AND CAPITAL RESOURCES In 1996, financial
performance continued to be solid. Internally generated
cash (net income less dividends plus charges to net income
not requiring cash) fully funded SIGECO's construction and
DSM program expenditures. SIGCORP's and SIGECO's ratio of
earnings to fixed charges (SEC method) was 4.0:1, and
embedded cost of long-term debt and preferred stock is 6.6%
and 5.6%, respectively. SIGCORP's financial strength is
reflected in high quality credit ratings. SIGECO's senior
secured debt continues to be rated AA, or equivalent, by
major credit rating agencies.
SIGCORP's demand for capital is primarily related to
SIGECO's construction of utility plant and equipment
necessary to meet customers' electric and gas energy needs,
as well as environmental compliance requirements, and to
expenditures for SIGECO's DSM programs. Construction
expenditures totaled $43.9 million during 1996, and
consisted of normal replacements and improvements to gas and
electric facilities. Those expenditures included $3.6
million for DSM programs and $2.8 million for facilities
under construction to serve the new Toyota truck
manufacturing plant. The 1996 expenditures compare to
$54.1 million and $84.8 million expended in 1995 and 1994,
respectively, which included the construction of the new
scrubber and the 1995 replacement and upgrade of the turbine
on one of SIGECO's turbine generators.
<PAGE> 23
Construction requirements for the years 1997-2001 are
projected to total approximately $260 million, including
approximately $25 million to design and implement several
comprehensive information systems necessary to meet
expanding customer service needs and better manage SIGECO's
resources. Construction requirements also include
approximately $9 million of capitalized expenditures to
develop and implement DSM programs.
Other than an $8.5 million increase in SIGCORP's short-term
debt, no financing activity occurred during 1996, which was
comparable to 1995, when the only financing activity was an
$8.4 million increase in short-term debt. At year end,
SIGCORP had $38.8 million in short-term borrowings, leaving
unused lines of credit and trust demand note arrangements
totaling $19.2 million. SIGECO's short-term debt rose $1.9
million during 1996, and no other financing occurred.
SIGECO's total long-term debt and long-term partnership
obligations declined $12.9 million during 1996 due to
dividending its nonregulated subsidiaries to SIGCORP January
1, 1996.
SIGECO redeemed $8.0 million of 6% first mortgage bonds
during 1996 with a like amount of short-term debt. During
the five-year period of 1997-2001, SIGCORP anticipates that
a total of $69.8 million of debt securities, primarily those
of SIGECO, will be redeemed.
SIGCORP expects the majority of the 1997-2001 construction
program and debt redemption requirements to be provided by
internally generated funds. External financing requirements
of $60-70 million are anticipated and will be used primarily
to redeem long-term debt.
SIGCORP is confident that its long-term financial
objectives, which include maintaining a capital structure
near 45-50% long-term debt, 3-7% preferred stock and 43-48%
common equity, will continue to be met, while providing for
future construction and other capital requirements.
<PAGE> 24
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
<TABLE>
<CAPTION>
Page
Number
<S> <C> <C>
1. Financial Statements
SIGCORP and SIGECO
Report of Independent Public Accountants 25
SIGCORP
Consolidated Statements of Income for the years
ended December 31, 1996, 1995 and 1994 27
Consolidated Statements of Cash Flows for the years
ended December 31, 1996, 1995 and 1994 28
Consolidated Balance Sheets - December 31, 1996
and 1995 29
Consolidated Statements of Capitalization -
December 31, 1996 and 1995 31
Consolidated Statements of Retained Earnings for the
years ended December 31, 1996, 1995 and 1994 32
SIGECO
Consolidated Statements of Income for the years
ended December 31, 1996, 1995 and 1994 34
Consolidated Statements of Cash Flows for the years
ended December 31, 1996, 1995 and 1994 35
Consolidated Balance Sheets - December 31, 1996
and 1995 36
Consolidated Statements of Capitalization -
December 31, 1996 and 1995 38
Consolidated Statements of Retained Earnings for the
years ended December 31, 1996, 1995 and 1994 39
SIGCORP and SIGECO
Notes to Consolidated Financial Statements 40
2. Supplementary Information
SIGCORP and SIGECO
Selected Quarterly Financial Data 56
3. Supplemental Schedules
SIGCORP and SIGECO
Schedule II - Valuation and Qualifying Accounts and
Reserves for the years ended
December 31, 1996, 1995 and 1994 61
<FN>
All other schedules have been omitted as not applicable
or not required or because the information required to be
shown is included in the Consolidated Financial Statements
or the accompanying Notes to Consolidated Financial
Statements.
</FN>
</TABLE>
<PAGE> 25
REPORT OF INDEPENDENT PUBLIC
ACCOUNTANTS
TO SIGCORP, Inc.:
We have audited the consolidated balance sheets and
consolidated statements of capitalization of SIGCORP, Inc.
(an Indiana corporation) and subsidiaries as of December 31,
1996 and 1995, and the related consolidated statements of
income, retained earnings and cash flows for each of the
three years in the period ended December 31, 1996. These
financial statements and the supplemental schedule referred
to below are the responsibility of SIGCORP'S management.
Our responsibility is to express an opinion on these
financial statements and supplemental schedule 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 consolidated financial statements
referred to above present fairly, in all material respects,
the financial position of SIGCORP, Inc. as of December 31,
1996 and 1995, and the results of their operations and their
cash flows for each of the three years in the period ended
December 31, 1996, in conformity with generally accepted
accounting principles.
As discussed in Note 3, effective January 1, 1995,
SIGECO changed its method of accounting for unbilled
revenues.
Our audits were made for the purpose of forming an
opinion on the basic financial statements taken as a whole.
The supplemental schedule listed under Item 8 (3) is
presented for the purposes of complying with the Securities
and Exchange Commission's rules and is not part of the basic
financial statements. This supplemental schedule has been
subjected to the auditing procedures applied in the audits
of the basic financial statements and, in our opinion,
fairly states in all material respects the financial data
required to be set forth therein in relation to the basic
financial statements taken as a whole.
ARTHUR ANDERSEN LLP
Chicago, Illinois
January 24, 1997
<PAGE> 26
SIGCORP, Inc. and
Subsidiaries
<PAGE> 27
<TABLE>
SIGCORP, Inc.
<CAPTION>
CONSOLIDATED STATEMENTS OF INCOME
Year Ended December 31
in thousands except for
per share amounts) 1996 1995 1994
<S> <C> <C> <C>
OPERATING REVENUES:
Electric $276,479 $275,495 $260,936
Gas 96,251 63,203 69,099
Total operating revenues 372,730 338,698 330,035
OPERATING EXPENSES:
Fuel for electric generation 74,860 81,236 83,382
Purchased electric energy 8,295 9,332 5,489
Cost of gas sold 66,105 40,303 42,319
Other operation expenses 56,188 50,712 48,911
Maintenance 29,641 32,158 30,355
Depreciation and amortization 38,617 39,302 37,705
Federal and state income taxes 24,034 18,093 19,302
Property and other taxes 13,949 13,689 10,205
Total operating expenses 311,689 284,825 277,668
OPERATING INCOME 61,041 53,873 52,367
OTHER INCOME:
Allowance for other funds used
during construction - 380 3,972
Interest 1,824 1,213 988
Other, net 2,523 4,914 2,685
Total other income 4,347 6,507 7,645
INCOME BEFORE INTEREST
AND OTHER CHARGES 65,388 60,380 60,012
INTEREST AND OTHER CHARGES:
Interest on long-term debt 18,432 18,789 18,604
Amortization of premium, discount,
and expense on debt 690 694 852
Other interest 2,350 1,894 1,589
Allowance for borrowed funds used
during construction (445) (621) (2,058)
Preferred dividend requirements
of subsidiary 1,097 1,099 1,105
Total interest and other charges 22,124 21,855 20,092
NET INCOME BEFORE CUMULATIVE EFFECT
OF ACCOUNTING CHANGE 43,264 38,525 39,920
Cumulative Effect at January 1, 1995 of
adopting the unbilled revenues method
of accounting - net of Income Taxes - 6,294 -
NET INCOME $ 43,264 $44,819 $39,920
AVERAGE COMMON SHARES OUTSTANDING 15,755 15,755 15,755
EARNINGS PER SHARE OF COMMON STOCK
BEFORE CUMULATIVE EFFECT OF
ACCOUNTING CHANGE $2.75 $2.44 $2.53
CUMULATIVE EFFECT OF ACCOUNTING CHANGE - 0.40 -
TOTAL EARNINGS PER SHARE OF
COMMON STOCK $2.75 $2.84 $2.53
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 28
<TABLE>
<CAPTION>
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31 (in thousands) 1996 1995 1994
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 43,264 $ 44,819 $ 39,920
Adjustments to reconcile net income
to net cash provided by operating
activities:
Depreciation and amortization 38,617 39,302 37,705
Preferred dividend requirements
of subsidiary 1,097 1,099 1,105
Deferred income taxes and
investment tax credits, net 11,474 9,516 (1,613)
Allowance for other funds used
during construction - (380) (3,972)
Cumulative effect of accounting
change - (6,294) -
Change in assets and liabilities:
Receivables, net (including
accrued unbilled revenues) (17,170) (22,167) 2,959
Inventories 3,721 11,479 (8,251)
Coal contract settlement 12,928 (5,243) 5,610
Accounts payable (4,396) 2,813 1,244
Accrued taxes (1,098) 1,972 (1,092)
Refunds from gas suppliers (1,213) 2,037 1,755
Refunds to customers (4,961) (7,348) 10,285
Accrued coal liability - (22,018) 13,269
Other assets and liabilities 5,117 (1,707) 3,638
Net cash provided by operating
activities 87,380 47,880 102,562
CASH FLOWS FROM INVESTING ACTIVITIES
Construction expenditures (net of
allowance for other funds used
during construction) (40,302) (44,709) (76,660)
Demand side management
program expenditures (3,633) (9,051) (4,119)
Investments in leveraged leases (6,850) - -
Purchases of investments - (2,034) (5,989)
Sales of investments 700 4,211 7,258
Investments in partnerships 126 (901) (1,582)
Change in nonutility property 395 2,316 (1,497)
Change in notes receivable (11,533) (1,138) (1,425)
Other 442 4,941 2,018
Net cash used in investing
activities (60,655) (46,365) (81,996)
CASH FLOWS FROM FINANCING ACTIVITIES
First mortgage bonds (8,000) (5,300) (105)
Dividends paid (28,353) (27,725) (27,060)
Reduction in preferred stock - (91) -
Change in environmental improvement
funds held by trustee (188) 6,884 12,087
Payments on partnership obligations (2,787) (3,256) (3,849)
Change in notes payable 11,432 9,127 11,149
Other 528 620 540
Net cash used in financing
activities (27,368) (19,741) (7,238)
NET (DECREASE) INCREASE IN CASH AND
CASH EQUIVALENTS (643) (18,226) 13,328
CASH AND CASH EQUIVALENTS AT
BEGINNING OF PERIOD 9,834 28,060 14,732
CASH AND CASH EQUIVALENTS
AT END OF PERIOD $ 9,191 $ 9,834 $ 28,060
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 29
<TABLE>
<CAPTION>
CONSOLIDATED BALANCE SHEETS
At December 31 (in thousands) 1996 1995
<S> <C> <C>
ASSETS
UTILITY PLANT, at original cost:
Electric $1,047,717 $1,030,890
Gas 131,796 125,053
1,179,513 1,155,943
Less accumulated provision for depreciation 524,104 490,326
655,409 665,617
Construction work in progress 25,849 13,750
Net utility plant 681,258 679,367
OTHER INVESTMENTS AND PROPERTY:
Investments in leveraged leases 42,887 35,609
Investments in partnerships 23,983 25,308
Environmental improvement funds
held by trustee 3,830 3,642
Nonutility property and other 22,743 11,605
Total other investments and property 93,443 76,164
CURRENT ASSETS:
Cash and cash equivalents 9,191 9,834
Temporary investments, at market 565 1,148
Receivables, less allowance of $215
and $138, respectively 36,469 35,392
Accrued unbilled revenues 34,744 18,651
Inventories 31,241 34,962
Coal contract settlement - 12,928
Other current assets 16,310 4,795
Total current assets 128,520 117,710
DEFERRED CHARGES:
Unamortized premium on reacquired debt 5,663 6,142
Postretirement benefits other than pensions 7,819 9,574
Demand side management program 23,359 20,337
Other deferred charges 12,591 14,687
Total deferred charges 49,432 50,740
TOTAL $ 952,653 $ 923,981
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 30
<TABLE>
<CAPTION>
At December 31 (in thousands) 1996 1995
<S> <C> <C>
SHAREHOLDERS' EQUITY AND LIABILITIES
CAPITALIZATION:
Common Stock $ 78,258 $ 78,258
Retained Earnings 252,626 236,617
Total common shareholders' equity 330,884 314,875
Cumulative Nonredeemable Preferred
Stock of Subsidiary 11,090 11,090
Cumulative Redeemable Preferred
Stock of Subsidiary 7,500 7,500
Cumulative Special Preferred
Stock of Subsidiary 924 924
Long-Term Debt, net of current maturities 261,629 257,440
Long-Term Partnership Obligations,
net of current maturities 4,563 6,839
Total capitalization, excluding bonds
subject to tender (see Consolidated
Statements of Capitalization) 616,590 598,668
CURRENT LIABILITIES:
Current Portion of Adjustable Rate
Bonds Subject to Tender 31,500 31,500
Current Maturities of Long-Term Debt,
Interim Financing and Long-Term
Partnership Obligations:
Maturing long-term debt 659 9,906
Notes payable 38,750 30,500
Partnership obligations 2,276 2,786
Total current maturities of long-term debt,
interim financing and long-term
partnership obligations 41,685 43,192
Other Current Liabilities:
Accounts payable 33,600 37,996
Dividends payable 123 123
Accrued taxes 7,723 8,821
Accrued interest 4,585 4,577
Refunds to customers 2,722 8,896
Other accrued liabilities 31,138 17,689
Total other current liabilities 79,891 78,102
Total current liabilities 153,076 152,794
DEFERRED CREDITS AND OTHER:
Accumulated deferred income taxes 147,070 132,793
Accumulated deferred investment tax credits,
being amortized over lives of property 21,706 23,146
Regulatory income tax liability 1,614 2,977
Postretirement benefits other than pensions 10,084 9,056
Other 2,513 4,547
Total deferred credits and other 182,987 172,519
TOTAL $952,653 $923,981
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 31
<TABLE>
<CAPTION>
CONSOLIDATED STATEMENTS OF CAPITALIZATION
At December 31 (in thousands) 1996 1995
<S> <C> <C>
COMMON SHAREHOLDERS' EQUITY
Common Stock, without par value, authorized
50,000,000 shares, issued 15,754,826 $ 78,258 $ 78,258
Retained Earnings, $2,194,121 restricted as
to payment of cash dividends on common stock 252,626 236,617
Total common shareholders' equity 330,884 314,875
PREFERRED STOCK OF SUBSIDIARY
Cumulative, $100 par value, authorized 800,000
shares, issuable in series:
Nonredeemable
4.8% Series, outstanding 85,895 shares,
callable at $110 per share 8,590 8,590
4.75% Series, outstanding 25,000 shares,
callable at $101 per share 2,500 2,500
Total nonredeemable preferred stock
of subsidiary 11,090 11,090
Redeemable
6.50% Series, outstanding 75,000 shares,
redeemable at $100 per share December 1, 2002 7,500 7,500
SPECIAL PREFERRED STOCK OF SUBSIDIARY
Cumulative, no par value, authorized 5,000,000
shares, issuable in series: 8-1/2% series, outstanding
9,237 shares redeemable at $100 per share 924 924
LONG-TERM DEBT, NET OF CURRENT MATURITIES
First mortgage bonds 251,115 251,410
Notes payable 11,273 6,836
Unamortized debt premium and discount, net (759) (806)
Total long-term debt 261,629 257,440
LONG-TERM PARTNERSHIP OBLIGATIONS,
NET OF CURRENT MATURITIES 4,563 6,839
CURRENT PORTION OF ADJUSTABLE RATE POLLUTION
CONTROL BONDS SUBJECT TO TENDER, DUE
2015, Series B, presently 4.60% 31,500 31,500
TOTAL CAPITALIZATION, including bonds
subject to tender $648,090 $630,168
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 32
<TABLE>
<CAPTION>
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS
Year Ended December 31 (in thousands) 1996 1995 1994
<S> <C> <C> <C>
Balance, January 1 $236,617 $218,424 $204,449
Net income 43,264 44,819 39,920
279,881 263,243 244,369
Common Stock Dividends ($1.73 per share
in 1996, $1.69 per share in 1995 and
$1.65 per share in 1994) 27,255 26,626 25,955
Capital Stock Expenses - - (10)
27,255 26,626 25,945
Balance, December 31 (See Consolidated
Statements of Capitalization
for restriction) $252,626 $236,617 $218,424
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 33
Southern Indiana Gas
And Electric Company
<PAGE> 34
<TABLE>
<CAPTION>
SOUTHERN INDIANA GAS AND ELECTRIC COMPANY
CONSOLIDATED STATEMENTS OF INCOME
Year Ended December 31 (in thousands
except for per share amounts) 1996 1995 1994
<S> <C> <C> <C>
OPERATING REVENUES
Electric $276,479 $275,495 $260,936
Gas 96,251 63,203 69,099
Total operating revenues 372,730 338,698 330,035
OPERATING EXPENSES:
Fuel for electric generation 74,860 81,236 83,382
Purchased electric energy 8,295 9,332 5,489
Cost of gas sold 66,105 40,303 42,319
Other operation expenses 56,188 50,712 48,911
Maintenance 29,641 32,158 30,355
Depreciation and amortization 38,617 39,302 37,705
Federal and state income taxes 24,034 18,093 19,302
Property and other taxes 13,949 13,689 10,205
Total operating expenses 311,689 284,825 277,668
OPERATING INCOME 61,041 53,873 52,367
OTHER INCOME:
Allowance for other funds used
during construction - 380 3,972
Interest 1,824 1,213 988
Other, net 1,003 4,914 2,685
Total other income 2,827 6,507 7,645
INCOME BEFORE INTEREST AND OTHER CHARGES 63,868 60,380 60,012
INTEREST AND OTHER CHARGES:
Interest on long-term debt 18,432 18,789 18,604
Amortization of premium, discount,
and expense on debt 690 694 852
Other interest 2,350 1,894 1,589
Allowance for borrowed funds used
during construction (445) (621) (2,058)
Total interest and other charges 21,027 20,756 18,987
NET INCOME BEFORE CUMULATIVE EFFECT
OF ACCOUNTING CHANGE 42,841 39,624 41,025
Cumulative Effect at January 1, 1995
of Adopting the Unbilled
Revenues Method of Accounting -
Net of Income Taxes - 6,294 -
NET INCOME 42,841 45,918 41,025
Preferred Stock Dividends 1,097 1,099 1,105
NET INCOME APPLICABLE TO COMMON STOCK $ 41,744 $ 44,819 $ 39,920
AVERAGE COMMON SHARES OUTSTANDING 15,755 15,755 15,755
EARNINGS PER SHARE OF COMMON STOCK
BEFORE CUMULATIVE EFFECT OF
ACCOUNTING CHANGE $2.65 $2.44 $2.53
CUMULATIVE EFFECT OF ACCOUNTING
CHANGE - 0.40 -
TOTAL EARNINGS PER SHARE
OF COMMON STOCK $2.65 $2.84 $2.53
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 35
<TABLE>
<CAPTION>
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31 (in thousands) 1996 1995 1994
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 42,841 $ 45,918 $ 41,025
Adjustments to reconcile net income
to net cash provided by operating activities:
Depreciation and amortization 38,617 39,302 37,705
Deferred income taxes and
investment tax credits, net 10,558 9,516 (1,613)
Allowance for other funds used
during construction - (380) (3,972)
Cumulative effect of accounting
change - (6,294) -
Change in assets and liabilities:
Receivables, net (including
accrued unbilled revenues) (18,128) (22,167) 2,959
Inventories 3,772 11,479 (8,251)
Coal contract settlement 12,928 (5,243) 5,610
Accounts payable (4,882) 2,813 1,244
Accrued taxes (1,682) 1,972 (1,092)
Refunds from gas suppliers (1,213) 2,037 1,755
Refunds to customers (4,961) (7,348) 10,285
Accrued coal liability - (22,018) 13,269
Other assets and liabilities 5,194 (1,707) 3,638
Net cash provided by operating
activities 83,044 47,880 102,562
CASH FLOWS FROM INVESTING ACTIVITIES
Construction expenditures (net of
allowance for other funds used
during construction) (40,302) (44,709) (76,660)
Demand side management program
expenditures (3,633) (9,051) (4,119)
Investments in leveraged leases - - -
Purchases of investments - (2,034) (5,989)
Sales of investments - 4,211 7,258
Investments in partnerships - (901) (1,582)
Change in nonutility property 648 2,316 (1,497)
Change in notes receivable - (1,138) (1,425)
Other (211) 4,941 2,018
Net cash used in investing
activities (43,498) (46,365) (81,996)
CASH FLOWS FROM FINANCING ACTIVITIES
First mortgage bonds (8,000) (5,300) (105)
Dividends paid (28,353) (27,725) (27,060)
Reduction in preferred stock - (91) -
Change in environmental improvement
funds held by trustee (188) 6,884 12,087
Payments on partnership obligations - (3,256) (3,849)
Change in notes payable 1,900 9,127 11,149
Contribution of nonregulated
subsidiaries to parent (12,145) - -
Other 533 620 540
Net cash used in financing
activities (46,253) (19,741) (7,238)
NET (DECREASE) INCREASE IN CASH AND
CASH EQUIVALENTS (6,707) (18,226) 13,328
CASH AND CASH EQUIVALENTS AT
BEGINNING OF PERIOD 9,834 28,060 14,732
CASH AND CASH EQUIVALENTS
AT END OF PERIOD $ 3,127 $ 9,834 $ 28,060
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 36
<TABLE>
<CAPTION>
CONSOLIDATED BALANCE SHEETS
At December 31 (in thousands) 1996 1995
<S> <C> <C>
ASSETS
UTILITY PLANT, at original cost:
Electric $1,047,717 $1,030,890
Gas 131,796 125,053
1,179,513 1,155,943
Less accumulated provision
for depreciation 524,104 490,326
655,409 665,617
Construction work in progress 25,849 13,750
Net utility plant 681,258 679,367
OTHER INVESTMENTS AND PROPERTY:
Investments in leveraged leases - 35,609
Investments in partnerships - 25,308
Environmental improvement funds
held by trustee 3,830 3,642
Nonutility property and other 1,552 11,605
Total other investments and property 5,382 76,164
CURRENT ASSETS:
Cash and cash equivalents 3,127 9,834
Temporary investments, at market - 1,148
Receivables, less allowance of $215
and $138, respectively 32,491 35,392
Accrued unbilled revenues 34,744 18,651
Inventories 31,190 34,962
Coal contract settlement - 12,928
Other current assets 15,304 4,795
Total current assets 116,856 117,710
DEFERRED CHARGES:
Unamortized premium on reacquired debt 5,663 6,142
Postretirement benefits other
than pensions 7,818 9,574
Demand side management program 23,359 20,337
Other deferred charges 11,989 14,687
Total deferred charges 48,829 50,740
TOTAL $ 852,325 $ 923,981
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 37
<TABLE>
<CAPTION>
At December 31 (in thousands) 1996 1995
<S> <C> <C>
SHAREHOLDERS' EQUITY AND LIABILITIES
CAPITALIZATION:
Common Stock $ 78,258 $ 78,258
Retained Earnings 213,688 236,617
Total common shareholders' equity 291,946 314,875
Cumulative Nonredeemable Preferred
Stock of Subsidiary 11,090 11,090
Cumulative Redeemable Preferred
Stock of Subsidiary 7,500 7,500
Cumulative Special Preferred
Stock of Subsidiary 924 924
Long-Term Debt, net of current maturities 251,355 257,440
Long-Term Partnership Obligations,
net of current maturities - 6,839
Total capitalization, excluding bonds
subject to tender (see Consolidated
Statements of Capitalization) 562,815 598,668
CURRENT LIABILITIES:
Current Portion of Adjustable Rate Bonds
Subject to Tender 31,500 31,500
Current Maturities of Long-Term Debt,
Interim Financing and Long-Term
Partnership Obligations:
Maturing long-term debt 295 9,906
Notes payable 32,400 30,500
Partnership obligations - 2,786
Total current maturities of long-term
debt, interim financing and long-term
partnership obligations 32,695 43,192
Other Current Liabilities:
Accounts payable 27,338 37,996
Dividends payable 123 123
Accrued taxes 8,713 8,821
Accrued interest 4,572 4,577
Refunds to customers 2,722 8,896
Other accrued liabilities 29,650 17,689
Total other current liabilities 73,118 78,102
Total current liabilities 137,313 152,794
DEFERRED CREDITS AND OTHER:
Accumulated deferred income taxes 116,373 132,793
Accumulated deferred investment tax
credits, being amortized over lives
of property 21,706 23,146
Regulatory income tax liability 1,613 2,977
Postretirement benefits other than
pensions 10,084 9,056
Other 2,421 4,547
Total deferred credits and other 152,197 172,519
TOTAL $852,325 $923,981
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 38
<TABLE>
<CAPTION>
CONSOLIDATED STATEMENTS OF CAPITALIZATION
At December 31 (in thousands) 1996 1995
<S> <C> <C>
COMMON SHAREHOLDERS' EQUITY
Common Stock, without par value, authorized
50,000,000 shares, issued 15,754,826 $ 78,258 $ 78,258
Retained Earnings, $2,194,121 restricted as
to payment of cash dividends on common stock 213,688 236,617
Total common shareholders' equity 291,946 314,875
PREFERRED STOCK OF SUBSIDIARY
Cumulative, $100 par value, authorized
800,000 shares, issuable in series:
Nonredeemable
4.8% Series, outstanding 85,895 shares,
callable at $110 per share 8,590 8,590
4.75% Series, outstanding 25,000 shares,
callable at $101 per share 2,500 2,500
Total nonredeemable preferred
stock of subsidiary 11,090 11,090
Redeemable
6.50% Series, outstanding 75,000 shares,
redeemable at $100 per share
December 1, 2002 7,500 7,500
SPECIAL PREFERRED STOCK OF SUBSIDIARY
Cumulative, no par value, authorized
5,000,000 shares, issuable in series:
8-1/2% series, outstanding 9,237 shares
redeemable at $100 per share 924 924
LONG-TERM DEBT, NET OF CURRENT MATURITIES
First mortgage bonds 251,114 251,410
Notes payable 1,000 6,836
Unamortized debt premium and discount, net (759) (806)
Total long-term debt 251,355 257,440
LONG-TERM PARTNERSHIP OBLIGATIONS,
NET OF CURRENT MATURITIES - 6,839
CURRENT PORTION OF ADJUSTABLE RATE POLLUTION
CONTROL BONDS SUBJECT TO TENDER, DUE
2015, Series B, presently 4.60% 31,500 31,500
TOTAL CAPITALIZATION, including bonds
subject to tender $594,315 $630,168
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 39
<TABLE>
<CAPTION>
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS
Year Ended December 31 (in thousands) 1996 1995 1994
<S> <C> <C> <C>
Balance, January 1 $236,617 $218,424 $204,449
Net income 42,841 45,918 41,025
279,458 264,342 245,474
Dividend Nonregulated Subsidiaries
to Parent 37,418 - -
Preferred Stock Dividends 1,097 1,099 1,105
Common Stock Dividends ($1.73 per share
in 1996, $1.69 per share in 1995 and
$1.65 per share in 1994) 27,255 26,626 25,955
Capital Stock Expenses - - (10)
65,770 27,725 27,050
Balance, December 31 (See Consolidated
Statements of Capitalization
for restriction) $213,688 $236,617 $218,424
<FN>
The accompanying Notes to Consolidated Financial Statements are an integral
part of these statements.</FN>
</TABLE>
<PAGE> 40
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 Summary of Significant Accounting Policies
SIGCORP and SIGECO
PRINCIPLES OF CONSOLIDATION Effective January 1, 1996, a
new holding company, SIGCORP, Inc. (SIGCORP), became the
parent of Southern Indiana Gas and Electric Company
(SIGECO), a regulated gas and electric utility which
accounts for over 90% of SIGCORP's net income, and four of
SIGECO's former wholly-owned subsidiaries: Energy Systems
Group, Inc. (ESGI), Southern Indiana Minerals, Inc. (SIMI),
Southern Indiana Properties, Inc.(SIPI) and ComSource, Inc.
(ComSource). All of the shares of SIGECO's common stock
were exchanged on a one-for-one basis for shares of SIGCORP,
while all of SIGECO's debt securities and all of its
outstanding shares of preferred stock remain securities of
SIGECO and are unaffected. During the fourth quarter of
1996, four additional nonregulated subsidiaries were formed:
SIGCORP Energy Services, Inc. (Energy), SIGCORP Capital,
Inc. (Capital), SIGCORP Fuels, Inc. (Fuels) and SIGCORP
Power Marketing, Inc. (Power).
SIGECO is a regulated gas and electric utility and engaged
principally in the production, purchase, transmission,
distribution and sale of electricity and the delivery of
natural gas. SIGECO serves 122,195 electric customers in
the city of Evansville and 74 other communities and serves
106,237 gas customers in the city of Evansville and 64 other
communities.
ESGI provides equipment and related design services to
industrial and commercial customers. SIMI processes and
markets coal combustion by-products. SIPI invests
principally in partnerships (primarily in real estate),
leveraged leases and marketable securities. ComSource
markets telecommunications services. Energy, incorporated
in October 1996, was established to provide natural gas,
pipeline management, storage service and other natural gas-
related services to SIGECO and other customers. Capital,
also incorporated in October 1996, will be the primary
financing vehicle for SIGCORP's nonregulated subsidiaries.
Fuels, incorporated in December 1996, was formed to provide
coal supply procurement and related services, such as
transportation of coal, to SIGECO and other customers.
Power, incorporated in December 1996, was formed to procure
electric power supplies for SIGECO and other customers, and
will market SIGECO's excess electric generation capacity.
Because SIGECO is the principal subsidiary of SIGCORP, the
operating results of all nonregulated subsidiaries are
included in "Other, net" in the Consolidated Statements of
Income. All significant intercompany transactions are
eliminated.
USE OF ESTIMATES The preparation of financial statements in
conformity with generally accepted accounting principles
requires management to make estimates and assumptions that
affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date
of the financial statements and the reported amounts of
revenues and expenses during the reporting period. Actual
results could differ from those estimates.
REGULATION The Indiana Utility Regulatory Commission (IURC)
has jurisdiction over all investor-owned gas and electric
utilities in Indiana. The Federal Energy Regulatory
Commission (FERC) has jurisdiction over those investor-owned
utilities that make wholesale energy sales. These agencies
regulate SIGECO's utility business operations, rates,
accounts, depreciation allowances, services, security issues
and the sale and acquisition of properties. The financial
statements of SIGECO are based on generally accepted
accounting principles, which give recognition to the
ratemaking and accounting practices of these agencies.
REGULATORY ASSETS SIGECO is subject to the provisions of
Statement of Financial Accounting Standards (SFAS) No. 71,
"Accounting for the Effects of Certain Types of Regulation."
Regulatory assets represent probable future revenues to
SIGECO associated with certain incurred costs which will be
recovered from customers through the ratemaking process.
SIGECO adopted SFAS No. 121, "Accounting for the Impairment
of Long-Lived Assets and for Long-Lived Assets to be
Disposed Of ", on January 1, 1996. SFAS No. 121 requires
that impairment losses for long-lived assets and
identifiable intangibles to be held and used, be based on
the fair value of the asset. Long-lived assets and certain
identifiable intangibles to be disposed of should be
reported at the lower of carrying amount or fair value less
cost to sell. It also requires that regulatory assets which
are no longer probable of recovery through future
<PAGE> 41
revenues, at the balance sheet date, be charged to earnings.
Adoption of the new standard did not have a material impact
on financial position or results of operation. The
following regulatory assets are reflected in the
Consolidated Balance Sheets:
<TABLE>
<CAPTION>
At December 31 (in thousands) 1996 1995
<S> <C> <C>
Regulatory Assets:
Demand side management program costs $23,359 $20,337
Postretirement benefit costs (Note 1) 7,819 9,574
Coal contract buyout costs (Note 2) - 12,928
Unamortized premium on reacquired debt 5,663 6,142
FERC Order No. 636 transition costs (Note 2) - 3,000
Regulatory study costs 718 905
Fuel and gas costs (Note 1) 13,237 2,573
Total 50,796 55,459
Less current amounts 13,237 15,501
Total long-term regulatory assets $37,559 $39,958
</TABLE>
Refer to the individual footnotes referenced above for
discussion of specific regulatory assets. See Income Taxes
for regulatory assets and liabilities related to income
taxes.
As of December 31, 1996, $33,800,000 of SIGECO's total
regulatory assets are being reflected in rates charged to
customers over periods ranging from 5 to 28 years. SIGECO
intends to request recovery of its remaining regulatory
assets in a future general rate case filing.
If all or a separable portion of SIGECO's operation becomes
no longer subject to the provisions of SFAS No. 71, a write
off of related regulatory assets would be required, unless
some form of transition cost recovery continues through
rates established and collected for SIGECO's remaining
regulated operations. In addition, SIGECO would be required
to determine any impairment to the carrying costs of
deregulated plant and inventory assets.
CONCENTRATION OF CREDIT RISK SIGECO's customer receivables
from gas and electric sales and gas transportation services
are primarily derived from a broadly diversified base of
residential, commercial and industrial customers located in
a southwestern region of Indiana. SIGECO continually
reviews customers' creditworthiness and requests deposits or
refunds deposits based on that review. See Note 4 for a
discussion of receivables related to its leveraged lease
investments.
UTILITY PLANT Utility plant is stated at the historical
original cost of construction. The cost of repairs and
minor renewals is charged to maintenance expense as
incurred. Property unit replacements are capitalized and
the depreciation reserve is charged with the cost, less net
salvage, of units retired.
DEPRECIATION Depreciation of utility plant is provided
using the straight-line method over the estimated service
lives of the depreciable plant. Provisions for
depreciation, expressed as an annual percentage of the cost
of average depreciable plant in service, were as follows:
<TABLE>
<CAPTION>
1996 1995 1994
<S> <C> <C> <C>
Electric 3.4% 3.8% 4.0%
Gas 3.2% 3.3% 3.3%
</TABLE>
INCOME TAXES SIGCORP utilizes the liability method of
accounting for income taxes, providing deferred taxes on
temporary differences. Investment tax credits have been
deferred and are amortized through credits to income over
the lives of the related property.
<PAGE> 42
The components of the net deferred income tax liability are
as follows:
<TABLE>
<CAPTION>
SIGCORP, Inc.
At December 31 (in thousands) 1996 1995
<S> <C> <C>
Deferred Tax Liabilities:
Depreciation and cost recovery
timing differences $115,095 $109,899
Deferred fuel costs, net 4,778 204
Leveraged leases 30,702 29,747
Regulatory assets recoverable
through future rates 25,668 26,839
Deferred Tax Assets:
Unbilled revenue (2,499) (2,575)
Regulatory liabilities to be
settled through future rates (27,282) (29,817)
Other, net 608 (1,504)
Net deferred income tax liability $147,070 $132,793
</TABLE>
Of the $14,277,000 increase in SIGCORP's net deferred income
tax liability from December 31, 1995 to December 31, 1996,
$12,771,000 is due to current year deferred federal and
state income tax expense and the remaining $1,506,000
increase is primarily a result of the change in the net
regulatory assets and liabilities. The $16,420,000 decrease
in SIGECO's net deferred income tax liability from December
31, 1995 to December 31, 1996 is primarily the result of
dividending SIGECO's nonregulated subsidiaries to SIGCORP.
See the following "Cash Flow Information" for further
discussion.
<TABLE>
<CAPTION>
Southern Indiana Gas and Electric Company
At December 31 (in thousands) 1996 1995
<S> <C> <C>
Deferred Tax Liabilities:
Depreciation and cost recovery
timing differences $115,095 $109,899
Deferred fuel costs, net 4,778 204
Leveraged leases - 29,747
Regulatory assets recoverable
through future rates 25,668 26,839
Deferred Tax Assets:
Unbilled revenue (2,499) (2,575)
Regulatory liabilities to be
settled through future rates (27,282) (29,817)
Other, net 613 (1,504)
Net deferred income tax liability $116,373 $132,793
</TABLE>
<PAGE> 43
The components of current and deferred income tax expense
are as follows:
<TABLE>
SIGCORP, Inc.
<CAPTION>
Year Ended December 31 ( in thousands) 1996 1995 1994
<S> <C> <C> <C>
Current
Federal $11,773 $ 9,801 $19,739
State 1,934 1,861 2,722
Deferred, net
Federal 10,081 6,719 (1,451)
State 1,689 1,268 138
Investment tax credit, net (1,443) (1,556) (1,846)
Income tax expense as shown on
Consolidated Statements of Income 24,034 18,093 19,302
Current income tax expense included
in Other Income (3,072) (3,030) (4,685)
Deferred income tax expense
included in Other Income 1,001 1,169 1,547
Total income tax expense related
to net income before cumulative
effect of accounting change 21,963 16,232 16,164
Current income tax expense related
to cumulative effect of accounting change - 3,845 -
Total income tax expense $21,963 $20,077 $16,164
</TABLE>
<TABLE>
Southern Indiana Gas and Electric Company
<CAPTION>
Year Ended December 31 ( in thousands) 1996 1995 1994
<S> <C> <C> <C>
Current
Federal $11,773 $ 9,801 $19,739
State 1,934 1,861 2,722
Deferred, net
Federal 10,081 6,719 (1,451)
State 1,689 1,268 138
Investment tax credit, net (1,443) (1,556) (1,846)
Income tax expense as shown on
Consolidated Statements of Income 24,034 18,093 19,302
Current income tax expense included
in Other Income 606 (3,030) (4,685)
Deferred income tax expense
included in Other Income - 1,169 1,547
Total income tax expense related
to net income before
cumulative effect of accounting change 24,640 16,232 16,164
Current income tax expense related to
cumulative effect of accounting change - 3,845 -
Total income tax expense $24,640 $20,077 $16,164
</TABLE>
A reconciliation of the statutory tax rates to the effective
income tax rate is as follows:
<TABLE>
SIGCORP, Inc.
<CAPTION>
Year Ended December 31 1996 1995 1994
<S> <C> <C> <C>
Statutory federal and state rate 37.9% 37.9% 37.9%
Equity portion of allowance for funds
used during construction - (0.2) (2.7)
Book depreciation over related tax
depreciation - nondeferred 1.7 2.0 2.1
Amortization of deferred investment
tax credit (2.2) (2.4) (3.3)
Low-income housing credit (4.2) (4.3) (4.9)
Preferred dividend requirements
of subsidiary 0.6 0.6 0.8
Other, net (0.1) (2.7) (1.1)
Effective tax rate 33.7% 30.9% 28.8%
</TABLE>
<PAGE> 44
<TABLE>
Southern Indiana Gas and Electric Company
<CAPTION>
Year Ended December 31 1996 1995 1994
<S> <C> <C> <C>
Statutory federal and state rate 37.9% 37.9% 37.9%
Equity portion of allowance for funds
used during construction - (0.2) (2.7)
Book depreciation over related tax
depreciation - nondeferred 1.9 2.0 2.1
Amortization of deferred investment
tax credit (2.3) (2.4) (3.3)
Low-income housing credit - (4.3) (4.9)
Preferred dividend requirements
of subsidiary - 0.6 0.8
Other, net (1.0) (2.7) (1.1)
Effective tax rate 36.5% 30.9% 28.8%
</TABLE>
PENSION BENEFITS SIGECO has trusteed, noncontributory
defined benefit plans which cover eligible full-time regular
employees. The plans provide retirement benefits based on
years of service and the employee's highest 60 consecutive
months' compensation during the last 120 months of
employment. The funding policy of SIGECO is to contribute
amounts to the plans equal to at least the minimum funding
requirements of the Employee Retirement Income Security Act
of 1974 (ERISA) but not in excess of the maximum deductible
for federal income tax purposes. The plans' assets as of
December 31, 1996 consist of investments in interest-bearing
obligations and common stocks of 47% and 53%, respectively.
The components of net pension cost related to these plans
are as follows:
<TABLE>
<CAPTION>
Year Ended December 31 (in thousands) 1996 1995 1994
<S> <C> <C> <C>
Service cost - benefits earned
during the period $ 2,288 $ 1,700 $ 1,963
Interest cost on projected
benefit obligation 4,433 4,044 3,842
Actual return on plan assets (7,409) (12,243) (469)
Net amortization and deferral 2,379 8,000 (3,978)
Net pension cost charged to operations,
construction and other accounts $ 1,691 $ 1,501 $ 1,358
</TABLE>
The funded status of the trusteed retirement plans is as
follows:
<TABLE>
<CAPTION>
At December 31 (in thousands) 1996 1995
<S> <C> <C>
Actuarial present value of:
Vested benefit obligation $(49,098) $(49,401)
Accumulated benefit obligation $(50,461) $(49,694)
Projected benefit obligation $(63,999) $(63,531)
Plan assets at fair value 66,011 60,928
Excess (deficiency) of plan assets
over projected benefit obligation 2,012 (2,603)
Remaining unrecognized transitional asset (2,651) (3,069)
Prior service cost 1,560 449
Unrecognized net gain (loss) (5,797) 1,521
Accrued pension liability $ (4,876) $ (3,702)
</TABLE>
The projected benefit obligation at December 31, 1996 and
1995 was determined using an assumed discount rate
of 7%. For both periods, the long-term rate of compensation
increases was assumed to be 5%, and the long-term rate of
return on plan assets was assumed to be 8%. The
transitional asset is being amortized over approximately 15,
18 and 14 years for the Salaried, Hourly and Hoosier plans,
respectively.
In addition to the trusteed pension plans discussed above,
SIGECO provides supplemental pension benefits to certain
current and former officers under nonqualified and nonfunded
plans. Annual service cost related to these benefits is
approximately $240,000.
POSTRETIREMENT BENEFITS OTHER THAN PENSIONS SIGECO provides
certain postretirement health care and life insurance
benefits for retired employees and their dependents through
fully insured plans. SFAS No. 106, "Employers' Accounting
for Postretirement Benefits Other Than Pensions," requires
the expected cost of these benefits
<PAGE> 45
be recognized during the employees' years of service. As
authorized by the IURC, SIGECO deferred as a regulatory
asset the additional SFAS No. 106 costs accrued over the
costs of benefits actually paid after date of adoption, but
prior to inclusion in rates. In June 1995, the IURC
authorized SIGECO to include in electric rates SFAS No. 106
cost and to recover the amounts previously deferred over a
60-month period beginning June 1995. In July 1996, the IURC
authorized SIGECO to include in gas rates SFAS No. 106 cost
and to recover the amounts previously deferred over a 60-
month period beginning July 1996.
The components of the net periodic other postretirement
benefit cost are as follows:
<TABLE>
<CAPTION>
Year Ended December 31
(in thousands of dollars) 1996 1995 1994
<S> <C> <C> <C>
Service cost - benefits earned
during the period $ 925 $ 903 $1,133
Interest cost on accumulated
benefit obligation 2,028 2,272 2,404
Actual return on assets (292) (107) -
Net amortization and deferral 1,267 1,259 1,472
Net periodic postretirement benefit cost 3,928 4,327 5,009
Amortization of prior years' deferred
postretirement benefit obligation 2,569 549 -
6,497 4,876 5,009
Deferred postretirement benefit obligation 314 2,112 3,886
Total charged to operations,
construction and other accounts $6,183 $2,764 $1,123
</TABLE>
The net periodic cost determined under the new standard
includes the amortization of the discounted present value of
the obligation at the adoption date, $29,400,000, over a 20-
year period.
Reconciliation of the accumulated postretirement benefit
obligation to the accrued liability for postretirement
benefits is as follows:
<TABLE>
<CAPTION>
At December 31 (in thousands) 1996 1995
<S> <C> <C>
Accumulated other postretirement benefit obligation:
Retirees $(10,041) $(10,775)
Other fully eligible participants (5,916) (5,893)
Other active participants (13,317) (13,944)
Total accumulated benefit obligation (29,274) (30,612)
Plan assets at fair value 5,205 2,658
Excess of accumulated benefit obligation
over plan assets (24,069) (27,954)
Unrecognized transition obligation 23,547 25,019
Unrecognized net gain (9,562) (6,121)
Accrued postretirement benefit liability $(10,084) $ (9,056)
</TABLE>
The assumptions used to develop the accumulated
postretirement benefit obligation at December 31, 1996 and
1995 included a discount rate of 7.25% and a health care
cost trend rate of 9% declining to 5% in 2004. The
estimated cost of these future benefits could be
significantly affected by future changes in health care
costs, work force demographics, interest rates or plan
changes. A 1% increase in the assumed health care cost
trend rate each year would increase the aggregate service
and interest costs for 1996 by $560,000 and the accumulated
postretirement benefit obligation by $5,000,000.
In 1995, SIGECO adopted Voluntary Employee Beneficiary
Association (VEBA) Trust Agreements for the funding of
postretirement health benefits for retirees and their
eligible dependents and beneficiaries. Annual funding is
discretionary and is based on the projected cost over time
of benefits to be provided to covered persons consistent
with acceptable actuarial methods. To the extent these
postretirement benefits are funded, the benefits will not be
shown as a liability on SIGECO's financial statements.
CASH FLOW INFORMATION For the purposes of the Consolidated
Balance Sheets and the Consolidated Statements of Cash
Flows, SIGCORP considers all highly liquid debt instruments
purchased with an original maturity of three months or less
to be cash equivalents.
<PAGE> 46
During 1996, 1995 and 1994, SIGCORP paid interest (net of
amounts capitalized) of $20,328,000, $20,085,000 and
$18,053,000, respectively, and income taxes of $12,237,000,
$10,334,000 and $15,447,000, respectively. SIGCORP is
involved in several partnerships which are partially
financed by partnership obligations amounting to $6,839,000
and $9,625,000 at December 31, 1996 and 1995, respectively.
During 1996, 1995 and 1994, SIGECO paid interest (net of
amounts capitalized) of $19,591,000, $20,085,000 and
$18,053,000, respectively, and income taxes of $15,746,000,
$10,334,000 and $15,447,000, respectively.
The following decreases in SIGECO's assets and liabilities
were caused by dividending the nonregulated subsidiaries to
SIGCORP and are noncash in nature.
Deferred income taxes (29,783)
Investments in Leveraged Leases (35,609)
Investments in Partnerships (25,307)
Partnership obligations (9,625)
Other, net (3,771)
INVENTORIES SIGECO accounts for inventories under the
average cost method except for gas in underground storage
which is accounted for under the last-in, first-out (LIFO)
method. Effective January 1, 1996, SIGECO's Hoosier
Division changed from the average cost to the last-in,
first-out method of valuing gas in underground storage.
This change had an immaterial effect on financial
statements. Inventories are as follows:
<TABLE>
<caption
At December 31 (in thousands) 1996 1995
<S> <C> <C>
Fuel (coal and oil) for electric generation $ 6,539 $11,163
Materials and supplies 15,614 15,422
Gas in underground storage - at LIFO cost 9,088 5,822
- at average cost - 2,555
Total inventories $31,241 $34,962
</TABLE>
Based on the December 1996 price of gas purchased, the cost
of replacing the current portion of gas in underground
storage at December 31, 1996 exceeded the amount stated on a
LIFO basis by approximately $23,000,000.
OPERATING REVENUES AND FUEL COSTS SIGECO accrues an
estimate of revenues unbilled for electric and gas service
furnished from the meter reading dates to the end of each
accounting period.
All metered gas rates contain a gas cost adjustment clause
which allows for adjustment in charges for changes in the
cost of purchased gas. The calculation of the adjustment
factor is based on the estimated cost of gas in a future
quarter, and provides that any under- or overrecovery caused
by variances between estimated and actual cost in a given
quarter, as well as refunds from its pipeline suppliers,
will be included in adjustment factors of four future
quarters beginning with the second succeeding quarter's
adjustment factor.
All metered electric rates contain a fuel adjustment clause
which allows for adjustment in charges for electric energy
to reflect changes in the cost of fuel and the net energy
cost of purchased power. The calculation of the adjustment
factor is based on the estimated cost of fuel and the net
energy cost of purchased power in a future quarter, and
provides that any under- or overrecovery caused by variances
between estimated and actual cost in a given quarter will be
included in the second succeeding quarter's adjustment
factor.
SIGECO also collects through a quarterly rate adjustment
mechanism, the margin on electric sales lost due to the
implementation of demand side management programs.
SIGECO records monthly any adjustment clause under- or
overrecovery as an asset or liability, respectively, until
such time as it is billed or refunded to its customers. The
IURC reviews for approval the adjustment clause factors on a
quarterly basis.
<PAGE> 47
The cost of gas sold is charged to operating expense as
delivered to customers and the cost of fuel for electric
generation is charged to operating expense when consumed.
Note 2 Rate and Regulatory Matters
SIGCORP and SIGECO
GAS MATTERS On September 7, 1995, SIGECO petitioned the
IURC seeking a general increase in gas rates. The requested
adjustment in rates, over those granted in 1993, is
necessary to recover increases in operating and maintenance
costs and additional investment in gas distribution
facilities. The adjustment included recovery of additional
costs incurred for postretirement benefits other than
pensions related to gas operations approximating $1.1
million annually beginning in 1993 which had been deferred
pending inclusion in rates. The petition also requested the
merger into SIGECO of its Lincoln Natural Gas Company
subsidiary (LNG) and the consolidation of gas rates for
customers of SIGECO's Evansville and Hoosier divisions and
of LNG into one set of rates. On July 3, 1996, the IURC
issued its order, effective July 15, 1996, granting a 7.3%,
or $4.8 million, increase in annual revenues.
In 1992, FERC issued Order No. 636 which required interstate
pipelines to restructure their services by unbundling
pipeline sales service so that gas supplies are sold
separately from interstate transportation services. FERC
authorized the pipelines to seek recovery of certain
transition costs associated with the restructuring from
their customers. SIGECO's total transition costs will
approximate $4.2 million. Through 1995, SIGECO was billed
$3 million of these transition costs by its former major
pipeline supplier, Texas Gas Transmission Corporation, $1.8
million of which it deferred pending authorization by the
IURC of recovery of such costs. During 1996, SIGECO was
billed an additional $.6 million of these costs. On
November 2, 1995, the IURC approved SIGECO's request for
recovery of transition costs through the gas cost adjustment
and, during 1996, SIGECO recovered all previously deferred
costs.
ELECTRIC MATTERS On June 21, 1995, the IURC approved the
third of three planned general electric rate increases
related to SIGECO's Clean Air Act Compliance project
(primarily the addition of a sulfur dioxide scrubber to
serve Culley Units 2 and 3), which began commercial
operation February 1995 . The third adjustment also covered
certain nonscrubber-related operating costs such as
additional costs incurred for postretirement benefits other
than pensions beginning in 1993, and the recovery of demand
side management program expenditures. The effective dates
and impact on annual electric revenues of the three
adjustments are summarized below:
<TABLE>
<CAPTION>
Additional
Effective Annual Revenue
Date Revenues Increase
<S> <C> <C> <C>
Adjustment 1 October 1, 1993 $1.8 million 1.0%
Adjustment 2 June 29, 1994 4.2 million 2.3
Adjustment 3 June 26, 1995 4.5 million 2.1
</TABLE>
Over the past several years, SIGECO has been actively
involved in intensive contract negotiations and legal
actions to reduce its coal costs and thereby lower its
electric rates. During 1992, SIGECO was successful in
negotiating a new coal supply contract with one of its major
coal suppliers effective through 1995. Included in the
agreement was a provision whereby the contract could be
reopened by SIGECO for modification of certain coal
specifications. In early 1993, SIGECO reopened the contract
for such modifications. In response, the coal supplier
elected to terminate the contract enabling SIGECO to buy out
the remainder of its contractual obligations and acquire
lower-priced spot market coal. The cost of the contract
buyout totaled approximately $18.6 million. The IURC
approved SIGECO's request to amortize all buyout costs to
coal inventory during the period July 1, 1993 through
December 31, 1995 and to recover such costs through the fuel
adjustment clause beginning February 1994. SIGECO estimates
the total savings in coal costs during the 1991-1995 period
resulting from the renegotiation and subsequent buyout, net
of the total buyout costs, approximated $59 million. The
net savings were passed back to SIGECO's electric customers
through the fuel adjustment clause.
On April 10, 1995, SIGECO reached an agreement with its
remaining long-term contract coal supplier, effective July
16, 1995, to buy out the remainder of SIGECO's contractual
obligations for $45.5 million, enabling it to
<PAGE> 48
acquire lower-priced spot market coal. SIGECO had been in
litigation with this coal supplier for several years. Under
the terms of the original contract, SIGECO was allegedly
obligated to take a minimum of 600,000 tons of coal
annually. In early 1993, SIGECO informed the supplier that
it would not require shipments under the contract until
later in 1993. On March 26, 1993, SIGECO and the supplier
agreed to resume coal shipments under the terms of a letter
agreement which were effective until final resolution of the
litigation. Under the letter agreement, the invoiced price
per ton was substantially lower than the contract price. As
approved by the IURC, SIGECO charged the full contract price
to coal inventory for recovery through the fuel adjustment
clause. The difference between the contract price and the
invoice price, $28.9 million at July 15, 1995, was deposited
in an escrow account and subsequently applied to the buyout
premium. The remaining buyout costs, about $16.6 million,
were amortized to coal inventory over a 14-month period
ending September 1996 and will be fully recovered through
the fuel adjustment clause by mid-1997. SIGECO estimates
the total savings in coal costs resulting from the buyout,
net of total buyout costs, will approximate $58 million
through December 31, 1998, the term of the original
contract. The net savings are being passed back to SIGECO's
electric customers through the fuel adjustment clause. All
issues in litigation were dismissed as a condition of the
settlement agreement, and all other interim agreements with
this coal supplier were terminated as of July 16, 1995.
Note 3 Revenues Accounting Change
SIGCORP and SIGECO
SIGECO previously recognized electric and gas revenues when
customers were billed on a cycle billing basis. The utility
service rendered after monthly meter reading dates through
the end of a calendar month (unbilled revenues) became a
part of operating revenues in the following month. To more
closely match revenues with expenses, effective January 1,
1995, SIGECO changed its method of accounting to accrue the
amount of revenue for sales unbilled at the end of each
month. The cumulative effect of the change on prior years,
net of income taxes, is included in net income for 1995.
The effect of the change was to increase 1995 net income
$7.9 million ($.50 per share), of which an increase of $1.6
million ($.10 per share), was reflected in operations and an
increase of $6.3 million ($.40 per share), the cumulative
effect of the change as of January 1, 1995, was reported as
a separate component of net income.
Summarized below is the pro forma effect of the accounting
change, as if the change had been effective during the
periods:
<TABLE>
<CAPTION>
Year Ending December 31
(in thousands except per share amounts)
1995 1994
<S> <C> <C>
As Reported
Operating Revenues
Electric $275,495 $260,936
Gas 63,203 69,099
Total $338,698 $330,035
Operating Income $ 53,873 $ 52,367
Net Income $ 44,819 $ 39,920
Earnings Per Share of Common Stock $ 2.84 $ 2.53
Pro Forma
Operating Revenues
Electric $275,495 $261,103
Gas 63,203 67,900
Total $338,698 $329,003
Operating Income $ 53,873 $ 51,717
Net Income $ 38,525 $ 39,270
Earnings Per Share of Common Stock $ 2.44 $ 2.49
</TABLE>
<PAGE> 49
Note 4 Leveraged Leases
SIGCORP
Southern Indiana Properties, Inc. is a lessor in five
leveraged lease agreements under which an office building, a
part of a reservoir, an interest in a paper mill, a gas
turbine electric generating peaking unit and passenger
railroad cars are leased to third parties. The economic
lives and lease terms vary with the leases. The total
equipment and facilities cost was approximately $110,800,000
and $101,200,000 at December 31, 1996 and 1995,
respectively. The cost of the equipment and facilities was
partially financed by nonrecourse debt provided by lenders,
who have been granted an assignment of rentals due under the
leases and a security interest in the leased property, which
they accepted as their sole remedy in the event of default
by the lessee. Such debt amounted to approximately
$81,700,000 and $80,970,000 at December 31, 1996 and 1995,
respectively. SIGCORP's net investment in leveraged leases
at those dates was $12,185,000 and $5,862,000, respectively,
as shown:
<TABLE>
<CAPTION>
At December 31 (in thousands) 1996 1995
<S> <C> <C>
Minimum lease payments receivable $65,363 $62,655
Estimated residual value 29,073 22,095
Less unearned income 51,549 49,141
Investment in lease financing
receivables and loan 42,887 35,609
Less deferred taxes arising from
leveraged leases 30,702 29,747
Net investment in leveraged leases $12,185 $ 5,862
</TABLE>
Note 5 Short-Term Financing
SIGCORP and SIGECO
SIGECO has trust demand note arrangements totaling
$17,000,000 with several banks, of which $15,000,000 was
utilized at December 31, 1996. Funds are also borrowed
periodically from banks on a short-term basis, made
available through lines of credit. SIGECO has available
lines of credit totaling $22,000,000 at December 31, 1996 of
which $16,000,000 was utilized at that date. SIGCORP has
available lines of credit totaling $41,000,000 at December
31, 1996 of which $23,750,000 was utilized at that date.
<TABLE>
SIGCORP, Inc.
<CAPTION>
At December 31 (in thousands) 1996 1995 1994
<S> <C> <C> <C>
Notes Payable
Balance at year end $38,750 $30,500 $22,060
Weighted average interest rate
on year end balance 5.94% 6.09% 6.83%
Average daily amount outstanding
during the year $24,430 $16,790 $13,827
Weighted average interest rate
on average daily amount
outstanding during the year 5.74% 6.32% 5.46%
</TABLE>
<TABLE>
Southern Indiana Gas and Electric Company
<CAPTION>
At December 31 (in thousands) 1996 1995 1994
<S> <C> <C> <C>
Notes Payable
Balance at year end $32,400 $30,500 $22,060
Weighted average interest
rate on year end balance 5.94% 6.09% 6.83%
Average daily amount outstanding
during the year $24,428 $16,790 $13,827
Weighted average interest rate
on average daily amount
outstanding during the year 5.74% 6.32% 5.46%
</TABLE>
<PAGE> 50
Note 6 Long-Term Debt
SIGCORP and SIGECO
The annual sinking fund requirement of SIGECO's first
mortgage bonds is 1% of the greatest amount of bonds
outstanding under the Mortgage Indenture. This requirement
may be satisfied by certification to the Trustee of unfunded
property additions in the prescribed amount as provided in
the Mortgage Indenture. SIGECO intends to meet the 1997
sinking fund requirement by this means and, accordingly, the
sinking fund requirement for 1997 is excluded from current
liabilities on the balance sheet. At December 31, 1996,
$215,725,000 of SIGECO's utility plant remained unfunded
under SIGECO's Mortgage Indenture.
Several of SIGCORP's partnership investments have been
financed through obligations with such partnerships.
Additionally, SIGCORP's investments in leveraged leases have
been partially financed through notes payable to banks. Of
the amount of first mortgage bonds, notes payable and
partnership obligations outstanding at December 31, 1996,
the following amounts mature in the five years subsequent to
1996:
<TABLE>
<CAPTION>
SIGCORP SIGECO
<S> <C> <C>
1997 $ 2,940,000 $ 300,000
1998 14,917,000 12,400,000
1999 48,180,000 45,500,000
2000 2,450,000 500,000
2001 1,270,000 600,000
</TABLE>
In addition, $31,500,000 of adjustable rate pollution
control series first mortgage bonds could, at the election
of the bondholder, be tendered to SIGECO in May 1997. If
SIGECO's agent is unable to remarket any bonds tendered at
that time, SIGECO would be required to obtain additional
funds for payment to bondholders. For financial statement
presentation purposes those bonds subject to tender in 1997
are shown as current liabilities.
First mortgage bonds, notes payable and partnership
obligations outstanding and classified as long-term are as
follows:
<TABLE>
<CAPTION>
SIGCORP, Inc.
December 31 (in thousands) 1996 1995
<S> <C> <C>
First Mortgage Bonds due:
1998, 6-3/8% $ 12,000 $ 12,000
1999, 6% 45,000 45,000
2003, 5.60% Pollution Control Series A 4,640 4,935
2008, 6.05% Pollution Control Series A 22,000 22,000
2014, 7.25% Pollution Control Series A 22,500 22,500
2016, 8-7/8% 25,000 25,000
2023, 7.60% 45,000 45,000
2025, 7-5/8% 20,000 20,000
Adjustable Rate Pollution Control:
2015, Series A, presently 4.60% 9,975 9,975
Adjustable Rate Environmental Improvement:
2023, Series B, presently 6% 22,800 22,800
2028, Series A, presently 4.65% 22,200 22,200
Total first mortgage bonds $251,115 $251,410
Notes Payable:
Banks, due 1998 through 2001,
presently 8% to 9% $ 10,273 $ 5,836
Tax Exempt, due 2003, 6.25% 1,000 1,000
Total notes payable $ 11,273 $ 6,836
Partnership Obligations, due 1998
through 2002, without interest $ 4,563 $ 6,839
</TABLE>
<PAGE> 51
<TABLE>
<CAPTION>
Southern Indiana Gas and Electric Company
At December 31 (in thousands) 1996 1995
<S> <C> <C>
First Mortgage Bonds due:
1998, 6-3/8% $ 12,000 $ 12,000
1999, 6% 45,000 45,000
2003, 5.60% Pollution Control Series A 4,640 4,935
2008, 6.05% Pollution Control Series A 22,000 22,000
2014, 7.25% Pollution Control Series A 22,500 22,500
2016, 8-7/8% 25,000 25,000
2023, 7.60% 45,000 45,000
2025, 7-5/8% 20,000 20,000
Adjustable Rate Pollution Control:
2015, Series A, presently 4.60% 9,975 9,975
Adjustable Rate Environmental Improvement:
2023, Series B, presently 6% 22,800 22,800
2028, Series A, presently 4.65% 22,200 22,200
Total first mortgage bonds $251,115 $251,410
Notes Payable:
Banks, due 1998 through 2001,
presently 8% to 9% $ - $ 5,836
Tax Exempt, due 2003, 6.25% 1,000 1,000
Total notes payable $ 1,000 $ 6,836
Partnership Obligations, due 1998 through
2002, without interest $ - $ 6,839
</TABLE>
Note 7 Capital Stock
SIGCORP and SIGECO
COMMON STOCK Each outstanding share of SIGCORP's common
stock contains a right which entitles registered holders to
purchase from SIGCORP one one-hundredth of a share of
SIGCORP's common stock, at an initial price of $65 per share
(Purchase Price) subject to adjustment. The rights will not
be exercisable until a party acquires beneficial ownership
of 10% of common shares or makes a tender offer for at least
10% of its common shares. The rights expire December 31,
2005. If not exercisable, the rights in whole may be
redeemed by SIGCORP at a price of $.01 per right at any time
prior to their expiration. If at any time after the rights
become exercisable and are not redeemed and SIGCORP is
involved in a merger or other business combination
transaction, proper provision shall be made to entitle a
holder of a right to buy common stock of the acquiring
company having a value of two times such Purchase Price.
SIGECO has a common stock option plan for its key management
employees. The option price for all stock options is at
least 100% of the fair market value of SIGCORP common stock
at the grant date. Options generally vest and become
exercisable between one and three years in equal annual
installments beginning one year after the grant date, and
generally expire in 10 years. The expiration dates for
options outstanding as of
<PAGE> 52
December 31, 1996, ranged from July 13, 2004 to July 14,
2006. Stock option activity for the past two years was as
follows:
<TABLE>
<CAPTION>
At December 31 1996 1995
<S> <C> <C>
Outstanding at beginning of year 188,319 153,666
Granted 30,771 36,228
Exercised (500) (1,575)
Outstanding at end of year 218,590 188,319
Exercisable at end of year 149,484 75,421
Reserved for future grants at end of year 281,410 310,106
Average Option Price - Exercised $27.63 $27.63
- Outstanding at end of year $31.04 $28.20
</TABLE>
SIGCORP adopted SFAS No. 123, "Accounting for Stock-Based
Compensation," in 1996 by continuing to account for stock
compensation in accordance with Accounting Principles Board
Opinion No. 25, "Accounting for Stock Issued to Employees."
If SIGCORP had recognized compensation expense for its
stock-based compensation plan according to the new standard,
the effect on net income and earnings per share for each of
the three years in the period ended December 31, 1996 would
have been insignificant.
CUMULATIVE PREFERRED STOCK OF SIGECO The amount payable in
the event of involuntary liquidation of each series of the
$100 par value preferred stock is $100 per share, plus
accrued dividends. This nonredeemable preferred stock is
callable at the option of SIGECO as follows: the 4.8% Series
at $110 per share, plus accrued dividends; and the 4.75%
Series at $101 per share, plus accrued dividends.
CUMULATIVE REDEEMABLE PREFERRED STOCK OF SIGECO The Series
has an interest rate of 6.50% and is redeemable at $100 per
share on December 1, 2002. In the event of involuntary
liquidation of this series of $100 par value preferred
stock, the amount payable is $100 per share, plus accrued
dividends.
CUMULATIVE SPECIAL PREFERRED STOCK OF SIGECO The Cumulative
Special Preferred Stock contains a provision which allows
the stock to be tendered on any of its dividend payment
dates. On March 8, 1995, SIGECO repurchased 913 shares of
the Cumulative Special Preferred Stock at a cost of $91,300
as a result of a tender within the provision of the
issuance.
Note 8 Ownership of Warrick Unit 4
SIGCORP and SIGECO
SIGECO and Alcoa Generating Corporation (AGC), a subsidiary
of Aluminum Company of America, own the 270 MW Unit 4 at the
Warrick Power Plant as tenants in common. SIGECO's share of
the cost of this unit at December 31, 1996 is $31,571,000
with accumulated depreciation totaling $22,096,000. AGC and
SIGECO also share equally in the cost of operation and
output of the unit. SIGECO's share of operating costs is
included in operating expenses in the Consolidated
Statements of Income.
Note 9 Commitments and Contingencies
SIGCORP and SIGECO
SIGECO presently estimates that approximately $55,000,000
will be expended for construction purposes in 1997,
including those amounts applicable to SIGECO's demand side
management (DSM) programs. Commitments for the 1997
construction program are approximately $18,200,000 at
December 31, 1996.
<PAGE> 53
Note 10 Segments of Business
SIGCORP and SIGECO
SIGCORP's principal subsidiary, SIGECO, is a public utility
operating company engaged in distributing electricity and
natural gas. The reportable items for electric and gas
departments are as follows:
<TABLE>
<CAPTION>
SIGCORP, Inc.
Year Ended December 31 (in thousands) 1996 1995 1994
<S> <C> <C> <C>
Operating Information-
Operating revenues:
Electric $276,479 $275,495 $260,936
Gas 96,251 63,203 69,099
Total 372,730 338,698 330,035
Operating expenses, excluding
provision for income taxes:
Electric 200,788 206,071 195,790
Gas 86,868 60,661 62,576
Total 287,656 266,732 258,366
Pretax operating income:
Electric 75,691 69,424 65,146
Gas 9,383 2,542 6,523
Total 85,074 71,966 71,669
Allowance for funds used during
construction 445 1,001 6,030
Other income, net 2,277 4,266 535
Interest and other charges (21,472) (21,377) (21,045)
Preferred dividend requirements
of subsidiary (1,097) (1,099) (1,105)
Provision for income taxes (21,963) (16,232) (16,164)
Net income before cumulative effect
of accounting change 43,264 38,525 39,920
Cumulative effect at January 1, 1995
of adopting the unbilled revenues
method of accounting -
net of income taxes - 6,294 -
Net income per accompanying
Consolidated Statements
of Income $ 43,264 $ 44,819 $ 39,920
Other Information-
Depreciation and amortization expense:
Electric $ 35,018 $ 35,802 $ 34,475
Gas 3,599 3,500 3,230
Total $ 38,617 $ 39,302 $ 37,705
Capital expenditures:
Electric <F1> $ 34,836 $ 44,465 $ 74,577
Gas 9,099 9,675 10,174
Total $ 43,935 $ 54,140 $ 84,751
Investment Information-
Identifiable assets <F2>:
Electric $696,600 $708,310 $718,154
Gas 139,030 115,266 102,762
Total 835,630 823,576 820,916
Nonutility plant and other investments 89,613 68,970 70,432
Assets utilized for overall company
operations 27,410 31,435 26,068
Total assets $952,653 $923,981 $917,416
</TABLE>
<PAGE> 54
<TABLE>
<CAPTION>
Southern Indiana Gas and Electric Company
Year Ended December 31 (in thousands) 1996 1995 1994
<S> <C> <C> <C>
Operating Information-
Operating revenues:
Electric $276,479 $275,495 $260,936
Gas 96,251 63,203 69,099
Total 372,730 338,698 330,035
Operating expenses, excluding provision
for income taxes:
Electric 200,788 206,071 195,790
Gas 86,868 60,661 62,576
Total 287,656 266,732 258,366
Pretax operating income:
Electric 75,691 69,424 65,146
Gas 9,383 2,542 6,523
Total 85,074 71,966 71,669
Allowance for funds used
during construction 445 1,001 6,030
Other income, net 3,434 4,266 535
Interest and other charges (21,472) (21,377) (21,045)
Provision for income taxes (24,640) (16,232) (16,164)
Net income before cumulative effect
of accounting change 42,841 39,624 41,025
Cumulative effect at January 1, 1995
of adopting the unbilled revenues
method of accounting
- net of income taxes - 6,294 -
Net Income $ 42,841 $ 45,918 $ 41,025
Preferred Stock Dividends (1,097) (1,099) (1,105)
Net Income Applicable to Common Stock
per accompanying Consolidated
Statements of Income 41,744 44,819 39,920
Other Information-
Depreciation and amortization expense:
Electric $ 35,018 $ 35,802 $ 34,475
Gas 3,599 3,500 3,230
Total $ 38,617 $ 39,302 $ 37,705
Capital expenditures:
Electric <F1> $ 34,836 $ 44,465 $ 74,577
Gas 9,099 9,675 10,174
Total $ 43,935 $ 54,140 $ 84,751
Investment Information-
Identifiable assets <F2>:
Electric $696,600 $708,310 $718,154
Gas 139,030 115,266 102,762
Total 835,630 823,576 820,916
Nonutility plant and other investments 1,552 68,970 70,432
Assets utilized for overall company
operations 15,143 31,435 26,068
Total assets $852,325 $923,981 $917,416
<FN>
<F1> Includes $3,633,000, $9,051,000 and $4,119,000 of
demand side management program expenditures for 1996, 1995
and 1994, respectively.
<F2> Utility plant less accumulated provision for
depreciation, inventories, receivables (less allowance),
regulatory assets and other identifiable assets.
</FN>
</TABLE>
<PAGE> 55
Note 11 Disclosures About Fair Value of Financial
Instruments
SIGCORP and SIGECO
Except for the following financial instruments, fair value
of SIGCORP's and SIGECO's financial instruments is
equivalent to carrying value due to their short-term nature.
<TABLE>
<CAPTION>
SIGCORP, Inc.
At December 31 (in thousands) 1996 1995
Carrying Estimated Carrying Estimated
Amount Fair Value Amount Fair Value
<S> <C> <C> <C> <C>
Long-Term Debt (including
current portion) $293,788 $335,771 $298,846 $336,162
Partnership Obligations
(including current portion) 6,839 8,231 9,625 11,965
Redeemable Preferred
Stock of Subsidiary 7,500 7,367 7,500 7,260
</TABLE>
<TABLE>
<CAPTION>
Southern Indiana Gas
and Electric Company
At December 31 (in thousands) 1996 1995
Carrying Estimated Carrying Estimated
Amount Fair Value Amount Fair Value
<S> <C> <C> <C> <C>
Long-Term Debt (including
current portion) $283,151 $324,325 $298,846 $336,162
Redeemable Preferred Stock 7,500 7,367 7,500 7,260
</TABLE>
At December 31, 1996 and 1995, respectively, the fair value of SIGCORP's
debt relating to utility operations exceeded carrying amounts by
$41,000,000 and $36,000,000. Anticipated regulatory treatment of the
excess or deficiency of fair value over carrying amounts of SIGECO's long-
term debt, if in fact settled at amounts approximating those above, would
dictate that these amounts be used to reduce or increase SIGECO's rates
over a prescribed amortization period. Accordingly, any settlement would
not result in a material impact on SIGECO's financial position or results
of operations.
LONG-TERM DEBT The fair value of SIGECO's long-term debt was estimated
based on the current quoted market rate of utilities with a comparable debt
rating. Nonutility long-term debt was valued based upon the most recent
debt financing.
REDEEMABLE PREFERRED STOCK OF SIGECO The fair value of SIGECO's redeemable
preferred stock was estimated based on the current quoted market rate of
utilities with a comparable debt rating.
PARTNERSHIP OBLIGATIONS The fair value of SIGCORP's partnership
obligations was estimated based on the current quoted market rate of
comparable debt.
<PAGE> 56
<TABLE>
<CAPTION>
Selected Quarterly Financial Data (Unaudited)
SIGCORP, Inc.
Quarter Ended
(in thousands except for per share amounts)
March 31, June 30, September 30, December 31,
1996 1995 1996 1995 1996 1995 1996 1995
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Operating Revenues
$106,476 $84,423 $83,426 $79,861 $91,095 $89,427 $91,733 $84,987
Operating Income
$16,332 $12,673 $13,231 $12,591 $20,517 $19,711 $10,961 $8,898
Net Income
$13,272 $15,776<F1> $8,837 $8,158 $15,948 $15,813 $5,207 $ 5,072
Earnings Per Share of Common Stock
$0.84 $1.00<F2> $0.56 $0.52 $1.01 $ 1.00 $0.33 $0.32
Average Common Shares Outstanding
15,755 15,755 15,755 15,755 15,755 15,755 15,755 15,755
SOUTHERN INDIANA GAS AND ELECTRIC COMPANY
Quarter Ended
(in thousands except for per share amounts)
March 31, June 30, September 30, December 31,
1996 1995 1996 1995 1996 1995 1996 1995
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Operating Revenues
$106,476 $84,423 $83,426 $79,861 $91,095 $89,427 $91,733 $84,987
Operating Income
$16,330 $12,673 $13,256 $12,591 $20,517 $19,711 $10,938 $8,898
Net Income
$12,402 $15,776<F1> $8,031 $8,158 $15,368 $15,813 $5,943 $ 5,072
Earnings Per Share of Common Stock
$0.79 $1.00<F2> $0.51 $0.52 $0.98 $ 1.00 $0.38 $0.32
Average Common Shares Outstanding
15,755 15,755 15,755 15,755 15,755 15,755 15,755 15,755
<FN>
<F1> Includes cumulative effect of accounting change of $6,294.
<F2> Includes cumulative effect of accounting change of $.40.
<F3> Information for any one quarterly period is not indicative of the
annual results which may be expected due to seasonal variations common in
the utility industry.
<F4>The quarterly earnings per share may not add to the total earnings per
share for the year due to rounding.
</FN>
</TABLE>
Item 9. DISAGREEMENTS ON ACCOUNTING AND FINANCIAL
DISCLOSURE
None
PART III
Item 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE
REGISTRANTS
(a) Identification of Directors
The information required by this item is included in
SIGCORP, Inc.'s and Southern Indiana Gas and Electric
Company's Joint Proxy Statement (the Joint Proxy Statement),
dated March 21, 1997 definitive copies of which were filed
with the Commission pursuant to Regulation 14A.
(b) Identification of Executive Officers
The information required by this item is included in
Part I, Item 1. - BUSINESS on page 14, to which reference is
hereby made.
Item 11. EXECUTIVE COMPENSATION AND TRANSACTIONS
The information required by this item is included in
the Joint Proxy Statement, definitive copies of which were
filed with the Commission pursuant to Regulation 14A.
<PAGE> 57
Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
AND MANAGEMENT
The information required by this item is included in
the Joint Proxy Statement, definitive copies of which were
filed with the Commission pursuant to Regulation 14A.
Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The information required by this item is included in
the Joint Proxy Statement, definitive copies of which were
filed with the Commission pursuant to Regulation 14A.
PART IV
Item 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND
REPORTS ON FORM 8-K
(a) 1 and 2) The financial statements, including supporting
schedule, are listed in the Index to Financial Statements,
page 24, filed as part of this report.
(a) 3) Exhibits:
SIGCORP and SIGECO
EX-2(a) Agreement and Plan of Exchange, of common
stock between Southern Indiana Gas and Electric Company and
SIGCORP, Inc., dated February 23, 1995. (Physically filed
and designated as Exhibit 2(a) in Amendment No. 1 to Form S-
4 Registration Statement filed January 20, 1995, File No.
33-57381.)
SIGCORP
EX-3(a) Restated Articles of Incorporation of SIGCORP,
Inc. (Physically filed and designated as Exhibit 3(a) in
Amendment No. 1 to Form S-4 Registration Statement, filed
February 23, 1995, File No. 33-57381.)
EX-3(b) By-Laws of SIGCORP, Inc. . (Physically filed
and designated as Exhibit 3(b) in Amendment No. 1 to Form S-
4 Registration Statement, filed February 23, 1995, File No.
33-57381.)
EX-4(a) Rights Agreement, between SIGCORP, Inc. and
Continental Stock Transfer & Trust Company, Rights Agent,
dated as of December 31, 1995. (Physically filed and
designated as Exhibit 4.1 in Form 8-B Registration Statement
filed December 15, 1995, File No. 1-11603.)
SIGECO
EX-3(a) Amended Articles of Incorporation as amended
March 26, 1985. (Physically filed and designated in Form
10-K, for the fiscal year 1985, File No. 1-3553, as Exhibit
3-A.) Articles of Amendment of the Amended Articles of
Incorporation, dated March 24, 1987. (Physically filed and
designated in Form 10-K for the fiscal year 1987, File No.
1-3553, as Exhibit 3-A.) Articles of Amendment of the
Amended Articles of Incorporation, dated November 27, 1992.
(Physically filed and designated in Form 10-K for the fiscal
year 1992, File No. 1-3553, as Exhibit 3-A).
EX-3(b) By-Laws as amended through December 18, 1990.
(Physically filed in Form 10-K for the fiscal year 1990,
File No. 1-3553, as Exhibit 3-B.) By-Laws as amended
through September 22, 1993. (Physically filed and
designated in Form 10-K for the fiscal year 1993, File No.
1-3553, as EX-3 (b).) By-Laws as amended through January 1,
1995. (Physically filed and designated in Form 10-K for the
fiscal year 1995, File No. 1-3553, as EX-3(b).)
<PAGE> 58
EX-4(a)* Mortgage and Deed of Trust dated as of April
1, 1932 between Southern Indiana Gas and Electric Company
and Bankers Trust Company, as Trustee, and Supplemental
Indentures thereto dated August 31, 1936, October 1, 1937,
March 22, 1939, July 1, 1948, June 1, 1949, October 1, 1949,
January 1, 1951, April 1, 1954, March 1, 1957, October 1,
1965, September 1, 1966, August 1, 1968, May 1, 1970,
August 1, 1971, April 1, 1972, October 1, 1973, April 1,
1975, January 15, 1977, April 1, 1978, June 4, 1981, January
20, 1983, November 1, 1983, March 1, 1984, June 1, 1984,
November 1, 1984, July 1, 1985, November 1, 1985, June 1,
1986. (Physically filed and designated in Registration No.
2-2536 as Exhibits B-1 and B-2; in Post-effective Amendment
No. 1 to Registration No. 2-62032 as Exhibit (b)(4)(ii), in
Registration No. 2-88923 as Exhibit 4(b)(2), in Form 8-K,
File No. 1-3553, dated June 1, 1984 as Exhibit (4), File No.
1-3553, dated March 24, 1986 as Exhibit 4-A, in Form 8-K,
File No. 1-3553, dated June 3, 1986 as Exhibit (4).) July
1, 1985 and November 1, 1985 (Physically filed and
designated in Form 10-K, for the fiscal year 1985, File
No. 1-3553, as Exhibit 4-A.) November 15, 1986 and January
15, 1987. (Physically filed and designated in Form 10-K,
for the fiscal year 1986, File No. 1-3553, as Exhibit 4-A.)
December 15, 1987. (Physically filed and designated in Form
10-K, for the fiscal year 1987, File No. 1-3553, as Exhibit
4-A.) December 13, 1990. (Physically filed and designated
in Form 10-K, for the fiscal year 1990, File No. 1-3553, as
Exhibit 4-A.) April 1, 1993. (Physically filed and
designated in Form 8-K, dated April 13, 1993, File 1-3553,
as Exhibit 4.) June 1, 1993 (Physically filed and
designated in Form 8-K, dated June 14, 1993, File 1-3553, as
Exhibit 4.) May 1, 1993. (Physically filed and designated
in Form 10-K, for the fiscal year 1993, File No. 1-3553, as
Exhibit 4(a).)
*Pursuant to paragraph (b)(4)(iii)(a) of Item 601 of
Regulation S-K, SIGECO agrees to furnish to the Commission
on request any instrument with respect to long-term debt if
the total amount of securities authorized thereunder does
not exceed 10% of the total assets of SIGECO, and has
therefore not filed such documents as exhibits to this Form
10-K.
EX-10.1 Agreement, dated, January 30, 1968, for Unit
No. 4 at the Warrick Power Plant of Alcoa Generating
Corporation ("Alcoa"), between Alcoa and Southern Indiana
Gas and Electric Company. (Physically filed and designated
in Registration No. 2-29653 as Exhibit 4(d)-A.)
EX-10.2 Letter of Agreement, dated June 1, 1971, and
Letter Agreement, dated June 26, 1969, between Alcoa and
Southern Indiana Gas and Electric Company. (Physically
filed and designated in Registration No. 2-41209 as Exhibit
4(e)-2.)
EX-10.3 Letter Agreement, dated April 9, 1973, and
Agreement dated April 30, 1973, between Alcoa and Southern
Indiana Gas and Electric Company. (Physically filed and
designated in Registration No. 2-53005 as Exhibit 4(e)-4.)
EX-10.4 Electric Power Agreement (the "Power
Agreement"), dated May 28, 1971, between Alcoa and Southern
Indiana Gas and Electric Company. (Physically filed and
designated in Registration No. 2-41209 as Exhibit 4(e)-1.)
EX-10.5 Second Supplement, dated as of July 10, 1975,
to the Power Agreement and Letter Agreement dated April 30,
1973 - First Supplement. (Physically filed and designated
in Form 12-K for the fiscal year 1975, File No. 1-3553, as
Exhibit 1(e).)
EX-10.6 Third Supplement, dated as of May 26, 1978, to
the Power Agreement. (Physically filed and designated in
Form 10-K for the fiscal year 1978 as Exhibit A-1.)
EX-10.7 Letter Agreement dated August 22, 1978 between
Southern Indiana Gas and Electric Company and Alcoa, which
amends Agreement for Sale in an Emergency of Electrical
Power and Energy Generation by Alcoa and Southern Indiana
Gas and Electric Company dated June 26, 1979. (Physically
filed and designated in Form 10-K for the fiscal year 1978,
File No. 1-3553, as Exhibit A-2.)
<PAGE> 59
EX-10.8 Fifth Supplement, dated as of December 13,
1978, to the Power Agreement. (Physically filed and
designated in Form 10-K for the fiscal year 1979, File No.
1-3553, as Exhibit A-3.)
EX-10.9 Sixth Supplement, dated as of July 1, 1979, to
the Power Agreement. (Physically filed and designated in
Form 10-K for the fiscal year 1979, File No. 1-3553, as
Exhibit A-5.)
EX-10.10 Seventh Supplement, dated as of October 1,
1979, to the Power Agreement. (Physically filed and
designated in Form 10-K for the fiscal year 1979, File No.
1-3553, as Exhibit A-6.)
EX-10.11 Eighth Supplement, dated as of June 1, 1980
to the Electric Power Agreement, dated May 28, 1971, between
Alcoa and Southern Indiana Gas and Electric Company.
(Physically filed and designated in Form 10-K for the fiscal
year 1980, File No. 1-3553, as Exhibit (20)-1.)
EX-10.12** Agreement dated May 6, 1991 between
Southern Indiana Gas and Electric Company and Ronald G.
Reherman for consulting services and supplemental pension
and disability benefits. (Physically filed and designated
in Form 10-K for the fiscal year 1992, File No. 1-3553, as
Exhibit 10-A-12.)
EX-10.13** Agreement dated July 22, 1986 between
Southern Indiana Gas and Electric Company and A. E. Goebel
regarding continuation of employment. (Physically filed and
designated in Form 10-K for the fiscal year 1992, File No.
1-3553, as Exhibit 10-A-13.)
EX-10.14** Agreement dated July 25, 1986 between
Southern Indiana Gas and Electric Company and Ronald G.
Reherman regarding continuation of employment. (Physically
filed and designated in Form 10-K for the fiscal year 1992,
File No. 1-3553, as Exhibit 10-A-14.)
EX-10.15** Agreement dated July 22, 1986 between
Southern Indiana Gas and Electric Company and James A. Van
Meter regarding continuation of employment. (Physically
filed and designated in Form 10-K for the fiscal year 1992,
File No. 1-3553, as Exhibit 10-A-15.)
EX-10.16** Agreement dated February 22, 1989 between
Southern Indiana Gas and Electric Company and J. Gordon
Hurst regarding continuation of employment. (Physically
filed and designated in Form 10-K for the fiscal year 1992,
File No. 1-3553 as Exhibit 10-A-16.)
EX-10.17** Summary description of Southern Indiana Gas
and Electric Company's nonqualified Supplemental Retirement
Plan (Physically filed and designated in Form 10-K for the
fiscal year 1992, File No. 1-3553, as Exhibit 10-A-17.)
EX-10.18** Supplemental Post Retirement Death Benefits
Plan, dated October 10, 1984. (Physically filed and
designated in Form 10-K for the fiscal year 1992, File No.
1-3553, as Exhibit 10-A-18.)
EX-10.19** Summary description of Southern Indiana Gas
and Electric Company's Corporate Performance Incentive Plan.
(Physically filed and designated in Form 10-K for the fiscal
year 1992, File No. 1-3553, as Exhibit 10-A-19.)
EX-10.20** Southern Indiana Gas and Electric Company's
Corporate Performance Incentive Plan as amended for the plan
year beginning January 1, 1994. (Physically filed and
designated in Form 10-K for the fiscal year 1993, File No.
1-3553, as Exhibit 10-A-20.)
** Filed pursuant to paragraph (b)(10)(iii)(A) of Item
601 of Regulation S-K.
<PAGE> 60
EX-10.21** Southern Indiana Gas and Electric Company
1994 Stock Option Plan (Physically filed and designated in
Southern Indiana Gas and Electric Company's Proxy Statement
dated February 22, 1994, File No. 1-3553, as Exhibit A.)
** Filed pursuant to paragraph (b)(10)(iii)(A) of Item
601 of Regulation S-K.
SIGECO
EX-12 Computation of Ratio of Earnings to Fixed
Charges
SIGCORP
EX-21 Subsidiaries of the Registrant
SIGCORP and SIGECO
EX-24 Power of Attorney
(b) Reports on Form 8-K
No Form 8-K reports were filed by SIGCORP or SIGECO
during the fourth quarter of 1996.
page> 61
<TABLE>
SCHEDULE II
SIGCORP, Inc.
and
Southern Indiana Gas And Electric Company
<CAPTION>
VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
Column A Column B Column C Column D Column E
Additions
Balance Charged Charged Deductions Balance
Beginning to to Other from Re- End of
Description of Year Expenses Accounts serves, Net Year
(in thousands)
>s> <C> <C> <C> <C> <C>
VALUATION AND QUALIFYING
ACCOUNTS:
Year 1996 - Accumulated
provision for uncollectible
accounts $ 138 $910 $ - $ 833 $ 215
Year 1995 - Accumulated
provision for uncollectible
accounts $ 231 $581 $ - $ 675 $ 138
Year 1994 - Accumulated
provision for uncollectible
accounts $ 166 $819 $ - $ 754 $ 231
OTHER RESERVES:
Year 1996 - Reserve for
injuries and damages $1,541 $968 $221<F1> $ 993 $1,737
Year 1995 - Reserve for
injuries and damages $1,692 $712 $155<F1> $1,018 $1,541
Year 1994 - Reserve for
injuries and damages $1,321 $705 $ 95<F1> $ 429 $1,692
<FN>
<F1> Charged to construction accounts
</FN>
</TABLE>
<PAGE> 62
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the
Securities Exchange Act of 1934, the registrants have duly
caused this report to be signed on their behalf by the
undersigned, thereunto duly authorized.
Date: March 27, 1997
SIGCORP, Inc.
By R. G. Reherman, Chairman, President
and Chief Executive Officer
BY: R. G. Reherman
R. G. Reherman
SOUTHERN INDIANA GAS AND ELECTRIC COMPANY
By R. G. Reherman, Chairman, President
and Chief Executive Officer
BY: R. G. Reherman
R. G. Reherman
Pursuant to the requirements of the Securities Exchange
Act of 1934, this report has been signed below by the
following persons on behalf of the registrants and in the
capacities and on the dates indicated.
<TABLE>
<CAPTION>
Signatures Title Date
<S> <C> <C>
R. G. Reherman Chairman, President, Chief Executive
Officer of SIGCORP, Inc. And Southern March 27, 1997
Indiana Gas and Electric Company
(Principal Executive Officer)
A. E. Goebel* Secretary and Treasurer of SIGCORP, Inc.
(Principal Financial Officer)
Chief Financial Officer and Secretary of
Southern Indiana Gas And Electric Company
(Principal Financial Officer) March 27, 1997
S. M. Kerney* Controller of Southern Indiana Gas
And Electric Company
(Principal Accounting Officer) March 27, 1997
John M. Dunn* )
)
John D. Engelbrecht* )
)
Robert L. Koch II* )
)
Donald A. Rausch* ) Directors of SIGCORP, Inc. March 27, 1997
) and Southern Indiana Gas
Richard W. Shymanski* ) And Electric Company
)
Donald E. Smith* )
)
James S. Vinson* )
)
N. P. Wagner* )
*By
(R. G. Reherman, Attorney-in-fact)
</TABLE>
SIGCORP
10-K
<PAGE>
<TABLE>
<CAPTION>
EXHIBIT INDEX
Sequential
Page Number
<S> <C> <C>
Exhibits incorporated by reference are found on 57 - 60
EX-21 Subsidiaries of the Registrant 64
EX-24 Power-of-Attorney 65 - 66
</TABLE>
EX-24
March 18, 1997
Mr. R. G. Reherman
Mr. A. E. Goebel
Southern Indiana Gas and Electric Company
20 N.W. Fourth Street
Evansville, Indiana 47741
J. H. Byington, Jr., Esq.
Winthrop, Stimson, Putnam & Roberts
40 Wall Street
New York, New York 10005
Dear Gentlemen:
SIGCORP, Inc. and Southern Indiana Gas and Electric
Company will each file an Annual Report on Form 10-K for the
fiscal year ended December 31, 1996 ("Form 10-K") before
April 1, 1997 which will be accompanied by certain exhibits.
We hereby authorize you, or any one of you, to
complete said Forms 10-K and to remedy any deficiencies with
respect to said Forms 10-K by appropriate amendment or
amendments; and we hereby make, constitute and appoint each
of you our true and lawful attorney for each of us and in
each of our names, places and steads, both in our individual
capacities as directors and that of officers of SIGCORP,
Inc. and Southern Indiana Gas and Electric Company, to sign
and cause to be filed with the Securities and Exchange
Commission said Forms 10-K, any appropriate amendment or
amendments thereto, and any exhibits thereto.
The undersigned, SIGCORP, Inc. and Southern Indiana
Gas and Electric Company, also authorize you and any one of
you to sign said Forms 10-K and any amendment or amendments
thereto on its behalf as attorney-in-fact for its respective
officers, and to file the same as
aforesaid together with exhibits.
Very truly yours,
SIGCORP, INC. and
SOUTHERN INDIANA GAS AND ELECTRIC COMPANY
By R. G. Reherman
R. G. Reherman, Chairman, President
and Chief Executive Officer
John M. Dunn Ronald G. Reherman
John M. Dunn Ronald G. Reherman
John D. Engelbrecht Richard W. Shymanski
John D. Engelbrecht Richard W. Shymanski
Robert L. Koch II Donald E. Smith
Robert L. Koch II Donald E. Smith
Jerry A. Lamb James S. Vinson
Jerry A. Lamb James S. Vinson
Donald A. Rausch N. P. Wagner
Donald A. Rausch N. P. Wagner
A. E. Goebel
A. E. Goebel
S. M. Kerney
S. M. Kerney
<TABLE> <S> <C>
<ARTICLE> UT
<CIK> 0000945372
<NAME> SIGCORP, INC.
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 12-MOS
<FISCAL-YEAR-END> DEC-31-1996
<PERIOD-END> DEC-31-1996
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 681,258
<OTHER-PROPERTY-AND-INVEST> 93,443
<TOTAL-CURRENT-ASSETS> 128,520
<TOTAL-DEFERRED-CHARGES> 49,432
<OTHER-ASSETS> 0
<TOTAL-ASSETS> 952,653
<COMMON> 78,258
<CAPITAL-SURPLUS-PAID-IN> 0
<RETAINED-EARNINGS> 252,626
<TOTAL-COMMON-STOCKHOLDERS-EQ> 330,884
0
19,514
<LONG-TERM-DEBT-NET> 266,192
<SHORT-TERM-NOTES> 0
<LONG-TERM-NOTES-PAYABLE> 38,750
<COMMERCIAL-PAPER-OBLIGATIONS> 0
<LONG-TERM-DEBT-CURRENT-PORT> 34,435
0
<CAPITAL-LEASE-OBLIGATIONS> 0
<LEASES-CURRENT> 0
<OTHER-ITEMS-CAPITAL-AND-LIAB> 234,206
<TOT-CAPITALIZATION-AND-LIAB> 923,981
<GROSS-OPERATING-REVENUE> 372,730
<INCOME-TAX-EXPENSE> 24,034
<OTHER-OPERATING-EXPENSES> 287,655
<TOTAL-OPERATING-EXPENSES> 311,689
<OPERATING-INCOME-LOSS> 61,041
<OTHER-INCOME-NET> 4,347
<INCOME-BEFORE-INTEREST-EXPEN> 65,388
<TOTAL-INTEREST-EXPENSE> 22,124
<NET-INCOME> 43,264
0
<EARNINGS-AVAILABLE-FOR-COMM> 0
<COMMON-STOCK-DIVIDENDS> 27,256
<TOTAL-INTEREST-ON-BONDS> 18,432
<CASH-FLOW-OPERATIONS> 87,380
<EPS-PRIMARY> 2.75
<EPS-DILUTED> 2.75
</TABLE>
EX-21
SIGCORP, Inc.
SUBSIDIARIES OF THE REGISTRANT
Southern Indiana Gas and Electric Company
Southern Indiana Properties, Incorporated in Indiana
Energy Systems Group, Incorporated in Indiana
Southern Indiana Minerals, Incorporated in Indiana
ComSource, Incorporated in Indiana
SIGCORP Energy Services, Incorporated in Indiana
SIGCORP Capital, Incorporated in Indiana
SIGCORP Fuels, Incorporated in Indiana
SIGCORP Power Marketing, Incorporated in Indiana
