UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 1995 Commission file number 1-5663
Or
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF
THE SECURITIES EXCHANGE ACT OF 1934
CENTRAL LOUISIANA ELECTRIC COMPANY, INC.
(EXACT NAME OF REGISTRANT AS SPECIFIED IN ITS CHARTER)
LOUISIANA 72-0244480
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
2030 DONAHUE FERRY ROAD, PINEVILLE, LOUISIANA 71360-5226
(Address of principal executive offices) (Zip Code)
REGISTRANT'S TELEPHONE NUMBER, INCLUDING AREA CODE: 318/484-7400
SECURITIES REGISTERED PURSUANT TO SECTION 12(B) OF THE ACT:
NAME OF EACH EXCHANGE
TITLE OF EACH CLASS ON WHICH REGISTERED
------------------- ---------------------
COMMON STOCK, $2.00 PAR VALUE New York Stock Exchange
Pacific Stock Exchange
SECURITIES REGISTERED PURSUANT TO SECTION 12(G) OF THE ACT:
TITLE OF EACH CLASS
Cumulative Preferred Stock, $100 Par Value
4.50% 4.50%, Series of 1955
4.65%, Series of 1964
4.75%, Series of 1965
Convertible, Series of 1991
Indicate by check mark whether the Registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
Registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes [X], No [ ].
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405
of Regulation S-K is not contained herein, and will not be contained, to the
best of Registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to this
Form 10-K. [ ]
As of February 19, 1996, the aggregate value of the Registrant's voting stock
held by non-affiliates was $598,490,824. The Registrant's Cumulative Preferred
Stock is not listed on any exchange, nor are prices for the Cumulative Preferred
Stock quoted on NASDAQ; therefore, its market value is not readily determinable
and is not included in the foregoing amount.
As of March 15, 1996, there were 22,440,634 shares outstanding of the
Registrant's Common Stock, par value $2.00 per share.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Registrant's Annual Report to Shareholders for the year ended
December 31, 1995, furnished to the Securities and Exchange Commission pursuant
to Rule 14a - 3(b) under the Securities Exchange Act of 1934 (1995 Annual Report
to Shareholders), are filed as Exhibit 13 to this report and incorporated by
reference into Part II herein. Portions of the Registrant's definitive Proxy
Statement dated March 5, 1996, for the Annual Meeting of Shareholders to be held
on April 19, 1996, are incorporated by reference into Part III herein.
TABLE OF CONTENTS
PART I
Page
----
Item 1. Business
General ............................................ 1
Electric Operations ................................ 1
Regulatory and Environmental Matters ............... 6
Item 2. Properties ......................................... 12
Item 3. Legal Proceedings .................................. 13
Item 4. Submission of Matters to a Vote
of Security Holders .............................. 13
Executive Officers of the Registrant ............... 14
PART II
Item 5. Market for Registrant's Common Equity
and Related Stockholder Matters .................. 16
Item 6. Selected Financial Data ............................ 16
Item 7. Management's Discussion and Analysis of
Financial Condition and Results of
Operations ....................................... 17
Item 8. Financial Statements and
Supplementary Data ............................... 17
Item 9. Changes in and Disagreements with
Accountants on Accounting and
Financial Disclosure ............................. 18
PART III
Item 10. Directors and Executive Officers
of the Registrant ................................ 18
Item 11. Executive Compensation ............................ 18
Item 12. Security Ownership of Certain Beneficial
Owners and Management ............................ 18
Item 13. Certain Relationships and Related
Transactions ..................................... 18
PART IV
Item 14. Exhibits, Financial Statement
Schedule, and Reports on Form 8-K ................ 19
ITEM 1. BUSINESS
GENERAL
Central Louisiana Electric Company, Inc. (the Company) was incorporated in
1934 under the laws of the State of Louisiana and is engaged principally in the
generation, transmission, distribution and sale of electric energy to
approximately 221,000 customers in 63 communities and contiguous rural areas in
a 14,000 square-mile region in the State of Louisiana. At December 31, 1995 the
Company employed 1,192 persons. The Company's mailing address is P. O. Box 5000,
Pineville, Louisiana 71361-5000, and its telephone number is (318) 484-7400.
ELECTRIC OPERATIONS
CERTAIN FACTORS AFFECTING THE COMPANY'S ELECTRIC OPERATIONS
As an electric utility, the Company has been affected, to varying degrees, by
a number of factors affecting the electric utility industry in general. These
factors include increasingly competitive business conditions, the cost of
compliance with environmental regulations, and changes in the federal regulation
of the generation and transmission of electricity. For a discussion of various
regulatory changes and competitive forces affecting the Company and other
electric utilities, see "Regulatory and Environmental Matters - Energy Policy
Act of 1992" - "Competition", and" - Regulatory matters" below.
POWER GENERATION
The Company operates and either owns or has an ownership interest in four
steam electric generating stations and a gas turbine. The Company is the sole
owner of Coughlin Power Station, Teche Power Station and Rodemacher Power
Station Unit 1. The Company owns a 50% interest in Dolet Hills Power Station
Unit 1 (Dolet Hills Unit 1), and a 30% interest in Rodemacher Power Station Unit
2 (Rodemacher Unit 2). In December 1995, the Company assumed formal ownership of
the city of Franklin's electrical system, including a 7 MW gas turbine. At
December 31, 1995 the Company's aggregate electric generating capacity was
1,693,000 kilowatts (excluding the Company's 20,000 kilowatts of firm purchases
from Sabine River Authority). The following table sets forth certain information
with respect to the Company's generating facilities.
1
YEAR CAPACITY TYPE OF
OF AT FUEL
GENERATING INITIAL 12/31/95 USED FOR
GENERATING STATION UNIT # OPERATION (KILOWATTS) GENERATION (1)
- ------------------------- --------- -------- ---------- --------------
Franklin Gas Turbine ............... 1973 7,000 gas
Coughlin Power Station ............. 6 1961 110,000 gas/oil(standby)
7 1966 224,000 gas/oil(standby)
Teche Power Station ................ 1 1953 23,000 gas
2 1956 48,000 gas
3 1971 359,000 gas/oil(standby)
Rodemacher Power Station ........... 1 1975 440,000 gas/oil
2 1982 157,000(2) coal/gas
Dolet Hills Power Station .......... 1 1986 325,000(3) lignite
---------
Total Generating Capability 1,693,000
=========
- ------------
(1) Where oil is used on a standby basis, capacity may be reduced.
(2) Represents the Company's 30% interest in the capacity of Rodemacher Unit 2,
a 523,000-kilowatt generating unit.
(3) Represents the Company's 50% interest in the capacity of Dolet Hills Unit 1,
a 650,000-kilowatt generating unit.
FUEL
The following table sets forth, for the periods indicated, the percentages of
power generated from various fuels at the Company's electric generating plants,
the cost of fuel used per kilowatt hour (KWH) attributable to each such fuel and
the weighted average fuel cost per KWH.
LIGNITE COAL GAS FUEL OIL WEIGHTED
-------------------- -------------------- -------------------- -------------------- AVERAGE
COST COST COST COST COST
PER PERCENT PER PERCENT PER PERCENT PER PERCENT PER
KWH OF KWH OF KWH OF KWH OF KWH
YEAR (MILLS) GENERATION (MILLS) GENERATION (MILLS) GENERATION (MILLS) GENERATION (MILLS)
- ---- ------- ---------- ------- ---------- ------- ---------- ------- ---------- -------
1995 14.86 35.9 18.88 14.3 19.48 49.8 24.77 0.0 17.74
1994 15.09 36.5 19.53 16.0 22.28 47.4 21.00 0.1 19.22
1993 15.50 32.7 20.28 19.5 25.11 47.8 -- -- 21.02
1992 14.96 37.0 20.07 16.7 21.48 46.3 -- -- 18.83
1991 14.96 37.2 21.07 15.2 19.94 47.6 -- -- 18.26
For information with respect to the Company's ability to pass through
changes in costs of fuel to its customers, see "Regulatory and Environmental
Matters - Rates" below.
Natural Gas Supply
During 1995, the Company purchased a total of 33,034 billion British
thermal units (MMMBtu) of natural gas for the generation of electricity. The
annual and average per-day quantities of gas purchased by the Company from each
supplier are shown in the table below.
2
AVERAGE
AMOUNT
1995 PURCHASED PERCENT
PURCHASES PER DAY OF TOTAL
NATURAL GAS SUPPLIER (MMMBTU) (MMMBTU GAS USED
- -------------------- ------ ----- -----
NorAm Energy Services, Inc. ............... 15,078 41.3 45.6
Louisiana Intrastate Gas Corporation ...... 13,893 38.1 42.1
Louisiana Land and Exploration Company . 1,824 5.0 5.5
Other .................................. 2,239 6.1 6.8
------ ----- -----
33,034 90.5 100.0
====== ===== =====
The Company has contracted with NorAm Energy Services, Inc. (NES), a
subsidiary of NorAm Energy Corp., for the purchase of natural gas to be
delivered to the Company's four power stations. The contract provides for a firm
gas supply through the year 2000 in quantities sufficient to meet the Company's
internal system requirements and contains options designed to enable the Company
to manage the natural gas component of its total fuel costs. The contract may be
terminated earlier under price reopener provisions which may be initiated by
either party in early 1996; and the Company has exercised its option to
renegotiate the price at this time. If the parties do not come to an agreement
the contract terminates effective January 1, 1997. The contract with NES
contains pricing mechanisms for gas purchased thereunder which are intended to
approximate current market prices at the time of purchase and are designed to be
competitive with prices paid by other Louisiana electric utilities. The Company
plans to construct or have constructed lateral pipelines to connect its
generating station(s) to other interstate natural gas pipelines in order to
provide additional sources of supply and transportation prior to the termination
or expiration of the NES contract.
The NES contract also contains minimum and maximum supply obligations
which are based upon the Company's seasonal generation requirements. The Company
is obligated to purchase certain quantities of gas from NES on an annual basis.
A minimum or base quantity of 20,000 MMMBtu of gas must be purchased during a
year, adjusted by plus or minus 10% at the option of the Company each year, if
all gas is purchased from NES. The Company exercised its option to reduce the
20,000 MMMBtu by 10% for 1995, in effect reducing the 1995 minimum gas purchase
to 18,000 MMMBtu. A minimum of 25,000 MMMBtu must be purchased during a year if
any gas is purchased from third party suppliers, unless a lesser amount is
permitted under the contract. In 1995, the Company met its minimum purchase
obligations under the contract. The contract also allows for the purchase of
natural gas from suppliers other than Louisiana Intrastate Gas Corporation (LIG)
or Louisiana Land and Exploration Company (LL&E), if the gas is purchased for
sales to other utilities.
The Company has a contract with LIG for the sale and transportation of
natural gas to the Company's power stations. A total of 13,893 MMMBtu of "spot"
and surplus gas was purchased from LIG during 1995 under sale and transportation
agreements. The month-to-month contract with LIG provides for the purchase of
spot gas for the Company's internal system requirements when the price of such
gas is less than that of energy purchases from other utilities and provides for
the purchase of surplus gas, if and when it is available, for energy sales to
other utilities. The Company has a separate contract with LIG which provides for
the transportation of gas purchased by the Company from third party suppliers or
under certain circumstances if NES were to fail to meet its contract
obligations.
3
The Company has contracted with LL&E for the purchase of up to 5 MMMBtu of
gas per day on a month-to-month basis, subject to termination by either party.
The purchase price of the gas is based on a monthly index plus a markup and
transportation fee. Purchased gas is transported via the intrastate pipeline
system owned and operated by LIG.
The Company has never incurred a liability for any gas not taken under the
take-or-pay provisions of its gas supply agreements. The Company believes that
it will be able either to renew its gas supply contracts as they terminate or
expire or enter into substitute contractual arrangements with other natural gas
suppliers. Although natural gas has been relatively plentiful in recent years,
supplies available to the Company and other consumers are vulnerable to
disruption due to weather conditions, transportation disruption, price changes
and other events. Large boiler-fuel users of natural gas, including electric
utilities, generally have the lowest priority among gas users in the event
pipeline suppliers are forced to curtail deliveries due to inadequate supplies.
Thus, supplies of natural gas may become unavailable from time to time, or
prices may increase rapidly in response to temporary supply disruptions. Such
events may require the Company to shift its gas-fired generation to alternative
fuel sources, such as fuel oil, to the extent it has the capability to burn
those alternative fuels. Currently, the Company anticipates that its alternative
fuel capability, combined with its solid-fuel generating resources, is adequate
to meet fuel needs during any temporary interruption of gas supplies.
Coal and Lignite Supply
Substantially all of the coal for Rodemacher Unit 2 is purchased under a
long-term contract with Kerr-McGee Coal Corporation from mines in Wyoming. The
price of coal under the contract is a base price per ton plus a "total
escalation charge" to reflect changes in certain indices specified in the
contract. After purchasing a given annual quantity of base coal (504,000 tons in
1995), the Company has the right to purchase coal from third parties in the spot
market, and Kerr-McGee has the right to meet the terms of the proposed purchase
if it chooses to do so. The coal is transported to the Rodemacher Unit 2 site
under terms of a long-term rail transportation contract in unit trains which are
leased by the Company pursuant to various long-term leases.
Substantially all of the lignite used to fuel Dolet Hills Unit 1 is
obtained under two long-term agreements. The Company and Southwestern Electric
Power Company (SWEPCO), each a 50% owner of Dolet Hills Unit 1, have entered
into agreements pursuant to which each acquired an undivided 50% interest in the
other's leased and owned lignite reserves in northwestern Louisiana. The Company
and SWEPCO have also entered into a long-term agreement with the Dolet Hills
Mining Venture for the mining and delivery of such lignite reserves, which
reserves are expected to provide a substantial portion of the fuel requirements
for the projected operating life of Dolet Hills Unit 1. The price of lignite
delivered pursuant to the agreement is a base price per ton, subject to
escalation based on certain inflation indices, plus specified "pass-through"
costs. Additional spot lignite may be obtained through competitive bidding.
Additionally, the Company and SWEPCO, have entered into a long-term
agreement with Red River Mining Co., a joint venture of the North American Coal
Corporation and Phillips Coal Company, which provides for base contract
purchases and spot purchases of lignite. The Company's minimum annual purchase
requirement is 275,000 tons. The base lignite price under the contract is a base
price per MMMBtu, subject to escalation, plus certain pass-through costs, while
the spot lignite price is determined through competitive bidding.
4
The continuous supply of coal and lignite from the mining sources may be
subject to interruption due to adverse weather conditions or other factors which
may disrupt mining operations or transportation. At December 31, 1995, the
Company's coal inventory at Rodemacher Unit 2 was approximately 72,000 tons
(about a 33-day supply) and the Company's lignite inventory at Dolet Hills
Unit 1 was approximately 210,000 tons (about a 37-day supply).
OIL SUPPLY
The Company stores fuel oil as an alternative fuel source. Rodemacher
Power Station has storage capacity for an approximate 75-day supply, and other
generating stations have storage capacity totaling about a 20-day supply.
However, in accordance with the Company's current fuel oil inventory practices,
at December 31, 1995, the Company had between 5 to 10 days supply of fuel oil
stored at its generating stations. During 1995, 1,147 barrels of fuel oil were
burned. The Company has been able to obtain fuel oil by spot purchases as
needed.
POWER PURCHASES
The Company purchases electric energy from neighboring utilities when the
price of the energy purchased is less than the cost to the Company of generating
such energy from its own facilities. Additionally, the Company has a long-term
contract under which it purchases a small percentage of its total energy
requirements from a hydroelectric generating plant. During 1995, the Company
purchased 1,430 million KWH of electricity, or approximately 19% of its total
energy requirements.
SALES
The Company is a "public utility" engaged principally in the generation,
transmission, distribution and sale of electricity within Louisiana. For further
information regarding the Company's generating stations and its transmission and
distribution facilities, see "Power Generation" above and "Properties" in Item 2
of this report. The following table sets forth information concerning sales by
the Company to various classes of customers for each of the last three years.
SALES (MILLION KWH)
-------------------------------
1995 1994 1993
----- ----- -----
Residential ............................. 2,763 2,532 2,470
Commercial .............................. 1,265 1,180 1,109
Industrial .............................. 2,227 2,030 2,005
Other retail ............................ 502 487 463
Sales for resale ........................ 360 210 175
----- ----- -----
Total sales to regular customers ..... 7,117 6,439 6,222
Short-term sales to other utilities ..... 68 174 266
----- ----- -----
Total kilowatt-hour sales ............ 7,185 6,613 6,488
===== ===== =====
The Company's 1995 system peak demand occurred in August and was 1,473,000
kilowatts. Sales and peak demand are affected by seasonal demand influenced by
weather and are generally highest during the summer air-conditioning and winter
heating seasons. The financial effects of seasonal demand on the Company's
quarterly operating results are listed in Note L to the Consolidated Financial
Statements on page 32 of the 1995 Annual Report to Shareholders, which is filed
as Exhibit 13 to this report and incorporated herein by reference.
5
The Company expects the peak demand on the system to grow at a compound
annual rate of approximately 1.9% over the next ten years. The Company's
capacity reserve margin for 1995 was 14.0%. The Company believes it can
economically meet the anticipated growth in customer demand by such measures as
refurbishing, by the year 2000, two existing gas-fired units not currently being
used or by purchasing the needed capacity on the wholesale market.
No customer accounted for 10% or more of the Company's revenues in 1995.
Additional information regarding the Company's sales and revenues is set forth
"Results of Operations" in "Management's Discussion and Analysis" on pages 15
and 16 of the 1995 Annual Report to Shareholders, which is filed as Exhibit 13
to this report and incorporated herein by reference.
CONSTRUCTION AND FINANCING
For information on the Company's construction program, financing and
related matters, see "Financial Condition" under "Management's Discussion and
Analysis" on pages 17 through 19 of the 1995 Annual Report to Shareholders,
which is filed as Exhibit 13 to this report and incorporated herein by
reference.
REGULATORY AND ENVIRONMENTAL MATTERS
RATES
Retail electric operations of the Company are subject to the jurisdiction
of the Louisiana Public Service Commission (LPSC) with respect to rates,
standards of service, accounting and other matters. The LPSC establishes base
rates based upon nonfuel costs, including the cost of capital, and sales. The
Company is also subject to the jurisdiction of the Federal Energy Regulatory
Commission (FERC) with respect to certain aspects of its electric business,
including rates for wholesale service and interconnections with, and the
transmission of power for, other utilities. Periodically, the Company has sought
and received increases in base rates from both the LPSC and the FERC to cover
increases in operating costs and costs associated with additions to generation,
transmission and distribution facilities.
The Company's electric rates include a fuel and purchased power cost
adjustment clause which enables the Company to reflect monthly fluctuations in
the cost of fuel and short-term purchased power. Additionally, pretax income
from certain off-system sales to other utilities is passed on to customers
through the fuel cost adjustment clause. Fuel costs and fuel adjustment billing
factors are approved by the LPSC and the FERC. These cost adjustments are based
on costs from earlier periods which result in over or under-recovery for the
period in which the adjustment is made. Any over or under-recovery is corrected
by adjustment in later periods. As of December 31, 1995, the net accumulated
balance of over-recovery on sales subject to the LPSC's jurisdiction was
approximately $3.7 million.
For information concerning an ongoing LPSC earnings review of the Company,
see "Regulatory Matters" below.
6
FRANCHISES
The Company operates under nonexclusive franchise rights granted by
governmental units and enforced by state regulation. These franchises are for
fixed terms, which vary from 10 years to 50 years. In the past, the Company has
been successful in the timely renewal of franchises as each reaches the end of
its term and expires. The citizens of Leesville (approximately 5,000 customers)
voted to approve a 20-year franchise with the Company in 1995.
ENERGY POLICY ACT OF 1992
The Energy Policy Act, adopted in October 1992, significantly changed U.S.
energy policy, including that governing the electric utility industry. The
Energy Policy Act allows the FERC, on a case-by-case basis and with certain
restrictions, to order wholesale transmission access and to order electric
utilities to enlarge their transmission systems. The Energy Policy Act does,
however, prohibit FERC-ordered retail wheeling (I.E., opening up the electric
utility systems to allow customer choice of energy suppliers at the retail
level), including "sham" wholesale transactions. Further, under the Energy
Policy Act an FERC transmission order requiring a transmitting utility to
provide wholesale transmission services must include provisions generally that
permit the utility to recover from the FERC applicant all of the costs incurred
in connection with the transmission services, any enlargement of the
transmission system and associated services.
In addition, the Energy Policy Act revised the Public Utility Holding
Company Act of 1935 (the Holding Company Act) to permit utilities, including
registered holding companies, and non-utilities to form "exempt wholesale
generators" without the principal restrictions of the Holding Company Act. Under
prior law, independent power producers were generally required to adopt
inefficient and complex ownership structures to avoid pervasive regulation under
the Holding Company Act. Management believes that the Energy Policy Act will
make wholesale markets more competitive.
REGULATORY MATTERS
The LPSC has elected to review the earnings of all electric, gas, water
and telecommunication utilities regulated by it to determine if the returns on
equity of these companies may be higher than returns that might be awarded in
the current economic environment. The LPSC began its review of the Company in
August 1995. Resolution of the earnings review, which is not subject to any
statutory or procedural deadlines, is expected in 1996. Although the Company's
rates are among the lowest in the state, the Company cannot predict the outcome
of the LPSC review or the effect on the Company's financial position, results of
operations, or cash flows.
For more information on regulatory matters, including proposed rulemakings
by the FERC on open transmission access, recovery of stranded cost, and
regulatory accounting, affecting the Company, see "Regulatory Matters" in
"Management's Discussion and Analysis" on page 19 of the 1995 Annual Report to
Shareholders, which is filed as Exhibit 13 to this report and incorporated
herein by reference.
7
COMPETITION
The LPSC does not provide exclusive service territories for electric
utilities under its jurisdiction. Instead, retail service is obtained through
long-term, nonexclusive franchises. The LPSC has used a "300 foot rule" for
determining the supplier for new customers. The application of this rule has led
to competition with neighboring utilities for retail customers at the borders of
the Company's service areas. The Company also competes in its service area with
suppliers of alternative forms of energy, some of which may be less costly for
certain applications than electricity. The Company could experience some
competition for electric sales to industrial customers in the form of
cogeneration or independent power producers. However, the Company believes that
its rates, and the quality and reliability of its service, places it in a
favorable competitive position in current retail markets.
Wholesale energy markets, including the market for wholesale electric
power, have been competitive, and are becoming even more so as the number of
competitors in these markets increases as a result of enactment of the Energy
Policy Act. The Company competes with other public utilities, cogenerators and
qualified facilities in other forms for sales of electric power at wholesale.
Under the Energy Policy Act, any participant in the wholesale market can obtain
a FERC order requiring transmission services be provided by the Company under
certain conditions.
Various federal and state legislative and regulatory bodies are
considering a number of issues in addition to those discussed above that will
shape the future of the electric utility industry. Such issues include the
extent of any deregulation of retail electricity sales, the ability of electric
utilities to recover stranded costs, the repeal or modification of the Public
Utility Holding Company Act of 1935, the unbundling of vertically integrated
electric utility companies into separate business segments or companies (i.e.,
transmission, distribution and generation), the role of electric utilities,
independent power producers and competitive bidding in the construction and
operation of new generating capacity, and the pricing of transmission service on
an electric utility's transmission system. Currently, there are no formal
actions relating to these issues pending before either the Louisiana legislature
or the LPSC. While the Company is unable to predict the outcome of such issues
or their effect on the Company's financial position, results of operations or
cash flows at this time, the Company plans to meet the challenges fostered by
this developing environment by continuing its planned course of action.
First, the Company intends to retain its low-cost supplier status by
continuing to enhance customer service while reducing costs. In 1993 the Company
conducted an organizational effectiveness study which resulted in a plan to
improve operations and provide better customer service at lower costs. As a
result of this study, the Company's organizational structure was streamlined in
1993. The second phase of the Company's reorganization plan commenced in May
1995, when the Company began operating a statewide customer call center to
handle customer calls 24 hours a day, seven days a week. Furthermore, the
Company consolidated 25 customer service offices located throughout the service
territory into 10 regional offices. These regional offices only handle walk-in
business while the call center now handles customer business by telephone. For
those customers who prefer to pay their bills in person, the Company implemented
a payment network of about 60 local businesses in the communities where customer
service offices were closed. This arrangement offers customers more locations
and extended business hours for paying their bills.
Second, the Company has adopted a strategy of adding retail customers near
its present retail markets. The Company's efforts to acquire Teche Electric
Cooperative, Inc. (Teche) are part of this strategy. The Company's purchase and
sale aggrement with Teche expires March 31, 1996, and the Company is currently
negotiating to extend the agreement. For more information on acquisition
efforts, see "Results of Operations - Co-op Developments" in "Management's
Discussion and Analysis" on page 16 of the 1995 Annual Report to Shareholders,
which information is filed as Exhibit 13 to this report and incorporated into
Part II herein by reference.
Additionally, in recent years, the Company has been successful in
competing for wholesale sales within its service territory, including short-term
sales to the city of Alexandria and a full requirements sale to the city of St.
Martinville. Sales under the St. Martinville agreement, which is subject to the
jurisdiction of the FERC, began in May 1995 and represent an approximate 13 MW
load. Sales to St. Martinville are expected to provide additional base revenues,
net of facility payments, of about
8
$4 million over the term of the agreement, which extends through December 2000.
This contract was challenged in 1993 by the previous supplier, Louisiana Energy
and Power Authority (LEPA), as well as the city of Lafayette and the American
Public Power Association, with assertions of preferential, discriminatory and
predatory pricing. An initial decision of the FERC's presiding administrative
law judge (ALJ) in February 1995 rejected LEPA's arguments. Under FERC
procedures, LEPA has filed a brief requesting the FERC to revise the initial
decision. The Company has opposed LEPA's brief.
Management believes that the ALJ's initial decision will be upheld.
At this time it is not possible to predict what changes to the electric
utility industry will emerge as a result of any federal or state regulatory and
legislative initiatives or from specific regulatory decisions of the LPSC or the
FERC, or the impact of such changes on the Company. It seems likely that such
changes will ultimately increase the competition the Company faces in supplying
electric energy to its customers.
ENVIRONMENTAL QUALITY
The Company is subject to numerous laws and regulations administered by
federal, state and local authorities to protect the environment. These statutory
and regulatory provisions impose various substantive requirements, the violation
of which may result in substantial fines and penalties. Environmental
requirements continue to increase as a result of new legislation, administrative
actions and judicial interpretations. Therefore, the precise future effects of
existing and potential requirements are difficult to determine. During 1995, the
Company's capital expenditures related to environmental compliance were about
$1.2 million and such expenditures are estimated to total about $1.4 million in
1996.
Air Quality
The State of Louisiana regulates emissions from each of the Company's
generating units through regulations issued by the Air Quality Division (AQD) of
the Louisiana Department of Environmental Quality (LDEQ). In addition, the AQD
implements certain programs initially established by the federal Environmental
Protection Agency (EPA). The AQD requires permits for certain generating units
on which construction commenced after the effective date of the applicable
regulation. The Company's three generating units which are subject to the AQD
permitting rules, Rodemacher Units 1 and 2 and Dolet Hills Unit 1, have received
AQD permits.
The federal Clean Air Act Amendments of 1990 (the Act) established a
regulatory program to address the effects of acid rain and imposed restrictions
on sulfur dioxide (SO2) emissions from certain utility units. The Act
essentially requires that utilities, like the Company, must hold a regulatory
"allowance" for each ton of SO2 emitted beginning in the year 2000. The EPA is
required to allocate a set number of allowances to each affected unit based on
its historic emissions. After the initial allocation the Company requested an
adjustment to the allowance allocation for Rodemacher Unit 2 because of an
extended outage of the unit during one of the years used in the EPA's
calculation. Because the final allowance allocation did not reflect the
requested adjustment, the Company filed a petition for judicial review of the
EPA's action on May 21, 1993 in the United States Court of Appeals for the
District of Columbia Circuit. In October 1995, the EPA signed a settlement
agreement in which it agreed to give Rodemacher Unit 2 the additional allowances
requested. The EPA should issue a notice of proposed rulemaking in 1996
describing the terms of the settlement agreement.
9
The Act also requires the EPA to revise nitrogen oxides (NOx) emission
limits for existing coal-fired boilers. In March 1994, the EPA lowered the NOx
emission rate for certain boilers, including Rodemacher Unit 2 and Dolet Hills
Unit 1. Rodemacher Unit 2 and Dolet Hills Unit 1 will have to meet this new
emission rate by January 1, 2000. The EPA has recently proposed to lower the NOx
emission rate further. The Company is evaluating its options under these NOx
rules, including the option of "early election." Early election would require
the Company to meet the revised NOx rate by 1997 instead of 2000, but would
protect the Company from any future reductions in the NOx permitted emission
rate until 2008. Significant reductions in NOx emission limits may require
modification of burners or other capital improvements at either or both of the
units.
The Act also requires the installation of continuous emission monitoring
systems (CEMS) on seven of the Company's generating units affected by the acid
rain program. Installation of the CEMS has been completed at a cost of
approximately $2.9 million.
Title V of the Act requires certain utility and industrial facilities to
obtain operating permits. States are required to develop operating permit
programs as part of their State Implementation Plans. In November 1993 the LDEQ
promulgated new regulations to comply with the requirements of Title V of the
Act and the EPA approved the state program in 1995. Title V operating permit
applications must be submitted to the LDEQ by October 1996. The operating
permits will contain acid rain permit requirements, as well as other
requirements of existing state and federal air programs.
Title V of the Act allows states to collect fees up to $25 per ton of
regulated emissions to support their operating permit programs. Fee assessments
on the Company's affected units have already increased because of this
provision. The LDEQ currently charges $9 per ton and that amount is expected to
increase.
Water Quality
The Company has received from the EPA all National Pollutant Discharge
Elimination System (NPDES) permits required under the Clean Water Act for
discharges from its four generating stations. NPDES permits have fixed dates of
expiration, and the Company has applied for renewal of these permits within the
applicable time periods. The Office of Water Resources of the LDEQ requires
facilities which discharge wastewater into Louisiana waters to be permitted
under the Louisiana Water Discharge Permit System (LWDPS). The Company has
applied for and received LWDPS permits for its four generating stations.
The most recently issued NPDES permit for Dolet Hills Unit 1 contained an
Administrative Order requiring biomonitoring of the discharge from the
impoundment associated with the Fly Ash/Scrubber Sludge Landfill. Because the
discharge from this impoundment failed all or part of the biomonitoring test at
various times during the testing schedule specified in the permit, the Company
has had discussions with the EPA regarding the results. The Company does not
expect administrative action on the part of the EPA until the NPDES permit is
renewed in 1997. At that time, the EPA may set
10
a biomonitoring limit in the NPDES permit. Violation of that limit may then
require submittal of a plan describing options for reducing certain constituents
in the discharge to the EPA. None of the options, if implemented, would affect
the operation of the unit, or involve a significant increase in the Company's
five-year construction plan.
Solid Waste Disposal
The Solid Waste Division of the LDEQ has adopted regulations and a
permitting system for the management and disposal of solid waste generated by
electric utilities. The Company has received all required permits from the Solid
Waste Division for the on-site disposal of solid waste generated at its
generating stations.
The Company has requested approval of an alternate liner system for the
Dolet Hills landfill facility and has received conditional approval from the
LDEQ. The Company is in the process of obtaining additional information to
submit to the LDEQ, which will make the approval permanent. The exemption, if
granted, is expected to save $360,000 to $900,000 per year in operating costs at
the landfill.
Hazardous Waste Generation
The Company produces certain wastes at its four generating stations and at
other locations which are classified as hazardous. The Hazardous Waste Division
of the LDEQ regulates these wastes and has issued identification numbers to the
sites where such wastes are produced. The Company does not treat, store or
dispose of these wastes on-site; therefore, no permits are required. All
hazardous wastes produced by the Company are disposed of at federally permitted
hazardous waste disposal sites.
PCB Disposal
In 1986 the Company was named a Potentially Responsible Party (PRP) by the
EPA under the Comprehensive Environmental Response, Compensation, and Liability
Act of 1980 (CERCLA) for its involvement at the Rose Chemicals (Rose)
polychlorinated biphenyl (PCP) disposal site in Holden, Missouri. The Company,
along with other PRPs, has entered into two Administrative Orders on Consent
with Region VII of the EPA for the removal of certain PCB materials from the
site. These materials have now been removed and disposed of at federally
permitted PCB disposal facilities. All clean-up activities at the site were
completed in 1995. The removal and disposal were funded by contributions from
the parties involved into a trust fund established for the clean-up. The site
will now be monitored over the next eight to ten years. To date, the Company has
contributed $142,000, net, to the trust fund.
The Company has complied with the requirements established by the EPA for
the general removal from service and disposal of certain equipment containing
PCBs. The EPA has authorized the continued use of such equipment in locations
where its use does not pose an exposure risk, and the Company uses such
equipment only in restricted or remote areas. In 1995, the Company spent
$262,000 on the disposal of PCB materials used in its system.
11
ELECTROMAGNETIC FIELDS
The possibility that exposure to electromagnetic fields (EMF) emanating from
power lines, household appliances and other electric devices may result in
adverse health effects or damage to the environment has been a subject of
current public attention. The scientific research conducted to date concerning
the effects of EMFs has not led to any definitive results, however, such
research is continuing. Lawsuits have arisen in several states against electric
utilities and others alleging that the presence or use of electric power
transmission and distribution lines has an adverse effect on health and/or
property values.
OTHER EVENTS
Cajun Electric Power Cooperative (Cajun)
Cajun, which provides power to the state's 12 electric distribution
cooperatives, is in Chapter 11 bankruptcy. Cajun's energy is supplied from its
share of a nuclear generating unit and several coal and gas-fired units it owns.
With Cajun in bankruptcy proceedings, the disposition of its assets is under
consideration, and the bankruptcy court trustee has asked for bids from
interested parties. In an effort to grow the Company's power supply business,
the Company, along with a non-utility company, submitted a joint bid on March 8,
for Cajun's nonnuclear generation assets and wholesale contracts. If the
Company's bid were to be accepted, closing of the transaction is subject to
approval of the bankruptcy trustee, Cajun's creditors, and various governmental
and regulatory agencies including the LPSC, the Rural Utilities Service, and the
FERC. An estimated 1,683 megawatts of generating capacity is involved as well as
91 megawatts of firm hydroelectric purchases. The wholesale contracts include
1,362 megawatts of wholesale co-op load and 300 megawatts of firm sales. The
Company has no nuclear generation and is not proposing to acquire Cajun's share
of a nuclear generating unit.
ITEM 2. PROPERTIES
All of the Company's electric generating stations and all other operating
properties are located in the State of Louisiana. The Company considers all of
its properties to be well maintained, in good operating condition and suitable
for their intended purposes.
ELECTRIC GENERATING STATIONS
As of December 31, 1995, the Company either owned or had an ownership
interest in four steam electric generating stations and a gas turbine with a
combined electric generating capacity of 1,693,000 kilowatts. For additional
information regarding the Company's generating facilities, see "Electric
Operations - Power Generation" in Item 1 of this report.
SUBSTATIONS
As of December 31, 1995, the Company owned 80 transmission substations and
308 distribution substations.
12
ELECTRIC LINES
As of December 31, 1995, the Company's transmission system consisted of
approximately 67 circuit miles of 500 kilovolt (KV) lines; 454 circuit miles of
230 KV lines; 648 circuit miles of 138 KV lines; and 21 circuit miles of 69 KV
lines. The Company's distribution system consisted of approximately 2,057
circuit miles of 34.5 KV lines and 10,524 circuit miles of other lines.
GENERAL PROPERTIES
The Company owns various properties which include a seven-story
headquarters office building, regional offices, a central warehouse, service
centers, telecommunications equipment and other facilities owned for general
purposes.
TITLE
The Company's electric generating plants and certain other principal
properties are owned in fee. Electric transmission and distribution lines are
located either on private rights-of-way or along streets or highways by public
consent.
Substantially all of the Company's property, plant and equipment is
subject to liens securing obligations of the Company under an Indenture of
Mortgage, none of which impairs the use of such properties in the operation of
its business.
ITEM 3. LEGAL PROCEEDINGS
The Company is not aware of any legal proceeding to which it is a party
which would have a material adverse effect on its financial condition, results
of operations, cash flows, or competitive position. For a discussion of certain
legal proceedings and regulatory matters involving the Company, see (i)
"Regulatory and Environmental Matters - Competition" "- Regulatory Matters", and
"- Environmental Quality" in Item 1 of this report and (ii) "Results of
Operations-Nonfuel Operating Expenses and Income Taxes" in "Management's
Discussion and Analysis" on pages 16 and 17 of the 1995 Annual Report to
Shareholders, which sections are incorporated herein by reference.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
There were no matters submitted to a vote of security holders of the
Company during the fourth quarter of 1995.
13
EXECUTIVE OFFICERS OF THE REGISTRANT
The names of the executive officers of the Company, their positions held,
five-year employment history, ages and years of service as of December 31, 1995,
are presented below. Executive officers are appointed annually to serve for the
ensuing year or until their successors have been appointed.
POSITION AND FIVE-YEAR
NAME OF EXECUTIVE OFFICER EMPLOYMENT HISTORY
- ------------------------- ------------------
Gregory L. Nesbitt....... President and Chief Executive Officer since April
1993; President and Chief Operating Officer from April
1992 to April 1993; Executive Vice President and Chief
Operating Officer from July 1991 to April 1992;
Executive Vice President from January 1988 to July
1991. (Age 57; 15 years of service)
Robert L. Duncan......... Vice President-Customer Operations since July 1984.
(Age 53; 30 years of service)
David M. Eppler.......... Vice President-Power Supply and Energy Transmission
since July 1995; Vice President-Finance from October
1993 to July 1995; Vice President and Treasurer from
July 1987 to October 1993. (Age 45; 14 years of
service)
Leonard G. Fontenot...... Vice President from July 1995 to date of retirement
January 1,1996; Vice President-Power Supply and
Energy Transmission from April 1986 to July 1995.
(Age 58; 33 years of service)
Catherine C. Scheffler... Vice President-Employee and Support Services since
July 1995;Vice President-Human Resources from October
1993 to July 1995; General Manager-Human Resources
from August 1993 to October 1993; Administrator-
Compensation from May 1991 to August 1993; Vice
President at Rapides Bank And Trust Company from
December 1987 to April 1991 (Age 40; 4 years of
service)
David K. Warner.......... Vice President-Finance and Chief Financial Officer
since July 1995;Vice President-Administrative Services
from April 1988 to July 1995. (Age 45; 15 years of
service)
John L. Baltes, Jr....... Controller since April 1989. (Age 49; 14 years of
service)
14
POSITION AND FIVE-YEAR
NAME OF EXECUTIVE OFFICER EMPLOYMENT HISTORY
- ------------------------- ----------------------
Michael P. Prudhomme..... Secretary-Treasurer since January 1994; Secretary from
October 1993 to January 1994; Vice President-Customer
Services from May 1985 to October 1993. (Age 52; 26
years of service)
Judy P. Miller........... Assistant Corporate Secretary since April 1995; Acting
Assistant Corporate Secretary from February 1995 to
April 1995; Supervisor-Plant Accounting from October
1993 to February 1995; Supervisor-Income and Other
Taxes from June 1990 to October 1993. (Age 38; 11
years of service)
15
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
The Company's common stock is listed for trading on the New York Stock
Exchange (NYSE) and the Pacific Stock Exchange. The following table sets forth
high and low sales prices for the Company's common stock as reported on the NYSE
Composite Tape and dividends paid per share during each calendar quarter of 1995
and 1994.
1995 1994
---------------------------------- ----------------------------------
HIGH LOW DIVIDEND HIGH LOW DIVIDEND
------- ------- ------ ------- ------- ------
First Quarter $24-1/2 $22 $0.365 $24-7/8 $21-1/4 $0.355
Second Quarter $24-1/2 $22-1/8 $0.375 $25-5/8 $22-1/4 $0.365
Third Quarter $25-5/8 $22-1/4 $0.375 $24-3/8 $21-1/4 $0.365
Fourth Quarter $28-1/8 $25-1/4 $0.375 $23-5/8 $20-7/8 $0.365
Subject to the prior rights of the holders of the respective series of the
Company's preferred stock, such dividends as determined by the Board of
Directors of the Company may be declared and paid on the common stock from time
to time out of funds legally available therefor. The provisions of the Company's
charter applicable to preferred stock and certain provisions contained in the
debt instruments of the Company under certain circumstances restrict the amount
of retained earnings available for the payment of dividends by the Company. The
most restrictive covenant requires that common shareholders' equity be not less
than 30% of total capitalization, including short-term debt. At December 31,
1995, approximately $144,000,000 of retained earnings was not restricted. On
January 26, 1996 the Board of Directors of the Company declared a quarterly
dividend of $0.375 per share, which dividend was paid on February 15, 1996, to
common shareholders of record on February 5, 1996.
As of March 15, 1996, there were 12,081 holders of record of the Company's
common stock, and the closing price of the Company's common stock as reported on
the NYSE Composite Tape was $25.875 per share.
ITEM 6. SELECTED FINANCIAL DATA
The following table sets forth certain selected financial data for the
respective periods presented and should be read in conjunction with the
Consolidated Financial Statements and the related Notes thereto set forth on
pages 20 through 33 in the 1995 Annual Report to Shareholders, which is filed as
Exhibit 13 to this report and incorporated herein by reference.
16
FOR THE YEARS ENDED DECEMBER 31,
--------------------------------------------------------------------------
1995 1994 1993 1992 1991
---------- ---------- ---------- -------- --------
FINANCIAL DATA (IN THOUSANDS, EXCEPT
PER SHARE AMOUNTS AND RATIOS)
Statement of Income Data
Operating revenues ............................. $ 394,426 $ 379,603 $ 382,433 $351,613 $343,350
Net income ..................................... $ 48,703 $ 45,043 $ 41,812 $ 45,239 $ 44,929
Net income applicable
to common stock .............................. $ 46,651 $ 43,017 $ 39,827 $ 43,010 $ 42,957
Primary net income
per common share (1) ......................... $ 2.08 $ 1.92 $ 1.78 $ 1.93 $ 1.92
Fully diluted net income
per common share (1) ......................... $ 2.01 $ 1.86 $ 1.73 $ 1.89 $ 1.87
Cash dividends paid per
common share (1) ............................. $ 1.490 $ 1.450 $ 1.410 $ 1.370 $ 1.325
Ratio of earnings to
fixed charges ................................ 3.49x 3.35x 3.30x 3.16x 2.99x
Ratio of earnings to
combined fixed charges and
preferred stock dividends .................... 3.17x 3.02x 2.96x 2.83x 2.73x
Balance Sheet Data
(at end of period)
Total assets ................................... $1,226,034 $1,178,191 $1,161,635 $978,220 $973,472
Long-term obligations and
redeemable preferred stock ................... $ 367,432 $ 343,509 $ 358,329 $318,214 $400,605
OPERATING STATISTICS
Electric sales - regular system
customers (million KWH)
Residential ................................... 2,763 2,532 2,470 2,353 2,313
Commercial .................................... 1,265 1,180 1,109 1,062 1,043
Industrial .................................... 2,227 2,030 2,005 1,972 1,928
Other retail .................................. 502 487 463 477 464
Sales for resale .............................. 360 210 175 146 141
---------- ---------- ---------- -------- --------
Total sales to regular customers ................ 7,117 6,439 6,222 6,010 5,889
Short-term energy sales to other
utilities (million KWH) ......................... 68 174 266 88 121
---------- ---------- ---------- -------- --------
Total electric sales .......................... 7,185 6,613 6,488 6,098 6,010
========== ========== ========== ======== ========
System peak (thousand kilowatts) .................. 1,473 1,310 1,346 1,308 1,233
Electric customers ................................ 220,923 217,568 212,559 213,941 211,332
- --------------
(1) All prior-period per share amounts have been restated to reflect a
two-for-one stock split effective in May 1992.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
The information set forth in "Management's Discussion and Analysis" on pages
15 through 19 of the Company's 1995 Annual Report to Shareholders is
incorporated herein by reference; such information is filed as Exhibit 13 to
this report.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The information set forth on pages 20 through 33 in the 1995 Annual Report to
Shareholders is incorporated herein by reference; such information is filed as
Exhibit 13 to this report.
17
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The information set forth (i) under the subcaption "Directors"
under the caption "Election of Directors" and (ii) in the last paragraph under
the caption "Security Ownership of Directors and Management" in the Company's
definitive Proxy Statement dated March 5, 1996, filed with the Securities and
Exchange Commission pursuant to Regulation 14A under the Securities Exchange Act
of 1934 (1996 Proxy Statement), is incorporated herein by reference. See also
"Executive Officers of the Registrant" on pages 14 and 15 of this report.
ITEM 11. EXECUTIVE COMPENSATION
The information set forth under the subcaption "Organization and
Compensation of the Board of Directors" under the caption "Election of
Directors" and under the caption "Executive Compensation" in the 1996 Proxy
Statement (excluding the information required by paragraphs (k) and (l) of Item
402 of Regulation S-K) is incorporated herein by reference.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The information set forth under the caption "Security Ownership
of Directors and Management" and under the caption "Security Ownership of
Certain Beneficial Owners" in the 1996 Proxy Statement is incorporated herein by
reference.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The information set forth under the subcaption "Directors" under
the caption "Election of Directors" in the 1996 Proxy Statement is incorporated
herein by reference.
18
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULE, AND REPORTS ON FORM 8-K
REFERENCE (PAGE)
---------------------------------
1995 ANNUAL
FORM 10-K REPORT TO
ANNUAL REPORT SHAREHOLDERS
------------- ------------
14(a)(1) Consolidated Financial Statements and Supplementary Data on
pages 20 through 33 in the Company's 1995 Annual Report to
Shareholders are filed as Exhibit 13 to this report and are
incorporated herein by reference.
Consolidated Statements of Income for the years ended
December 31, 1995, 1994 and 1993 20
Consolidated Balance Sheets at December 31, 1995 and
1994 21
Consolidated Statements of Cash Flows for the years
ended December 31, 1995, 1994 and 1993 22
Consolidated Statements of Changes in Common
Shareholders' Equity for the years ended
December 31, 1995, 1994 and 1993 23
Notes to Consolidated Financial Statements 24
Report of Independent Accountants 33
14(a)(2) Financial Statement Schedules
Report of Independent Accountants 26
Schedule II - Valuation and Qualifying Accounts 27
Financial Statement Schedules other than those shown in the
above index are omitted because they are either not required
or are not applicable or the required information is shown in
the Consolidated Financial Statements and Notes thereto.
19
14(a)(3) List of Exhibits
The Exhibits designated by an asterisk are filed herewith. The Exhibits not so
designated have been previously filed with the Securities and Exchange
Commission, and are incorporated herein by reference. The Exhibits designated by
two asterisks are management contracts and compensatory plans and arrangements
required to be filed as Exhibits to this report.
SEC FILE OR REGISTRATION
REGISTRATION STATEMENT EXHIBIT
EXHIBITS NUMBER OR REPORT NUMBER
- ----------------------------------------------------------- ------------ ----------- -------
3(a) Restated Articles of Incorporation of the 1-5663 10-Q(3/92) 3
Company dated as of July 24, 1989,
as amended through April 24, 1992
* 3(b) Amended and Restated Bylaws of the
Company, as amended to March 5, 1996
4(a)(1) Indenture of Mortgage dated as of July 1, 2-27284 S-1(10/17/67) 4(b)(1)
1950, between the Company and First
National Bank of New Orleans, as Trustee
4(a)(2) First Supplemental Indenture dated as 2-27284 S-1(10/17/67) 4(b)(2)
of October 1, 1951, to Exhibit 4(a)(1)
4(a)(3) Second Supplemental Indenture dated as 2-27284 S-1(10/17/67) 4(b)(3)
of June 1, 1952, to Exhibit 4(a)(1)
4(a)(4) Third Supplemental Indenture dated as 2-27284 S-1(10/17/67) 4(b)(4)
of January 1, 1954, to Exhibit 4(a)(1)
4(a)(5) Fourth Supplemental Indenture dated as 2-27284 S-1(10/17/67) 4(b)(5)
of November 1, 1954, to Exhibit 4(a)(1)
4(a)(6) Tenth Supplemental Indenture dated as 1-5663 10-K(1986) 4(a)(11)
of September 1, 1965, to Exhibit 4(a)(1)
4(a)(7) Eleventh Supplemental Indenture dated 2-32069 S-9(4/7/69) 2(m)
as of April 1, 1969, to Exhibit 4(a)(1)
4(a)(8) Eighteenth Supplemental Indenture dated as 1-5663 10-K(1993) 4(a)(8)
of December 1, 1982, to Exhibit 4(a)(1)
4(a)(9) Nineteenth Supplemental Indenture dated as 1-5663 10-K(1993) 4(a)(9)
of January 1, 1983, to Exhibit 4(a)(1)
4(a)(10) Twenty-Sixth Supplemental Indenture dated as 1-5663 8-K(3/90) 4(a)(27)
of March 15, 1990, to Exhibit 4(a)(1)
4(a)(11) Twenty-Seventh Supplemental Indenture dated as 2-27284 S-1(10/17/67) 4(f)(1)
of July 15, 1991, to Exhibit 4(a)(1)
4(b) Indenture between the Company and Bankers 33-24896 S-3(10/11/88) 4(b)
Trust Company, as Trustee, dated as of
October 1, 1988
4(c) Trust Indenture (The Industrial Development 1-5663 10-K(1991) 4(i)
Board of the Parish of Rapides, Inc.
(Louisiana) Adjustable Tender Pollution
Control Revenue Refunding Bonds, Series 1991)
dated as of May 1, 1991, between The Industrial
Development Board of the Parish of Rapides, Inc.
and First National Bank of Commerce
20
4(c)(1) First Supplemental Trust Indenture (The Industrial 1-5663 10-K(1994) 4(e)(1)
Development Board of the Parish of Rapides, Inc.
(Louisiana) Adjustable Tender Pollution Control
Revenue Refunding Bonds, Series 1991) dated as
of May 1, 1993, between The Industrial
Development Board of the Parish of
Rapides, Inc. and First National Bank
of Commerce, relating to Exhibit 4(c)
4(d) Refunding Agreement (The Industrial 1-5663 10-Q(6/91) 10(a)
Development Board of the Parish of Rapides,
Inc. (Louisiana) Adjustable Tender Pollution
Control Revenue Refunding Bonds, Series
1991) dated as of May 1, 1991, between the
Company and The Industrial Development
Board of the Parish of Rapides, Inc.
4(e) Trust Indenture (Parish of DeSoto, State of 1-5663 10-K(1991) 4(k)
Louisiana Adjustable Tender Pollution Control
Revenue Refunding Bonds, Series 1991A) dated
as of May 1, 1991, between Parish of Desoto,
State of Louisiana and First National Bank of
Commerce
4(e)(1) First Supplemental Trust Indenture ( Parish 1-5663 10-K(1994) 4(g)(l)
of DeSoto, State of Louisiana Adjustable Tender
Pollution Control Revenue Refunding Bonds,
Series 1991A) dated as of May 1, 1993,
between the Parish of DeSoto, State of
Louisiana and First National Bank of Commerce,
relating to Exhibit 4(e)
4(f) Refunding Agreement (Parish of DeSoto, 1-5663 10-Q(6/91) 10(b)
State of Louisiana Adjustable Tender Pollution
Control Revenue Refunding Bonds, Series
1991A) dated as of May 1, 1991, between
the Parish of DeSoto, State of Louisiana
and the Company
4(g) Trust Indenture (Parish of DeSoto, State of 1-5663 10-K(1991) 4(m)
Louisiana Adjustable Tender Pollution
Control Revenue Refunding Bonds, Series 1991B)
dated as of May 1, 1991, between Parish of
DeSoto, State of Louisiana and First National
Bank of Commerce
4(g)(1) First Supplemental Trust Indenture (Parish 1-5663 10-K(1994) 4(i)(1)
of DeSoto, State of Louisiana Adjustable
Tender Pollution Control Revenue Refunding
Bonds, Series 1991B) dated as of May 1,
1993, between the Parish of DeSoto, State of
Louisiana and First National Bank of Commerce,
relating to Exhibit 4(g)
21
4(h) Refunding Agreement (Parish of DeSoto, 1-5663 10-Q(6/91) 10(c)
State of Louisiana Adjustable Tender Pollution
Control Revenue Refunding Bonds, Series
1991B) dated as of May 1, 1991, between
the Parish of DeSoto, State of Louisiana
and the Company
4(i) $100,000,000 Credit Agreement dated as of June 1-5663 10-Q(6/95) 4
15, 1995, among the Company, certain Banks
parties thereto, and The Bank of New York as
Agent
**10(a) 1990 Long-Term Incentive Compensation Plan 1-5663 1990 Proxy A
Statement (4/90)
**10(b) 1981 Incentive Stock Option Plan 1-5663 10-K(1992) 10(i)
***10(c) Annual Incentive Compensation Plan
**10(d) Deferred Compensation Plan for Directors 1-5663 10-K(1992) 10(n)
**10(e)(1) Supplemental Executive Retirement Plan 1-5663 10-K(1992) 10(o)(1)
**10(e)(2) Form of Supplemental Executive Retirement 1-5663 10-K(1992) 10(o)(2)
Plan Participation Agreement between the Company
and the following officers: Gregory L. Nesbitt,
Robert L. Duncan David M. Eppler, Leonard G.
Fontenot and David K. Warner
***10(f) Form of Executive Severance Agreement between
the Company and the following officers: Gregory
L. Nesbitt, Robert L. Duncan, David M. Eppler,
and David K. Warner
10(g)(1) Receivables Purchase Agreement, dated 1-5663 10-K(1994) 10(n)(l)
as of April 9, 1990, as Amended and Restated as
of March 1, 1995, among the Company, Corporate
Asset Funding Company, Inc. and Citicorp North
America, Inc.
10(g)(2) Receivables Purchase Agreement, dated 1-5663 10-K(1994) 10(n)(2)
as of April 9, 1990, as Amended and Restated as
of March 1, 1995, among the Company, Citicorp,
N.A. and Citicorp North America, Inc.
10(h)(1) Term Loan Agreement dated as of April 2, 1991, 1-5663 10-Q(3/91) 4(b)
among the 401(k) Savings and Investment Plan
ESOP Trust, the Company, as Guarantor, the
22
Banks listed therein and The Bank of New York,
as Agent, relating to Exhibit 10(m)
10(h)(2) Assignment and Assumption Agreement, effective 1-5663 10-Q(3/91) 4(c)
as of May 6, 1991, between The Bank of New York
and the Canadian Imperial Bank of Commerce,
relating to Exhibit 10(h)(1)
10(h)(3) Assignment and Assumption Agreement dated as of 1-5663 10-K(1991) 10(y)(3)
July 3, 1991, between The Bank of New York and
Rapides Bank and Trust Company in Alexandria,
relating to Exhibit 10(h)(1)
10(h)(4) Assignment and Assumption Agreement dated as of 1-5663 10-K(1992) 10(bb)(4)
July 6, 1992, among The Bank of New York, CIBC,
Inc. and Rapides Bank and Trust Company in
Alexandria, as Assignors, the 401(k) Savings and
Investment Plan ESOP Trust, as Borrower, and the
Company, as Guarantor, relating to Exhibit
10(h)(1)
10(i) Reimbursement Agreement (The Industrial 1-5663 10-Q(6/91) 4(a)
Development Board of the Parish of Rapides, Inc.
(Louisiana) Adjustable Tender Pollution Control
Revenue Refunding Bonds, Series 1991) dated as
of May 29, 1991, among the Company, various
financial institutions, Swiss Bank Corporation
and The First National Bank of Chicago
10(i)(1) Remarketing Agreement (The Industrial Development 1-5663 10-Q(9/94) 10(a)
Board of the Parish of Rapides, Inc. (Louisiana)
Adjustable Tender Pollution Control Revenue
Refunding Bonds, Series 1991) dated as of July
19,1994, between the Company and PaineWebber
Incorporated
10(i)(2) Tender Agreement (The Industrial Development Board 1-5663 10-K(1991) 10(z)(2)
of the Parish of Rapides, Inc. (Louisiana)
Adjustable Tender Pollution Control Revenue
Refunding Bonds, Series 1991) dated as of May 1,
1991, among First National Bank of Commerce, as
Trustee, the Company, The First National Bank of
Chicago, as Tender Agent and Registrar, Smith
Barney, Harris Upham & Co. Incorporated, as
Remarketing Agent, and Swiss Bank Corporation,
as Bank
10 (i)(3) Amendment No. 1 to Reimbursement Agreements (The 1-5663 10-K(1994) 10(p)(3)
Industrial Development Board of the Parish of
Rapides, Inc. (Louisiana) Adjustable Tender
Pollution Control
23
Revenue Refunding Bonds, Series 1991, 1991A and
1991B) dated as of December 9, 1994, among the
Company, various financial institutions, Swiss
Bank Corporation, New York Branch, as Issuer of
the Letters of Credit, and Swiss Bank
Corporation, New York Branch, as Agent, relating
to Exhibits 10(i), 10(j) and 10(k).
10(j) Reimbursement Agreement (Parish of DeSoto, 1-5663 10-Q(6/91) 4(b)
State of Louisiana Adjustable Tender Pollution
Control Revenue Refunding Bonds, Series 1991A)
dated as of May 29, 1991, among the Company,
various financial institutions, Swiss Bank
Corporation and The First National Bank of
Chicago
10(j)(1) Remarketing Agreement (Parish of DeSoto, State of 1-5663 10-Q(9/94) 10(b)
Louisiana Adjustable Tender Pollution Control
Revenue Refunding Bonds, Series 1991A) dated as
of July 19, 1994, between the Company and
PaineWebber Incorporated
10(j)(2) Tender Agreement (Parish of DeSoto, State of 1-5663 10-K(1991) 10(aa)(2)
Louisiana Adjustable Tender Pollution Control
Revenue Refunding Bonds, Series 1991A) dated as
of May 1, 1991, among First National Bank of
Commerce, as Trustee, the Company, The First
National Bank of Chicago, as Tender Agent and
Registrar, Smith Barney, Harris Upham & Co.
Incorporated, as Remarketing Agent, and Swiss
Bank Corporation, as Bank
10(k) Reimbursement Agreement (Parish of DeSoto, 1-5663 10-Q(6/91) 4(c)
State of Louisiana Adjustable Tender Pollution
Control Revenue Refunding Bonds, Series 1991B)
dated as of May 29, 1991, among the Company,
various financial institutions, Swiss Bank
Corporation and The First National Bank of
Chicago
10(k)(1) Remarketing Agreement (Parish of DeSoto, State of 1-5663 10-Q(9/94) 10(c)
Louisiana Adjustable Tender Pollution Control
Revenue Refunding Bonds, Series 1991B) dated as
of July 19, 1994, between the Company and
PaineWebber Incorporated
10(k)(2) Tender Agreement (Parish of DeSoto, State of 1-5663 10-K(1991) 10(bb)(2)
Louisiana Adjustable Tender Pollution Control
Revenue Refunding Bonds, Series 1991B) dated as
of May 1, 1991, among First National Bank of
Commerce,
24
as Trustee, the Company, The First National Bank
of Chicago, as Tender Agent and Registrar, Smith
Barney, Harris Upham & Co. Incorporated, as
Remarketing Agent, and Swiss Bank Corporation,
as Bank
10(l) Selling Agency Agreement between the Company 1-5663 8-K(2/92) 1
and Salomon Brothers Inc, The First Boston
Corporation and Smith Barney, Harris Upham & Co.
Incorporated dated as of February 27, 1992
10(m) 401(k) Savings and Investment Plan ESOP 1-5663 10-Q(3/91) 4(a)
Trust Agreement dated as of April 2, 1991,
between State Street Bank and Trust Company and
the Company
*10(m)(1) First Amendment to 401(k) Savings and Investment
Plan ESOP Trust Agreement dated as of July 30,
1993, between State Street Bank and Trust
Company and the Company
*11 Computation of Net Income Per Common Share
*12 Computation of Earnings to Fixed Charges
and Earnings to Combined Fixed Charges and
Preferred Stock Dividends
*13 Management's Discussion and Analysis of Financial
Condition and Results of Operations,
Consolidated Financial Statements and Notes and
Report of Independent Accountants
*23 Consent of Independent Accountants
*24 Power of Attorney from each Director of the Company
whose signature is affixed to this Form 10-K for
the year ended December 31, 1995
*27 Financial Data Schedule UT
14(b) Reports on Form 8-K
During the three-month period ended December 31, 1995, the Company filed no
current Reports on Form 8-K.
25
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors and Shareholders
of Central Louisiana Electric Company, Inc.:
Our report on the consolidated financial statements of Central Louisiana
Electric Company, Inc. has been incorporated by reference in this Form 10-K from
page 33 of the 1995 Annual Report to Shareholders of Central Louisiana Electric
Company, Inc. In connection with our audits of such financial statements, we
have also audited the related financial statement schedule listed in Item
14(a)(2) on page 19 of this Form 10-K. This financial statement schedule is the
responsibility of the Company's management. Our responsibility is to express an
opinion on this financial statement schedule based upon our audit.
In our opinion, the financial statement schedule referred to above, when
considered in relation to the basic financial statements taken as a whole,
present fairly, in all material respects, the information required to be
included therein.
COOPERS & LYBRAND L.L.P.
New Orleans, Louisiana
January 26, 1996
26
CENTRAL LOUISIANA ELECTRIC COMPANY, INC.
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
Years ended December 31, 1995, 1994 and 1993
(In thousands)
COL. A COL. B COL. C COL. D COL. E
- -----------------------------------------------------------------------------------------------------------------------
ADDITIONS UNCOLLECTIBLE
BALANCE AT CHARGED TO ACCOUNTS BALANCE AT
BEGINNING COST AND WRITE-OFFS, END
ALLOWANCE FOR UNCOLLECTIBLE ACCOUNTS OF PERIOD EXPENSES LESS RECOVERIES OF PERIOD (1)
- -----------------------------------------------------------------------------------------------------------------------
Year Ended December 31, 1995 ............ $444 $817 $723 $538
Year Ended December 31, 1994 ............ $537 $442 $535 $444
Year Ended December 31, 1993 ............ $779 $ 92 $334 $537
- ------------
(1) Deducted in the balance sheet
27
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, the Registrant has duly caused this report to be signed on its
behalf by the undersigned, thereunto duly authorized.
CENTRAL LOUISIANA ELECTRIC COMPANY, INC.
(REGISTRANT)
BY: GREGORY L. NESBITT
(Gregory L. Nesbitt, President
and Chief Executive Officer)
Date: March , 29 1996
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
Registrant and in the capacities and on the dates indicated.
SIGNATURE TITLE DATE
--------- ----- ----
GREGORY L. NESBITT President, Chief Executive Officer and Director March 29, 1996
(Gregory L. Nesbitt) (Principal Executive Officer)
DAVID K. WARNER Vice President, Finance and Chief Financial Officer March 29, 1996
(David K. Warner) (Principal Financial Officer)
JOHN L. BALTES, JR. Controller March 29, 1996
(John L. Baltes, Jr.) (Principal Accounting Officer)
SHERIAN G. CADORIA DIRECTOR*
J. PATRICK GARRETT DIRECTOR*
F. BEN JAMES, JR. DIRECTOR*
HUGH J. KELLY DIRECTOR*
A. DELOACH MARTIN, JR. DIRECTOR*
ROBERT T. RATCLIFF DIRECTOR*
EDWARD D. SIMMONS DIRECTOR*
ERNEST L. WILLIAMSON DIRECTOR*
*BY: DAVID K. WARNER
(David K. Warner, as March 29, 1996
Attorney-in-Fact)
28