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SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
/X/ Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange
Act of 1934 For the Fiscal Year Ended DECEMBER 31, 1997
/ / Transition Report Pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934 For the transition period from to
------------ ------------
Commission File No. 1-3548
MINNESOTA POWER & LIGHT COMPANY
(Exact name of registrant as specified in its charter)
Minnesota 41-0418150
(State or other jurisdiction (I.R.S. Employer
of incorporation or organization) Identification No.)
30 West Superior Street
Duluth, Minnesota 55802
(Address of principal executive offices including Zip Code)
Registrant's telephone number, including area code (218) 722-2641
Securities registered pursuant to Section 12(b) of the Act:
Name of Each Stock
Title of Each Class Exchange on Which Registered
------------------- ----------------------------
Common Stock, without par value New York Stock Exchange
5% Cumulative Preferred Stock, par value
$100 per share American Stock Exchange
8.05% Cumulative Quarterly Income
Preferred Securities
of MP&L Capital I, a subsidiary of
Minnesota Power & Light Company New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act:
Preferred Stock, without par value
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. /X/
The aggregate market value of voting stock held by nonaffiliates on
March 2, 1998 was $1,370,119,250.
As of March 2, 1998 there were 33,699,517 shares of Minnesota Power & Light
Company Common Stock, without par value, outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Minnesota Power 1997 Annual Report are incorporated by reference
in Part II, Items 7 and 8, and portions of the Proxy Statement for the 1998
Annual Meeting of Shareholders are incorporated by reference in Part III.
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INDEX
PAGE
PART I
Item 1. Business 1
Electric Operations 2
Electric Sales 2
Purchased Power 5
Capacity Sales 5
Fuel 6
Regulatory Issues 6
Capital Expenditure Program 8
Competition 8
Franchises 9
Environmental Matters 9
Water Services 12
Regulatory Issues 13
Capital Expenditure Program 14
Competition 14
Franchises 14
Environmental Matters 14
Automotive Services 15
Capital Expenditure Program 15
Competition 16
Environmental Matters 16
Investments 16
Environmental Matters 17
Executive Officers of the Registrant 18
Item 2. Properties 20
Item 3. Legal Proceedings 22
Item 4. Submission of Matters to a Vote of Security Holders 23
PART II
Item 5. Market for the Registrant's Common Equity and Related
Stockholder Matters 23
Item 6. Selected Financial Data 24
Item 7. Management's Discussion and Analysis of Financial Condition
and Results of Operations 24
Item 8. Financial Statements and Supplementary Data 24
Item 9. Changes in and Disagreements with Accountants on Accounting
and Financial Disclosure 24
PART III
Item 10. Directors and Executive Officers of the Registrant 25
Item 11. Executive Compensation 25
Item 12. Security Ownership of Certain Beneficial Owners
and Management 25
Item 13. Certain Relationships and Related Transactions 25
PART IV
Item 14. Exhibits, Financial Statement Schedules and Reports
on Form 8-K 26
SIGNATURES 33
DEFINITIONS
The following abbreviations or acronyms are used in the text.
ABBREVIATION OR ACRONYMS TERM
- - - ------------------------ ----------------------------------------------------
ADESA ADESA Corporation
AFC Automotive Finance Corporation
Americas' Water Americas' Water Services Corporation
BNI Coal BNI Coal, Ltd.
Boswell Boswell Energy Center
Capital Re Capital Re Corporation
CIP Conservation Improvement Program(s)
Company Minnesota Power & Light Company and its Subsidiaries
Duluth City of Duluth, Minnesota
EPA Environmental Protection Agency
FERC Federal Energy Regulatory Commission
Florida Water Florida Water Services Corporation
FPSC Florida Public Service Commission
Great Rigs Great Rigs Incorporated
Heater Heater Utilities, Inc.
Hibbard M.L. Hibbard Station
ISI Instrumentation Services, Inc.
Laskin Laskin Energy Center
Lehigh Lehigh Acquisition Corporation
MAPP Mid-Continent Area Power Pool
MBtu Million British thermal units
Minnesota Power Minnesota Power & Light Company and its Subsidiaries
Minnkota Power Minnkota Power Cooperative, Inc.
MP Telecom Minnesota Power Telecom, Inc.
MPCA Minnesota Pollution Control Agency
MPUC Minnesota Public Utilities Commission
MW Megawatt(s)
MWh Megawatthour
NCUC North Carolina Utilities Commission
Note_ Note __ to the consolidated financial statements
in the Minnesota Power 1997 Annual Report
NPDES National Pollutant Discharge Elimination System
PSCW Public Service Commission of Wisconsin
Square Butte Square Butte Electric Cooperative
SWL&P Superior Water, Light and Power Company
U.S. Maintenance
and Management U.S. Maintenance and Management Services
Corporation
WPPI Wisconsin Public Power, Inc.
SAFE HARBOR STATEMENT
UNDER THE
PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
In connection with the safe harbor provisions of the Private Securities
Litigation Reform Act of 1995 (Reform Act), the Company is hereby filing
cautionary statements identifying important factors that could cause the
Company's actual results to differ materially from those projected in
forward-looking statements (as such term is defined in the Reform Act) made by
or on behalf of the Company in this annual report on Form 10-K, in
presentations, in response to questions or otherwise. Any statements that
express, or involve discussions as to expectations, beliefs, plans, objectives,
assumptions or future events or performance (often, but not always, through the
use of words or phrases such as "anticipates", "believes", "estimates",
"expects", "intends", "plans", "predicts", "projects", "will likely result",
"will continue", or similar expressions) are not statements of historical facts
and may be forward-looking.
Forward-looking statements involve estimates, assumptions, and
uncertainties and are qualified in their entirety by reference to, and are
accompanied by, the following important factors, which are difficult to predict,
contain uncertainties, are beyond the control of the Company and may cause
actual results to differ materially from those contained in forward-looking
statements:
- prevailing governmental policies and regulatory actions, including
those of the FERC, the MPUC, the FPSC, the NCUC and the PSCW, with
respect to allowed rates of return, industry and rate structure,
acquisition and disposal of assets and facilities, operation and
construction of plant facilities, recovery of purchased power, and
present or prospective wholesale and retail competition (including
but not limited to retail wheeling and transmission costs);
- economic and geographic factors including political and economic
risks;
- changes in and compliance with environmental and safety
laws and policies;
- weather conditions;
- population growth rates and demographic patterns;
- competition for retail and wholesale customers;
- pricing and transportation of commodities;
- market demand, including structural market changes;
- changes in tax rates or policies or in rates of inflation;
- changes in project costs;
- unanticipated changes in operating expenses and capital
expenditures;
- capital market conditions;
- competition for new energy development opportunities; and
- legal and administrative proceedings (whether civil or criminal)
and settlements that influence the business and profitability of
the Company.
Any forward-looking statement speaks only as of the date on which such
statement is made, and the Company undertakes no obligation to update any
forward-looking statement to reflect events or circumstances after the date on
which such statement is made or to reflect the occurrence of unanticipated
events. New factors emerge from time to time and it is not possible for
management to predict all of such factors, nor can it assess the impact of any
such factor on the business or the extent to which any factor, or combination of
factors, may cause results to differ materially from those contained in any
forward-looking statement.
PART I
ITEM 1. BUSINESS.
Minnesota Power, a broadly diversified service company incorporated
under the laws of the State of Minnesota in 1906, has operations in four
business segments: (1) Electric Operations, which include electric and gas
services, and coal mining; (2) Water Services, which include water and
wastewater services; (3) Automotive Services, which include a network of vehicle
auctions, a finance company and an auto transport company; and (4) Investments,
which include a securities portfolio, a 21 percent equity investment in a
financial guaranty reinsurance and insurance company and real estate operations.
Corporate Charges represent general corporate expenses, including interest, not
specifically related to any one business segment. As of December 31, 1997 the
Company and its subsidiaries had approximately 6,800 employees.
1997 1996 1995
- - - --------------------------------------------------------------------------------
Millions
Operating Revenue and Income
Electric Operations $ 541.9 $ 529.2 $ 503.5
Water Services 95.5 85.2 66.1
Automotive Services (a) 255.5 183.9 61.6
Investments 60.9 49.9 43.7
Corporate Charges (0.2) (1.3) (2.0)
------- ------- -------
$ 953.6 $ 846.9 $ 672.9
======= ======= =======
Net Income
Electric Operations $ 43.1 $ 39.4 $ 41.0
Water Services 8.2 5.4 (1.0)
Automotive Services (a) 14.0 3.7 -
Investments 32.1 38.1 41.3
Corporate Charges (19.8) (17.4) (19.4)
------- ------- -------
77.6 69.2 61.9
Discontinued Operations (b) - - 2.8
------- ------- -------
$ 77.6 $ 69.2 $ 64.7
======= ======= =======
- - - --------------------------------------------------------------------------------
Basic and Diluted
Earnings Per Share of Common Stock $2.47 $2.28 $2.16
Average Shares of Common Stock - Millions 30.6 29.3 28.5
- - - --------------------------------------------------------------------------------
(a) The Company purchased 80 percent of ADESA, including AFC and Great
Rigs, on July 1, 1995, another 3 percent in January 1996 and the remaining
17 percent in August 1996.
(b) On June 30, 1995 the Company sold its interest in the paper and pulp
business to Consolidated Papers, Inc.
Since 1983 Minnesota Power has been diversifying to reduce its reliance
on electricity sales to Minnesota's taconite industry and to gain additional
earnings growth potential. Acquisitions have been a primary means of
diversification. During 1997 the Company continued its corporate strategy of
expanding existing business segments. Electric Operations created a
telecommunications subsidiary, while Water Services acquired a water subsidiary
and established two non-regulated subsidiaries. Automotive Services added two
auction facilities and 25 loan production offices. The Company plans to consider
other acquisitions that would complement its businesses, expand its services and
contribute to earnings growth.
For a detailed discussion of results of operations and trends, see
Management's Discussion and Analysis of Financial Condition and Results of
Operations in the Minnesota Power 1997 Annual Report. For business segment
information, see Note 1.
-1-
ELECTRIC OPERATIONS
Electric Operations generate, transmit, distribute and market
electricity. In addition Electric Operations include coal mining,
telecommunications and economic development projects within the Company's
service area. Electric Operations intend to seek cost saving alternatives and
efficiencies, and expand non-regulated services.
- MINNESOTA POWER provides electricity in a 26,000 square mile
electric service territory located in northeastern Minnesota. As
of December 31, 1997 Minnesota Power was supplying retail electric
service to 122,000 customers in 153 cities, towns and communities,
and outlying rural areas. The largest city served is Duluth with a
population of 85,000 based on the 1990 census. Wholesale electric
service for resale is supplied to 15 municipal distribution
systems, one private utility and SWL&P.
MPEX, a division of Minnesota Power, is an expansion of the
Company's inter-utility marketing group which has been a buyer and
seller of capacity and energy for over 25 years in the wholesale
power market. The customers of MPEX are other power suppliers in
the Midwest and Canada. MPEX also contracts with its customers to
provide hourly energy scheduling and power trading services.
- SUPERIOR WATER, LIGHT AND POWER COMPANY sells electricity and
natural gas, and provides water service in northwestern Wisconsin.
As of December 31, 1997 SWL&P served 14,000 electric customers,
11,000 natural gas customers and 10,000 water customers.
- BNI COAL owns and operates a lignite mine in North Dakota. Two
electric generating cooperatives, Minnkota Power and Square Butte,
presently consume virtually all of BNI Coal's production of
lignite coal under coal supply agreements extending to 2027. Under
an agreement with Square Butte, Minnesota Power purchases about 71
percent of the output from the Square Butte unit which is capable
of generating up to 455 MW. Minnkota Power has an option to extend
its coal supply agreement to 2042. (See - Fuel and Note 5.)
- ELECTRIC OUTLET, INC. is a retail store that sells life-style
changing electric products and also researches new products to
be offered for sale and distribution.
- MINNESOTA POWER TELECOM, INC., formed in 1997, will provide high
volume fiber optic and microwave communications to businesses
across the Company's service territory.
- UPPER MINNESOTA PROPERTIES, INC. has invested in affordable
housing projects located in Electric Operations' service
territory. The Company is also an active participant in a variety
of economic development projects throughout Electric Operations'
service territory providing resources and expertise.
ELECTRIC SALES
The two major industries in Minnesota Power's service territory are
taconite production, and paper and pulp mills. Taconite customers accounted for
31 percent of the Company's electric operating revenue and income in 1997 (32
percent in 1996; 35 percent in 1995). Paper and pulp customers accounted for 12
percent of electric operating revenue and income in 1997 (11 percent in 1996; 12
percent in 1995). Sales to other power suppliers accounted for 12 percent of
electric operating revenue and income in 1997 (13 percent in 1996; 9 percent in
1995). As deregulation of the electric utility industry approaches, the Company
believes the percentage of electric revenue from sales to other power suppliers
will continue to increase. The percentage of electric revenue from taconite
customers is expected to decrease as other strategic initiatives, including MPEX
and MP Telecom, add to electric operating revenue and income.
Over the last five years, 80 percent of the domestic ore consumed by
iron and steel plants in the United States has originated from plants within the
Company's electric service territory. Taconite, an iron-bearing rock of
relatively low iron content which is abundantly available in Minnesota, is an
important domestic source of raw material for the steel industry. Taconite
processing plants use large quantities of electric power to grind the
ore-bearing rock, and agglomerate and pelletize the iron particles into taconite
pellets. Annual taconite production in Minnesota was 47 million tons in 1997 (46
million tons in 1996;
-2-
47 million tons in 1995). Based on the Company's research of the taconite
industry, 1998 Minnesota taconite production is anticipated to remain at or near
the 1997 level. While taconite production is expected to continue at annual
levels over 40 million tons, the long-term future of this cyclical industry is
less certain. Production may decline gradually some time after the year 2008.
Year Ended December 31,
1997 1996 1995
- - - -------------------------------------------------------------------------------------------------------------------
Total Electric Operating Revenue and Income - Millions $541.9 $529.2 $503.5
Percentage of Total Electric Operating Revenue and Income
Retail
Industrial
Taconite Producers <F1> 31% 32% 35%
Paper and Pulp Mills 12 11 12
Other Industrial 6 6 7
--- --- ---
Total Industrial 49 49 54
Residential 12 12 11
Commercial 11 11 12
Other Retail 1 1 1
Sales to Other Power Suppliers 12 13 9
Other Revenue and Income 15 14 13
--- --- ---
100% 100% 100%
=== === ===
- - - -------------------------------------------------------------------------------------------------------------------
<FN>
<F1> The Company's two largest customers represented 10 percent and 8 percent,
respectively, of total electric operating revenue and income in 1997 (11
percent and 8 percent in 1996; 12 percent and 9 percent in 1995).
</FN>
LARGE POWER CUSTOMER CONTRACTS
The Company has Large Power Customer contracts with five taconite
producers, four paper and pulp mills, and two pipeline companies (Large Power
Customers), each of which requires 10 MW or more of generating capacity. Large
Power Customer contracts require the Company to have a certain amount of
generating capacity available at all times. In turn each Large Power Customer is
required to pay a minimum monthly demand charge that covers the fixed costs
associated with having capacity available to serve the customer, including a
return on common equity. Most contracts allow customers to establish the level
of MW subject to a demand charge on a periodic (pool season) basis and require
that a portion of their MW needs be committed on a take-or-pay basis for the
entire term of the agreement. In addition to the demand charge, each Large Power
Customer is billed an energy charge for each kilowatthour used that recovers the
variable costs incurred in generating electricity. Six of the Large Power
Customers have interruptible service for a portion of their needs which includes
a discounted demand rate and energy priced at the Company's incremental cost
after serving all firm power obligations. The Company also provides incremental
production service for customer demand levels above the contract take-or-pay
levels. There is no demand charge for this service and energy is priced at an
increment above the Company's cost. Incremental production service is
interruptible.
Each contract continues after the contract termination date, unless the
required four-year advance notice of cancellation has been given. Such contracts
minimize the impact on earnings that otherwise would result from significant
reductions in kilowatthour sales to such customers. Large Power Customers are
required to purchase their entire electric service requirements from the Company
for the duration of their contracts. The rates and corresponding revenue
associated with capacity and energy provided under these contracts are subject
to change through the same regulatory process governing all retail electric
rates. Minnesota Power has implemented a key account management process to
heighten its focus on large commercial and industrial customers' needs, and
anticipates continuing negotiations with these customers to explore options to
respond to those needs. (See Regulatory Issues - Electric Rates.)
As of March 15, 1998 the minimum annual revenue the Company would
collect under contracts with these Large Power Customers, assuming no electric
energy use by these customers, is estimated to be $101.8, $78.3, $69.2, $66.5
and $47.3 million during the years 1998, 1999, 2000, 2001 and 2002,
respectively. Based on past experiences and projected operating levels, the
Company believes revenue from these Large Power Customers will be substantially
in excess of the minimum contract amounts.
-3-
CONTRACT STATUS FOR MINNESOTA POWER LARGE POWER CUSTOMERS
AS OF MARCH 15, 1998
- - - -------------------------------------------------------------------------------------------------------------------
Earliest
Customer Location Ownership Termination Date
- - - -------- -------- --------- ----------------
Eveleth Mines LLC Eveleth, MN 45% Rouge Steel Co. October 31, 1999 <F1>
40% AK Steel Co.
15% Stelco Inc.
Hibbing Taconite Co. Hibbing, MN 70.3% Bethlehem Steel Corp. December 31, 2001 <F2>
15% Cleveland-Cliffs Inc
14.7% Stelco Inc.
Inland Steel Mining Co. Virginia, MN Inland Steel Co. December 31, 2007
U.S. Steel - Minntac Mt. Iron, MN USX Corporation December 31, 2007
National Steel Pellet Co. Keewatin, MN National Steel Corp. October 31, 2004
Blandin Paper Co. Grand Rapids, MN UPM-Kymmene Corporation April 30, 2004
Boise Cascade Corp. International Falls, MN Boise Cascade Corp. December 31, 2002
Lake Superior Paper Duluth, MN Consolidated Papers, Inc. July 31, 2008
Industries and Superior
Recycled Fiber Industries
Potlatch Corp. Cloquet, MN and Potlatch Corp. December 31, 2002
Brainerd, MN
Lakehead Pipe Line Co. L.P. Deer River, MN Lakehead Pipe Line April 30, 2001
Floodwood, MN Partners, L.P.
Minnesota Pipeline Company Staples, MN 60% Koch Pipeline Co LP September 30, 2002
Little Falls, MN 40% Marathon Ashland
Park Rapids, MN Petroleum LLC
- - - -------------------------------------------------------------------------------------------------------------------
<FN>
<F1> A contract amendment, which provides for the Company to continue to meet
all of Eveleth Mines LLC's electric requirements through October 2008, has
been filed for MPUC approval.
<F2> A contract amendment, which provides for the Company to continue to meet
all of Hibbing Taconite Co.'s electric requirements through December 2008,
has been filed for MPUC approval.
</FN>
-4-
PURCHASED POWER
Minnesota Power has contracts to purchase capacity and energy from
various entities. In addition to the contracts listed below, the Company has
entered into various smaller purchased power contracts for the purposes of
meeting its capacity needs or brokering power.
STATUS OF MINNESOTA POWER PURCHASED POWER CONTRACTS
- - - --------------------------------------------------------------------------------
Entity Contract MW Contract Period
- - - ------ ----------- ---------------
Participation Power
- - - -------------------
Purchases (a)
---------
Square Butte (b) 322 May 6, 1977 through December 31, 2007
LTV Steel 210 May 1, 1995 though April 30, 2000
Silver Bay Power 78 November 1, 1995 through October 31, 2000
- - - --------------------------------------------------------------------------------
(a) Participation power purchase contracts require the Company to pay the
demand charges for generating capacity under contract and an energy charge
for each MWh purchased. The selling entity is obligated to provide energy
as scheduled by the Company from the generating unit specified in the
contract as energy is available from that unit.
(b) Under an agreement extending through 2007 with Square Butte, Minnesota
Power purchases about 71 percent of the output of a mine-mouth generating
unit capable of generating up to 455 MW. The Square Butte generating unit
is located near Center, North Dakota and is one of two lignite-fired units
at Minnkota Power's Milton R. Young Generating Station. Reductions to about
49 percent of the output are provided for in the contract and, at the
option of Square Butte, could begin after a five-year advance notice to the
Company. The cost of the power and energy purchased is a proportionate
share of Square Butte's fixed and variable costs. The Company is
responsible for paying all costs and expenses of Square Butte (including
leasing, operating and any debt service costs) if not paid by Square Butte
when due. These obligations of the Company are absolute and unconditional,
whether or not any power is actually delivered to the Company. (See Note
5.)
CAPACITY SALES
Minnesota Power has contracts to sell capacity to nonaffiliated utility
companies. In addition to the contracts listed below, the Company has entered
into various smaller capacity sales contracts for the purposes of selling
surplus capacity or brokering power.
STATUS OF MINNESOTA POWER CAPACITY SALES CONTRACTS
- - - --------------------------------------------------------------------------------
Utility Contract MW Contract Period
- - - ------- ----------- ---------------
Participation Power
- - - -------------------
Sales (a)
-----
Interstate Power
Company 55 May 1 through October 31 of each year from
1994 through 2000
20 November 1, 1997 through April 30, 1998
35 November 1, 1998 through April 30, 1999
50 November 1, 1999 through April 30, 2000
Firm Power Sales (b)
- - - --------------------
Wisconsin Power &
Light Company 75 January 1, 1998 through December 31, 2007
Northern States
Power Company 150 May 1 through October 31 of each year from
1997 through 2000
- - - --------------------------------------------------------------------------------
(a) Participation power sales contracts require the purchasing utility to pay
the demand charges for MW under contract and an energy charge for each MWh
purchased. The Company is obligated to provide energy as scheduled by the
purchasing utility from the generating unit specified in the contract as
energy is available from that unit.
(b) Firm power sales contracts require the purchasing utility to pay the demand
charges for MW under contract and an energy charge for each MWh purchased.
The Company is obligated to provide energy as scheduled by the purchasing
utility.
-5-
FUEL
The Company purchases low-sulfur, sub-bituminous coal from the Powder
River Basin coal field located in Montana and Wyoming. Coal consumption for
electric generation at the Company's Minnesota coal-fired generating stations in
1997 was about 4.1 million tons. As of December 31, 1997 the Company had a coal
inventory of about 497,000 tons. The Company has three coal supply agreements in
place with Montana suppliers. Two terminate in December 1999 and the other
terminates in December 2000. Under these agreements the Company has the tonnage
flexibility to procure 70 percent to 100 percent of its total coal requirements.
The Company will obtain coal in 1998 under these agreements and the spot market.
This mix of coal supply options allows the Company to reduce market risk and to
take advantage of favorable spot market prices. The Company is exploring future
coal supply options and believes that adequate supplies of low-sulfur,
sub-bituminous coal will continue to be available.
Burlington Northern Santa Fe Railroad transports the coal by unit train
from Montana or Wyoming to the Company's generating stations. The Company and
Burlington Northern Santa Fe Railroad have two long-term coal freight-rate
contracts that provide for coal deliveries through 2002 to Laskin and through
2003 to Boswell. The Company also has a contract with the Duluth Missabe & Iron
Range Railway which is the final destination short-hauler to Laskin. This
contract provides for deliveries through 2002. The delivered price of coal is
subject to periodic adjustments in freight rates.
Year Ended December 31,
COAL DELIVERED TO MINNESOTA POWER 1997 1996 1995
- - - --------------------------------------------------------------------------------
Average Price Per Ton $20.26 $19.30 $19.19
Average Price Per MBtu $1.11 $1.06 $1.07
- - - --------------------------------------------------------------------------------
The generating unit operated by Square Butte burns North Dakota lignite
supplied by BNI Coal, a wholly owned subsidiary of the Company, pursuant to the
terms of a contract expiring in 2027. Square Butte's cost of lignite burned in
1997 was approximately 64 cents per MBtu. The lignite acreage that has been
dedicated to Square Butte by BNI Coal is located on lands essentially all of
which are under private control and presently leased by BNI Coal. This lignite
supply is sufficient to provide the fuel for the anticipated useful life of the
generating unit. Under the various agreements with Square Butte, the Company is
unconditionally obligated to pay all costs not paid by Square Butte when due.
These costs include the price of lignite purchased under a cost-plus contract
from BNI Coal. (See Item 2. Properties and Note 5.) BNI Coal has experienced no
difficulty in supplying all of Square Butte's lignite requirements.
REGULATORY ISSUES
The Company and its subsidiaries are exempt from regulation under the
Public Utility Holding Company Act of 1935, except as to Section 9(a)(2) which
relates to acquisition of securities of public utility operations.
The Company and its subsidiaries are subject to the jurisdiction of
various regulatory authorities. The MPUC has regulatory authority over Electric
Operations' service area in Minnesota, retail rates, retail services, issuance
of securities and other matters. The FERC has jurisdiction over the licensing of
hydroelectric projects, the establishment of rates and charges for the sale of
electricity for resale and transmission of electricity in interstate commerce,
and certain accounting and record keeping practices. The PSCW has regulatory
authority over the retail sales of electricity, water and gas by SWL&P. The
MPUC, FERC and PSCW had regulatory authority over 68 percent, 12 percent, and 8
percent, respectively, of the Company's 1997 electric operating revenue and
income.
ELECTRIC RATES
The Company has historically designed its electric service rates based
on cost of service studies under which allocations are made to the various
classes of customers. Nearly all retail sales include billing adjustment clauses
which adjust electric service rates for changes in the cost of fuel and
purchased energy, and recovery of current and deferred CIP expenditures.
-6-
The demand charge component of the Company's large power rate schedules
are designed to recover the fixed costs of providing capacity to Large Power
Customers, including a return on common equity. A Large Power Customer's monthly
demand charge obligation in any particular month is determined based upon the
firm demand amount. The rates and corresponding revenue associated with capacity
and energy provided under these contracts are subject to change through the
regulatory process governing all retail electric rates. Contracts with ten of
the eleven Large Power Customers provide for deferral without interest or
diminishment of one-half of demand charge obligations incurred during the first
three months of a strike or illegal walkout at a customer's facilities, with
repayment required over the 12-month period following resolution of the work
stoppage. (See Electric Sales - Large Power Customer Contracts.)
The Company also has contracts with large industrial and commercial
customers who have monthly demands of more than 2 MW but less than 10 MW of
capacity (Large Light and Power Customers). The terms of these contracts vary
depending upon the customers' demand for power and the cost of extending the
Company's facilities to provide electric service. Generally, the contracts for
less than 3 MW have one-year terms and the contracts ranging from 3 to 10 MW
have initial five-year terms. The Company's rate schedule for Large Light and
Power Customers is designed to minimize fluctuations in revenue and to recover a
significant portion of the fixed costs of providing service to such customers.
The Company requires that all large industrial and commercial customers
under contract specify the date when power is first required, and thereafter the
customer is billed for at least the minimum power for which they contracted.
These conditions are part of all contracts covering power to be supplied to new
large industrial and commercial customers and to current customers as their
contracts expire or are amended. All contracts provide that new rates which have
been approved by appropriate regulatory authorities will be substituted
immediately for obsolete rates, without regard to any unexpired term of the
existing contract. All rate schedules are subject to approval by appropriate
regulatory authorities.
FEDERAL ENERGY REGULATORY COMMISSION
The FERC has jurisdiction over the Company's wholesale electric service
resale customers and transmission service (wheeling) customers.
The Company has long-term contracts with 15 Minnesota municipalities
receiving resale service. Two contracts are for service through 2002 and 2004,
while the other 13 are for service through at least 2007. The contracts limit
rate increases (including fuel costs) to about 2 percent per year on a
cumulative basis. In 1997 the 15 municipal customers purchased 615,422 MWh from
the Company.
A contract between Minnesota Power and SWL&P provides for SWL&P to
purchase its power from the Company through at least 2010 and limits rate
increases (including fuel costs) to about 2 percent per year on a cumulative
basis. SWL&P purchased 564,200 MWh from the Company in 1997.
The Company also has a contract through 2004 to supply electricity to
Dahlberg Light and Power Company (Dahlberg), a private utility. Dahlberg
purchased 86,434 MWh from the Company in 1997.
The Company's hydroelectric facilities, which are located in Minnesota,
are licensed by the FERC. In 1995 the FERC issued to the Company a 30-year
license for the St. Louis River hydroelectric project (87.6 MW generating
capability). In 1996 the FERC extended the license term from 30 to 40 years
because of certain mandates to mitigate environmental consequences of the
project. In May 1997 the FERC issued an annual license for the Pillager
hydroelectric project (1.5 MW generating capability) under the existing license
terms and conditions. This annual license is effective until the new license is
issued. (See Environmental Matters - Water.)
MINNESOTA PUBLIC UTILITIES COMMISSION
The Company's retail rates are based on a 1994 MPUC retail rate order
which allows for an 11.6 percent return on common equity devoted to utility
plant.
Minnesota requires investor owned electric utilities to spend a minimum
of 1.5 percent of gross annual retail electric revenue on conservation
improvement programs (CIP) each year. The MPUC approved a minimum statutory
spending requirement of $5.1 million for 1997 ($5.1 million for 1996; $5.3
million for 1995). In 1997 the Company spent $5.8 million on CIP ($14.4 million
in 1996; $14.2 million in 1995) and expects to spend a total of $11.9 million
during 1998. The MPUC allows such conservation
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expenditures in excess of amounts recovered through current rates to be
accumulated in a deferred account for future recovery. Through a billing
adjustment and retail base rates approved by the MPUC, the Company is allowed to
recover current and deferred CIP expenditures, a carrying charge on unrecovered
expenditures and the lost margins associated with power saved as a result of
these programs. The Company collected CIP related revenue of $13.7 million in
1997 ($10.8 million in 1996 and 1995).
CAPITAL EXPENDITURE PROGRAM
Capital expenditures for Electric Operations totaled $35 million during
1997. Internally generated funds and long-term financing were used to fund these
capital expenditures. Electric Operations capital expenditures are expected to
be $44 million in 1998 and total approximately $144 million during the period
1999 through 2002. The 1998 amount is for electric system component replacement
and upgrades, telecommunication fiber and coal handling equipment. The Company's
estimates of such capital expenditures and the sources of financing are subject
to continuing review and adjustment.
COMPETITION
The electric utility industry continues to become more competitive at
both the wholesale and retail levels. This is particularly the case in the
wholesale markets. Retail deregulation of the industry is being considered at
both the federal and state level, and effects the way the Company strategically
views the future. With electric rates among the lowest in the United States and
with long-term wholesale and Large Power Customer retail contracts in place,
Minnesota Power believes Electric Operations are well positioned to address and
benefit from competitive pressures.
WHOLESALE
Minnesota Power's MPEX division conducts an active wholesale power
marketing and trading business, including participation in the new power and
energy markets within the Mid-Continent Area Power Pool and other regional
reliability councils. In 1997 Manitoba Hydro and Minnesota Power signed a
three-year agreement whereby MPEX will provide Manitoba Hydro with exclusive
hourly power trading and energy scheduling services in the United States. This
agreement became effective January 1, 1998. Also in 1997 Manitoba Hydro and
Minnesota Power signed a memorandum of understanding that establishes an
alliance whereby the two utilities are and will market electric energy in the
Midwest, including but not limited to Wisconsin, Michigan and Illinois. This
memorandum strengthens the international relationship beyond the wholesale power
trading agreement. Manitoba Hydro is the fourth largest electric utility in
Canada. More than a third of Manitoba Hydro's electric sales represent exports
of renewable hydroelectricity to the United States and neighboring provinces in
Canada. MPEX is reviewing new strategic opportunities for its wholesale
marketing operations in light of the new Open Access Transmission Rules enacted
by the FERC in 1996. The Company also has wholesale contracts with a number of
municipal customers. (See Regulatory Issues - Federal Energy Regulatory
Commission.)
In 1996 the Company completed functional unbundling of its operations
under FERC Order No. 888, "Open Access Transmission Rules." This order requires
public utilities to take transmission service for their own wholesale
transactions under the same terms and conditions on which transmission service
is provided to third parties. Also in 1996 the Company filed its "Code of
Conduct" under FERC Order No. 889, "Open Access Same Time Information System and
Standards of Conduct," which formalized the functional separation of generation
from transmission within the organization. The transmission component of
Electric Operations is organized for and conducting business under these new
federal regulatory requirements. (See Item 2. Properties - Electric Operations.)
RETAIL
In 1995 the MPUC initiated an investigation into structural and
regulatory issues in the electric utility industry. To make certain that
delivery of electric service continues to be efficient following any
restructuring, the MPUC adopted 15 principles to guide a deliberate and orderly
approach to developing reasonable restructuring alternatives that ensure the
fairness of a competitive market and protect the public interest. In January
1996 the MPUC established a competition working group in which company
representatives have participated in addressing issues related to wholesale and
retail competition. The
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working group issued a Wholesale Competition Report in October 1996 and a Retail
Competition Report in November 1997. The MPUC is expected to begin identifying
the steps necessary to successfully implement restructuring upon receipt of a
legislative mandate.
LEGISLATION
During 1998 Congress is expected to continue to debate proposed
legislation which, if enacted, would promote customer choice and a more
competitive electric market. The Company is actively participating in the
dialogue and debate on these issues in various forums, principally to advocate
fairness and parity for all power and energy competitors in any deregulated
markets that may be created by new legislation. While Congress is not expected
to pass legislation in 1998, the Company cannot predict the timing or substance
of any future legislation which might ultimately be enacted. However, the
Company will take the necessary steps to maintain its competitive position as a
low-cost and long-term supplier to large industrial customers.
Legislative activity is evolving both in Minnesota and Wisconsin. An
electric Energy Task Force comprised of representatives of both houses of the
Minnesota legislature continues to study a variety of issues related to industry
restructuring. In Minnesota legislation has been introduced, but the Governor
and legislative leadership have indicated that no action to restructure the
industry will be taken in 1998. The Company is also promoting property tax
reform before the Minnesota legislature in order to eliminate the taxation of
personal property that results in an inequitable tax burden among current and
potential competitors in local markets. The Wisconsin legislature is pursuing
electric utility industry restructuring, including the possible formation of an
independent transmission system operator within the state.
FRANCHISES
Minnesota Power holds franchises to construct and maintain an electric
distribution and transmission system in 85 cities and towns located within its
electric service territory. SWL&P holds franchises in 15 cities and towns within
its service territory. The remaining cities and towns served do not require a
franchise to operate within their boundaries.
ENVIRONMENTAL MATTERS
Certain businesses included in the Company's Electric Operations
segment are subject to regulation by various federal, state and local
authorities with respect to air quality, water quality, solid wastes and other
environmental matters. The Company considers these businesses to be in
substantial compliance with those environmental regulations currently applicable
to its operations and believes all necessary permits to conduct such operations
have been obtained. The Company does not currently anticipate that potential
capital expenditures for environmental matters will be material. However,
because environmental laws and regulations are constantly evolving, the
character, scope and ultimate costs of environmental compliance cannot be
estimated.
AIR
CLEAN AIR ACT. The federal Clean Air Act Amendments of 1990 (Clean Air
Act) require that specified fossil-fueled generating plants obtain air emission
permits from the EPA (or, when delegated, from individual state and pollution
control agencies), and meet new sulfur dioxide and nitrogen oxide emission
standards beginning January 1, 1995 (Phase I) and that virtually all generating
plants meet more strict emission standards beginning January 1, 2000 (Phase II).
None of Minnesota Power's generating facilities are covered by the Phase I
requirements of the Clean Air Act for sulfur dioxide. However, Phase II
requirements apply to the Company's Boswell, Laskin and Hibbard plants, as well
as Square Butte.
The Clean Air Act creates emission allowances for sulfur dioxide based
on formulas relating to the permitted 1985 emissions rate and a baseline of
average fossil fuel consumed in the years 1985, 1986 and 1987. Each allowance is
an authorization to emit one ton of sulfur dioxide, and each utility must have
sufficient allowances to cover its annual emissions. Minnesota Power's
generating facilities in Minnesota burn mainly low-sulfur western coal and
Square Butte, located in North Dakota, burns lignite coal. All of these
facilities are equipped with pollution control equipment such as scrubbers,
baghouses or electrostatic precipitators. Phase II sulfur dioxide emission
requirements are currently being met by Boswell Unit 4. Some moderate reductions
in emissions may be necessary for Boswell Units 1, 2 and 3,
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Laskin Units 1 and 2, and Square Butte to meet the Phase II sulfur dioxide
emission requirements. The Company believes it is in a good position to comply
with the sulfur dioxide standards without extensive modifications. Any required
reductions at the Minnesota generating facilities are expected to be achieved
through the use of lower sulfur coal. Square Butte anticipates meeting its
sulfur dioxide requirements through increased use of existing scrubbers or by
purchasing additional allowances. The estimated cost to meet sulfur dioxide
requirements at Square Butte is $500,000 to $600,000 per year.
Pursuant to the Clean Air Act, the EPA has established nitrogen oxide
limitations for Phase II generating units. To meet Phase II nitrogen oxide
limitations, the Company has spent $4.2 million and will spend an additional
$1.8 million in 1998 on advanced low emission burner technology and associated
control equipment to operate the Boswell and Laskin facilities at or below the
compliance standards. Options for complying with the nitrogen oxide limitations
at Square Butte are being studied at this time and include operational changes,
capital expenditures and seeking regulatory relief. The EPA decided not to
promulgate nitrogen oxide limitations for the type of boilers at Hibbard.
The Company has obtained all necessary Title V air operating permits
from the MPCA for applicable facilities to conduct its electric operations.
AIR QUALITY EMISSION PERMITS
- - - --------------------------------------------------------------------------------
Facility Effective Date Expiration Date
-------- -------------- ---------------
Boswell March 24, 1997 March 24, 2002
Laskin May 12, 1997 May 12, 2002
Hibbard July 14, 1997 July 14, 2002
- - - --------------------------------------------------------------------------------
CLIMATE CHALLENGE. The Company is participating in a voluntary program
(Climate Challenge) with the United States Department of Energy to identify
activities that the Company has taken and additional measures that the Company
may undertake on a voluntary basis that will result in limitations, reductions
or sequestrations of greenhouse gas emissions by the year 2000. The Company has
agreed to participate in this voluntary program provided that such participation
is consistent with the Company's integrated resource planning process, does not
have a material adverse effect on the Company's competitive position with
respect to rates and costs, and continues to be acceptable to the Company's
regulators. The costs to Minnesota Power associated with Climate Challenge
participation are minor, reflecting program facilitation and voluntary reporting
costs.
KYOTO PROTOCOL. On December 11, 1997 the United Nations Framework
Convention on Climate Change agreed upon a draft international treaty, the Kyoto
Protocol (Protocol), which, if ratified, would call for reductions in greenhouse
gas emissions. The United States' target is to achieve a 7 percent reduction
below 1990 emission levels by the period 2008-2012. The Protocol must be
ratified by the United States Senate by March 15, 1999; however, the Protocol
does not currently satisfy the guidance provided in a 1997 Senate resolution.
The Company currently cannot predict when or if the Protocol will be ratified
nor can it determine the impact such ratification would have on the Company.
WATER
The Federal Water Pollution Control Act of 1972 (FWPCA), as amended by
the Clean Water Act of 1977 and the Water Quality Act of 1987, established the
National Pollutant Discharge Elimination System (NPDES) permit program. The
FWPCA requires that NPDES permits be obtained from the EPA (or, when delegated,
from individual state pollution control agencies) for any wastewater discharged
into navigable waters. The Company has obtained all necessary NPDES permits,
including NPDES storm water permits for applicable facilities, to conduct its
electric operations.
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NATIONAL POLLUTANT DISCHARGE ELIMINATION SYSTEM PERMITS
- - - --------------------------------------------------------------------------------
Facility Effective Date Expiration Date
- - - -------- -------------- ---------------
Boswell February 4, 1993 December 31, 1997 (a)
Laskin December 22, 1993 October 31, 1998 (b)
Hibbard September 29, 1994 June 30, 1999
Arrowhead DC Terminal June 17, 1996 March 31, 2001
General Office Building/
Lake Superior Plaza January 6, 1998 December 31, 2002
Square Butte July 1, 1995 June 30, 2000
- - - --------------------------------------------------------------------------------
(a) On June 27, 1997 a renewal application for this permit was submitted to the
MPCA. A new permit is expected to be issued in the second quarter of 1998.
Permits are extended by the timely filing of a renewal application which
stays the expiration of the previously issued permit.
(b) A renewal application for this permit is due April 30, 1998. The renewal
application is expected to be filed on or before March 30, 1998.
The Company holds FERC licenses authorizing the ownership and operation
of seven hydroelectric generating projects with a total generating capacity of
about 118 MW.
FERC LICENSES FOR HYDROELECTRIC PROJECTS
- - - --------------------------------------------------------------------------------
Name Plate
Facility Rating Effective Date Expiration Date
- - - -------- ---------- -------------- ---------------
MW
Pillager 1.5 May 12, 1997 May 11, 1998 (a)
Blanchard 18.0 December 1, 1987 August 24, 2003 (b)
Winton 4.0 March 1, 1981 October 31, 2003 (b)
Little Falls 4.7 January 1, 1994 December 31, 2023
Prairie River 1.1 January 1, 1994 December 31, 2023
Sylvan 1.8 January 1, 1994 December 31, 2023
St. Louis River 87.6 July 1, 1995 June 30, 2035 (c)
- - - --------------------------------------------------------------------------------
(a) The FERC issued an annual license to the Company under the existing license
terms and conditions. This annual license is effective until the new license
is issued. An application to relicense this facility was filed with the FERC
on May 11, 1995. The FERC will perform an engineering, environmental and
economic analysis of that application in order to determine whether to issue
a new license for the project. FERC scoping meetings to discuss any
environmental and operational issues related to this project were held in
October 1996 with the resource agencies and the public. The FERC staff
sought input related to any water quality, fishery, terrestrial, cultural
and recreation issues that the agencies and public have prior to preparing
the environmental assessment for this project. To date, no substantive
issues have been raised by the resource agencies or the public in the
license process.
(b) The Company is currently in the planning stages for the relicensing of this
facility.
(c) The Company filed a request for rehearing of the FERC's order for the
purpose of challenging certain terms and conditions of the license which, if
accepted by the Company, would alter the Company's operation of the project.
In 1996 the FERC issued an order on rehearing in response to the rehearing
request and extended the license term from 30 to 40 years because of the
anticipated impact of the FERC's mandates to mitigate environmental
consequences of the project. The FERC also directed the Company to negotiate
with the Fond du Lac Band of Lake Superior Chippewa (Fond du Lac Band) a
reasonable annual charge for the use of tribal lands within the project. In
June 1996 the Company filed in the U.S. Court of Appeals for the District of
Columbia Circuit a petition for review of the license as issued by the FERC.
Separate petitions for review were also filed in June 1996 in the same court
by the U.S. Department of the Interior and the Fond du Lac Band, two
intervenors in the licensing proceedings. The issues to be resolved concern
the terms and conditions of the license which will govern the Company's
operation and maintenance of the project. In July 1996 the court
consolidated the three petitions for review. In October 1996 the Company
filed with the court an unopposed motion for a procedural schedule pursuant
to which the briefing of the issues would be completed in May 1997. The
motion was granted by the court; however, the briefing schedule has been
suspended while the Company and the Fond du Lac Band negotiate the
reasonable fee for use of tribal lands as mandated by the new license. Both
parties have informed the court that these negotiations may resolve other
disputed issues, and they are obligated to report to the court periodically
the status of these discussions. Beginning in 1996, and most recently in
February 1998, the Company filed requests with the FERC for extensions of
time to comply with certain plans and studies required by the license which
might conflict with the settlement discussions. The FERC granted an
extension until August 1, 1998 to comply with those requirements.
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SOLID AND HAZARDOUS WASTE
The Resource Conservation and Recovery Act of 1976 regulates the
management and disposal of solid wastes. As a result of this legislation, the
EPA has promulgated various hazardous waste rules. The Company is required to
notify the EPA of hazardous waste activity and routinely submits the necessary
annual reports to the EPA.
In response to EPA Region V's request for utilities to participate in
their Great Lakes Initiative by voluntarily removing remaining polychlorinated
biphenyl (PCB) inventories, the Company has scheduled replacement of
PCB-contaminated oil from substation equipment by 2000 and the removal of PCB
capacitors by 2006. The total cost is expected to be between $1.5 million and $2
million of which $400,000 was expended through December 31, 1997. The Company
expects to spend about $110,000 in 1998.
MINING CONTROL AND RECLAMATION
BNI Coal's mining operations are governed by the Federal Surface Mining
Control and Reclamation Act of 1977. This Act, together with the rules and
regulations adopted thereunder by the Department of the Interior, Office of
Surface Mining Reclamation and Enforcement (OSM), governs the approval or
disapproval of all mining permits on federally owned land and the actions of the
OSM in approving or disapproving state regulatory programs regulating mining
activities. The North Dakota Reclamation of Strip Mined Lands Act and rules and
regulations enacted thereunder in 1969, as subsequently amended by the North
Dakota Mining and Reclamation Act and rules and regulations enacted thereunder
in 1977, govern the reclamation of surface mined lands and are generally as
stringent or more stringent than the federal rules and regulations. Compliance
is monitored by the North Dakota Public Service Commission. The federal and
state laws and regulations require a wide range of procedures including water
management, topsoil and subsoil segregation, stockpiling and revegetation, and
the posting of performance bonds to assure compliance. In general these laws and
regulations require the reclaiming of mined lands to a level of usefulness equal
to or greater than that available before active mining. The Company considers
BNI Coal to be in substantial compliance with those environmental regulations
currently applicable to its operations and believes all necessary permits to
conduct such operations have been obtained.
WATER SERVICES
Water Services are comprised of regulated and non-regulated wholly
owned subsidiaries of the Company. Water Services have been laying the
groundwork for future growth in several new areas of the water business.
Non-regulated subsidiaries have initiated marketing the Company's water
expertise outside traditional utility boundaries.
REGULATED SUBSIDIARIES
- FLORIDA WATER, the largest investor owned water supplier in
Florida, owns and operates water and wastewater treatment
facilities within that state. As of December 31, 1997 Florida
Water served 119,000 water customers and 52,000 wastewater
treatment customers.
In 1997 Florida Water sold certain water and wastewater assets to
Orange County in Florida for $13.1 million. These assets served
about 4,000 customers. The transaction resulted in a $4.7 million
after-tax gain.
- HEATER owns and operates four companies which provide water and
wastewater treatment services primarily in North Carolina. As of
December 31, 1997 these companies served 28,000 water customers
and 2,000 wastewater treatment customers.
In 1997 the NCUC approved the transfer of LaGrange Waterworks
Corporation (LaGrange) to Heater. The Company exchanged 96,000
shares of common stock, with a market value of approximately $3.4
million, for the outstanding shares of LaGrange. The transaction
was accounted for as a pooling of interest. LaGrange provides
water services to approximately 5,300 customers near Fayetteville,
North Carolina.
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NON-REGULATED SUBSIDIARIES
- INSTRUMENTATION SERVICES, INC. provides predictive maintenance
and instrumentation consulting services to water and wastewater
utilities, and other industrial operations throughout the
southeastern part of the United States as well as Texas and
Minnesota.
- U.S. MAINTENANCE AND MANAGEMENT SERVICES CORPORATION was
incorporated in 1997 to complement ISI's operations. U.S.
Maintenance and Management provides maintenance services to
water and wastewater utilities and other industrial operations
primarily in Florida.
- AMERICAS' WATER SERVICES CORPORATION was incorporated in 1997.
Headquartered near Chicago, Illinois, Americas' Water offers
contract management, operations and maintenance services to
governments and industries throughout the Americas.
REGULATORY ISSUES
FLORIDA PUBLIC SERVICE COMMISSION
- 1991 RATE CASE REFUNDS. In 1995 the Florida First District Court
of Appeals (Court of Appeals) reversed a 1993 FPSC order
establishing uniform rates for most of Florida Water's service
areas. With "uniform rates," all customers in each uniform rate
area pay the same rates for water and wastewater services. In
response to the Court of Appeals' order, in August 1996 the FPSC
ordered Florida Water to issue refunds to those customers who paid
more since October 1993 under uniform rates than they would have
paid under stand-alone rates. This order did not permit a
balancing surcharge to customers who paid less under uniform
rates. Florida Water appealed, and the Court of Appeals ruled in
June 1997 that the FPSC could not order refunds without balancing
surcharges. In response to the Court of Appeals' ruling, the FPSC
issued an order on January 26, 1998 that would not require Florida
Water to refund about $12.5 million, which included interest, to
customers who paid more under uniform rates.
In the same January 26, 1998 order, the FPSC required Florida
Water to refund $2.5 million, the amount paid by customers in the
Spring Hill service area from January 1996 through June 1997 under
uniform rates which exceeded the amount these customers would have
paid under a modified stand-alone rate structure. No balancing
surcharge was permitted. The FPSC ordered this refund because
Spring Hill customers continued to pay uniform rates after other
customers began paying modified stand-alone rates effective
January 1996 pursuant to the FPSC's interim rate order in Florida
Water's 1995 Rate Case. The FPSC did not include Spring Hill in
this interim rate order because Hernando County had assumed
jurisdiction over Spring Hill's rates. In June 1997 Florida Water
reached an agreement with Hernando County to revert to stand-alone
rates for Spring Hill customers.
Customer groups which paid more under uniform rates have appealed
the FPSC's January 26, 1998 order. The Company has also appealed
the $2.5 million refund order. No provision for refund has been
recorded.
- 1995 RATE CASE. Florida Water requested an $18.1 million rate
increase in June 1995 for all water and wastewater customers of
Florida Water regulated by the FPSC. In October 1996 the FPSC
issued its final order approving an $11.1 million annual increase.
In November 1996 Florida Water filed with the Court of Appeals an
appeal of the FPSC's final order seeking judicial review of issues
relating to the amount of investment in utility facilities
recoverable in rates from current customers. Other parties to the
rate case also filed appeals. In June 1997, as part of the review
process, the FPSC allowed Florida Water to resume collecting
approximately $1 million, on an annual basis, in new customer
connection fees. Oral argument on the appeal was heard by the
Court of Appeals on February 10, 1998. The Company is unable to
predict the timing or outcome of the appeals process.
- HILLSBOROUGH COUNTY RATES. On July 2, 1997 Florida Water filed
for a rate change with the Hillsborough County Utilities
Department. Florida Water filed for an annual interim rate
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increase of $848,845 (43.1 percent) and a final rate increase of
$877,607 (44.6 percent). Interim rates became effective on August
18, 1997. Hearings are scheduled for April, May and June 1998. It
is anticipated that final rates will be implemented in July 1998.
The Company is unable to predict the outcome of this case.
NORTH CAROLINA UTILITIES COMMISSION
On September 30, 1997 Heater filed with the NCUC for a $1.1 million
annual increase for its water and wastewater customers. The hearing was held on
March 10, 1998. The annual increase in operating revenue is expected to be
$343,000. The test year was adjusted for customer growth and consumption which
substantially decreased the annual rate increase required. A final order from
the NCUC is expected in May 1998.
CAPITAL EXPENDITURE PROGRAM
Capital expenditures for Water Services totaled $22 million during
1997. Expenditures were funded with internally generated funds. Capital
expenditures for the Company's Water Services are expected to be $22 million in
1998 to meet environmental standards, expand water and wastewater treatment
facilities to accommodate customer growth, and for water conservation
initiatives. Capital expenditures are expected to total approximately $110
million during the period 1999 through 2002.
COMPETITION
Water Services provide water and wastewater services at regulated rates
within exclusive service territories granted by regulators.
With respect to non-regulated businesses within Water Services,
significant competition exists for the provision of the types of services
provided by Americas' Water. Although a few private contractors control a large
percentage of the market for contract management, operations and maintenance
services, the Company believes that the current and anticipated growth in that
market will allow for emerging companies like Americas' Water to succeed.
FRANCHISES
Florida Water provides water and wastewater treatment services in 21
counties regulated by the FPSC and holds franchises in three counties which
have retained authority to regulate such operations. (See Regulatory Issues
- - - - Florida Public Service Commission.)
Water and wastewater services provided by Heater are under the
jurisdiction of the NCUC. The commission grants franchises for Heater's service
territory when the rates are authorized.
ENVIRONMENTAL MATTERS
The Company's Water Services are subject to regulation by various
federal, state and local authorities with respect to water quality, solid wastes
and other environmental matters. The Company considers these businesses to
generally be in compliance with those environmental regulations currently
applicable to its operations and have the permits necessary to conduct such
operations. The Company does not currently anticipate that potential capital
expenditures for environmental matters will be material. However, because
environmental laws and regulations are constantly evolving, the character, scope
and ultimate costs of environmental compliance cannot be estimated.
UNIVERSITY SHORES AND SEABOARD FACILITIES
In 1993 the EPA notified Florida Water of alleged exceedences of
effluent limitations in its NPDES permit for Florida Water's University Shores
wastewater facility in Orange County, Florida. During 1993 and 1994, Florida
Water periodically corresponded and met with the EPA concerning the alleged
exceedences of the permit. The matters at issue were resolved in February 1994
when the University Shores facility was modified such that effluent was no
longer discharged to surface waters. In 1992 the EPA notified Florida Water of
alleged exceedences of effluent limitations in the NPDES permit for Florida
Water's Seaboard wastewater treatment facility in Hillsborough County, Florida.
Between 1992 and 1994,
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Florida Water periodically corresponded and met with the EPA concerning alleged
exceedences of the permit. In March 1994 the matters at issue were resolved when
the facility was taken out of service and the collection system was
interconnected with the City of Tampa utilities. In 1997 the United States
Department of Justice (DOJ), on behalf of the EPA, served Florida Water with a
complaint in a civil action in the U.S. District Court for the Middle District
of Florida (District Court). The suit sought civil penalties not to exceed
$25,000 per day for each alleged violation of effluent limitations in the NPDES
permits occurring at the University Shores and Seaboard wastewater facilities
from February 1992 through March 1994. In 1998 Florida Water, the DOJ and the
EPA executed a Consent Decree as a settlement of the complaint filed in 1997.
The Consent Decree requires Florida Water to pay a $250,000 civil penalty;
complete a Supplemental Environmental Project totaling $200,000; and complete an
additional environmental project totaling $450,000. After a 30 day period for
notice and public comment, the Consent Decree will be filed with the District
Court for approval.
AUTOMOTIVE SERVICES
Automotive Services include wholly owned subsidiaries operating as
integral parts of the vehicle auction business: ADESA, a network of vehicle
auctions; AFC, a finance company; and Great Rigs, an auto transport company. The
Company acquired 80 percent of ADESA, including AFC and Great Rigs, on July
1, 1995. The Company increased its ownership interest to 83 percent in January
1996 and acquired the remaining 17 percent interest in August 1996. Automotive
Services plans on growth through selective acquisitions and expanding services.
- ADESA is the third largest vehicle auction network in the United
States. Headquartered in Indianapolis, Indiana, ADESA owns and
operates 25 vehicle auction facilities in the United States and
Canada through which used cars and other vehicles are sold to
franchised automobile dealers and licensed used car dealers.
Sellers at ADESA's auctions include domestic and foreign auto
manufacturers, car dealers, automotive fleet/lease companies,
banks and finance companies. During 1997 ADESA sold one of its
auction facilities in Florida, acquired a new auction facility in
Sacramento, California and 80 percent of another auction facility
in Columbus, Indiana.
PROFESSIONAL AUTO REMARKETING (PAR), a division of ADESA,
provides customized remarketing services to various businesses
with fleet operations.
- AUTOMOTIVE FINANCE CORPORATION provides inventory financing for
wholesale and retail automobile dealers who purchase vehicles from
ADESA auctions, independent auctions and other auction chains. AFC
is headquartered in Indianapolis, Indiana, and has 57 loan
production offices which are located at most ADESA auctions, as
well as at or near independently owned auto auctions. From these
offices car dealers obtain credit to purchase vehicles at any of
the over 300 auctions approved by AFC. During 1997 AFC added 25
loan production offices. In early 1998 three more loan production
offices were added.
- GREAT RIGS is one of the nation's largest independent used
automobile transport carriers with 110 leased automotive carriers
operating as an integral part of the vehicle auction business.
Headquartered in Moody, Alabama, Great Rigs offers customers pick
up and delivery through 11 strategically located transportation
hubs. Customers of Great Rigs include ADESA auctions, car
dealerships, vehicle manufacturers, leasing companies, finance
companies and other auctions. Major customers include GE Capital,
Nissan, Ford Motor Credit and General Motors Acceptance Corp. By
the end of second quarter 1998, Great Rigs expects to expand its
fleet to 150 automobile carriers.
CAPITAL EXPENDITURE PROGRAM
Capital expenditures for automobile auction site relocation,
development and facility improvements were $11 million during 1997. Capital
expenditures for Automotive Services are expected to be $24 million in 1998 and
to total approximately $47 million during the period 1999 through 2002. Capital
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expenditures in 1998 are for on-going improvements and relocation of existing
vehicle auction facilities, and associated information systems.
COMPETITION
Within the automobile auction industry, ADESA's competition includes
independently owned auctions as well as major chains and associations with
auctions in geographic proximity. ADESA competes with other auctions for a
supply of vehicles to be sold on consignment for automobile dealers, financial
institutions and other sellers. ADESA also competes for a supply of rental
repurchase vehicles from automobile manufacturers for auction at factory sales.
Automobile manufacturers often choose between auctions across multi-state areas
in distributing rental repurchase vehicles. ADESA competes for these customers
by attempting to attract a large number of dealers to purchase vehicles, which
ensures competitive prices and supports the volume of vehicles auctioned. ADESA
also competes by providing a full range of services including dealer inventory
financing, reconditioning services which prepare vehicles for auction,
transporting vehicles and the prompt processing of sale transactions. Another
factor affecting the industry, the impact of which is yet to be determined, is
the entrance of large used car dealerships called "superstores" that have
emerged in densely populated markets.
AFC is well positioned as a provider of floorplan financing services to
the used vehicle industry. AFC's competition includes other specialty lenders,
as well as banks and other financial institutions. AFC competes with other
floorplan providers and strives to distinguish itself based upon convenience and
quality of service. A key component of AFC's program is conveniently located
loan production offices with personnel available to assist automobile dealers
with their financing needs. As part of AFC's continued effort to focus on
providing other financing services to dealers, in 1997 AFC entered into an
agreement with ACC Consumer Finance Corp. (ACC). ACC has subsequently been
acquired by Household International. Together these two companies will test a
program designed to promote ACC's retail financing of used vehicles floorplanned
by AFC.
ENVIRONMENTAL MATTERS
Certain businesses in the Company's Automotive Services segment are
subject to regulation by various federal, state and local authorities with
respect to air quality, water quality, solid wastes and other environmental
matters. The Company considers these businesses to be in substantial compliance
with those environmental regulations currently applicable to its operations and
believes all necessary permits to conduct such operations have been obtained.
The Company does not currently anticipate that potential capital expenditures
for environmental matters will be material. However, because environmental laws
and regulations are constantly evolving, the character, scope and ultimate costs
of environmental compliance cannot be estimated.
INVESTMENTS
The Investments segment is comprised of a securities portfolio, an
investment in a financial guaranty reinsurance and insurance company, and real
estate operations.
PORTFOLIO AND REINSURANCE
- SECURITIES PORTFOLIO. The Company's securities portfolio is
managed by selected outside managers as well as internal managers.
It is intended to provide stable earnings and liquidity, and is
available for investment in existing businesses, acquisitions and
other corporate purposes. The Company's objective is to maintain
corporate liquidity between 7 percent and 10 percent of total
assets ($150 million to $200 million). The Company plans to
continue to concentrate in market-neutral investment strategies
designed to provide stable and acceptable returns without
sacrificing needed liquidity. The securities portfolio is hedged
against market downturns and aimed at an after-tax return between
7 percent and 9 percent. While these returns may seem modest
compared to broader market indices over the past three years, the
Company believes its hedge strategy is a wise course in a volatile
economic
-16-
environment. Returns will continue to be partially dependent
on general market conditions. The Company's investment in the
securities portfolio at December 31, 1997 was $184 million
($155 million at December 31, 1996).
- REINSURANCE. Minnesota Power owns 3.3 million shares of Capital
Re, a specialty insurance and reinsurance business. Capital Re's
product lines currently include financial guaranty, mortgage,
title, financial, credit and specialty reinsurance, and specialty
insurance through its participation in Lloyds of London. Capital
Re trades on the New York Stock Exchange under the symbol KRE.
Minnesota Power's ownership represents 21 percent of the 16
million total outstanding shares of Capital Re. The market value
of the Company's investment in Capital Re was $203 million at
December 31, 1997 ($152 million at December 31, 1996) based on a
Capital Re share price of $62 5/16 ($46 5/8 at December 31, 1996).
The Company accounts for its investment in Capital Re under the
equity method and the carrying value was $119 million at December
31, 1997. Capital Re will continue to be a core component of the
Company's Investment segment.
- OTHER. Since 1985 the Company has invested about $8 million as a
shareholder in Utech Venture Capital Corporation (Utech). Utech
manages a group of venture capital funds that seek long-term
capital appreciation by making investments in companies developing
advanced technologies to be used by the utility industry. The
Company is committed to invest an additional $14 million over the
next five years. Minnesota Power has recognized dividends and
return of capital from the funds in the year they are paid. As
successful companies "go public" or are sold, investors, like
Minnesota Power, may realize income as the stock is sold and the
cash distributed.
In 1997 Minnesota Power loaned $4 million to Car Canada
Corporation, a start-up retail car "superstore" business with
stores in Ottawa and Toronto. The Company holds a 10 percent note
due 2002 for the principal amount of the loan. The note has five
equal payments due at the end of years one through five. The
Company also holds detachable warrants that can be exercised for
25 percent of the outstanding shares of Car Canada in exchange for
approximately $18,000. The warrants are exercisable automatically
in an initial public offering, or sale, or merger of the firm and
any other time at the sole option of Minnesota Power.
REAL ESTATE OPERATIONS
The Company owns 80 percent of Lehigh, a Florida real estate company
which owns property in three different locations. The real estate strategy is to
continue to acquire large community properties at low cost, add value and sell
them at going market prices.
- LEHIGH ACRES properties include 2,500 acres of land and
approximately 4,000 home sites near Fort Myers, Florida.
- SUGARMILL WOODS properties include 1,000 home sites in Citrus
County, Florida.
- PALM COAST properties include 2,700 home sites and 12,000 acres
of residential, commercial and industrial land at Palm Coast,
Florida. Palm Coast is a planned community between St. Augustine
and Daytona Beach.
ENVIRONMENTAL MATTERS
Certain businesses included in the Company's Investments segment are
subject to regulation by various federal, state and local authorities with
respect to air quality, water quality, solid wastes and other environmental
matters. The Company considers these businesses to be in substantial compliance
with those environmental regulations currently applicable to its operations and
believes all necessary permits to conduct such operations have been obtained.
The Company does not currently anticipate that potential capital expenditures
for environmental matters will be material. However, because environmental laws
and regulations are constantly evolving, the character, scope and ultimate costs
of environmental compliance cannot be estimated.
-17-
EXECUTIVE OFFICERS OF THE REGISTRANT
Initial
Executive Officers Effective Date
- - - ------------------ --------------
John A. Cirello, Age 54
Executive Vice President and President and
Chief Executive Officer - MP Water Resources
Group Inc. July 24, 1995
Donnie R. Crandell, Age 54
Senior Vice President and President - MP Real Estate
Holdings, Inc. January 1, 1996
Senior Vice President - Corporate Development December 1, 1994
Retired February 28, 1994
Vice President - Corporate Development March 1, 1993
Robert D. Edwards, Age 53
Executive Vice President and President - MP Electric July 26, 1995
Executive Vice President and Chief Operating Officer March 1, 1993
Group Vice President - Corporate Services and
Chief Financial Officer January 1, 1991
John E. Fuller, Age 54
Senior Vice President and President and
Chief Executive Officer - AFC April 23, 1997
President and
Chief Executive Officer - AFC January 1, 1994
Laurence H. Fuller, Age 49
Vice President - Corporate Development February 10, 1997
David G. Gartzke, Age 54
Senior Vice President - Finance and Chief
Financial Officer December 1, 1994
Vice President - Finance and Chief Financial Officer March 1, 1993
Vice President - Finance and Treasurer January 1, 1991
James P. Hallett, Age 44
Executive Vice President and President and
Chief Executive Officer - ADESA April 23, 1997
President and Chief Executive Officer - ADESA August 21, 1996
Philip R. Halverson, Age 50
Vice President, General Counsel and Secretary January 1, 1996
General Counsel and Corporate Secretary March 1, 1993
General Counsel and Assistant Secretary January 23, 1991
James A. Roberts, Age 47
Vice President - Corporate Relations January 1, 1996
Edwin L. Russell, Age 53
Chairman, President and Chief Executive Officer May 14, 1996
President and Chief Executive Officer January 22, 1996
President May 9, 1995
Mark A. Schober, Age 42
Controller March 1, 1993
James K. Vizanko, Age 44
Treasurer March 1, 1993
-18-
All of the executive officers above, except Mr. Cirello, Mr. Crandell,
Mr. John Fuller, Mr. Laurence Fuller, Mr. Hallet and Mr. Russell, have been
employed by the Company for more than five years in executive or management
positions.
- Mr. Cirello was president of Metcalf & Eddy Services, Inc. from
1992 to 1995, responsible for $64 million in water/wastewater
operation services.
- Mr. Crandell was director of business development of the Company,
vice president of Topeka Group Incorporated and vice president of
business development for Topeka Group Incorporated prior to March
1, 1993.
- Mr. John Fuller was previously president and 50 percent owner of
CITA, Inc., which he founded in 1987 (CITA was renamed Automotive
Finance Corporation in December 1993 and sold to ADESA in January
1994).
- Mr. Laurence Fuller was previously senior vice president, new
business development and strategic planning, for Diners Club
International, a subsidiary of Citicorp, Inc.
- Mr. Hallet was previously executive vice president of ADESA
and president of ADESA's Canadian operations.
- Mr. Russell was previously group vice president of J. M. Huber
Corporation, a $1.5 billion diversified manufacturing and natural
resources company.
Prior to election to the positions shown above, Mr. Roberts, Mr.
Schober and Mr. Vizanko held other positions with the Company after January 1,
1993.
- Mr. Roberts was director of corporate relations.
- Mr. Schober was director of internal audit.
- Mr. Vizanko was director of investments and analysis.
There are no family relationships between any executive officers of the
Company. All officers and directors are elected or appointed annually.
The present term of office of the above executive officers extends to
the first meeting of the Company's Board of Directors after the next annual
meeting of shareholders. Both meetings are scheduled for May 12, 1998.
-19-
ITEM 2. PROPERTIES.
ELECTRIC OPERATIONS
The Company had an annual and all-time record net peak load of 1,476 MW
on February 10, 1997. Information with respect to existing power supply sources
is shown below.
Unit Year Net Winter Net Electric
Power Supply No. Installed Capability Requirements
- - - -------------------------------------------------------------------------------------------------------------------
MW MWh %
Steam
Coal-Fired
Boswell Energy Center
near Grand Rapids, MN 1 1958 69
2 1960 69
3 1973 350
4 1980 428
------
916 5,618,246 43.7%
------
Laskin Energy Center
Hoyt Lakes, MN 1 1953 55
2 1953 55
------
110 537,875 4.2
------
Purchased Steam
M. L. Hibbard
Duluth, MN 3 1949 33 814 -
------ ---------- ------
Total Steam 1,059 6,156,935 47.9
------ ---------- ------
Hydro
Group consisting of ten stations in MN Various 118 578,020 4.5
------ ---------- ------
Purchased Power
Square Butte burns lignite in Center, ND 322 2,307,308 18.0
All other - net - 3,802,005 29.6
------ ---------- ------
Total Purchased Power 322 6,109,313 47.6
------ ---------- ------
For the Year Ended December 31, 1997 1,499 12,844,268 100.0%
- - - -------------------------------------------------------------------------------------------------------------------
The Company has electric transmission and distribution lines of 500
kilovolts (kV) (8 miles), 230 kV (606 miles), 161 kV (43 miles), 138 kV (6
miles), 115 kV (1,260 miles) and less than 115 kV (6,176 miles). The Company
owns and operates 176 substations with a total capacity of 8,533
megavoltamperes. Some of the transmission and distribution lines interconnect
with other utilities.
The Company owns and has a substantial investment in offices and
service buildings, area headquarters, an energy control center, repair shops,
motor vehicles, construction equipment and tools, office furniture and
equipment, and leases offices and storerooms in various localities within the
Company's service territory. It also owns miscellaneous parcels of real estate
not presently used in Electric Operations.
Substantially all of the electric plant of the Company is subject to
the lien of its Mortgage and Deed of Trust which secures first mortgage bonds
issued by the Company. The Company's properties are held by it in fee and are
free from other encumbrances, subject to minor exceptions, none of which are of
such a nature as to substantially impair the usefulness to the Company of such
properties. Other property, including certain offices and equipment, is utilized
under leases. In general, some of the electric lines are located on land not
owned in fee, but are covered by necessary consents of various governmental
authorities or by appropriate rights obtained from owners of private property.
These consents and rights are deemed adequate for the purposes for which the
properties are being used. In September 1990 the Company sold a portion of
Boswell Unit 4 to WPPI. WPPI has the right to use the Company's transmission
line facilities to transport its share of generation.
-20-
Substantially all of the plant of SWL&P is subject to the lien of its
Mortgage and Deed of Trust which secures first mortgage bonds issued by SWL&P.
A large dragline, shop complex, and certain other less significant
property and equipment items at BNI Coal are leased under a leveraged lease
agreement that expires in 2002. Certain computer and other equipment are leased
under operating lease agreements that expire in 2000 and 2007, respectively. All
other property and equipment is owned by BNI Coal.
The Company is a member of the Mid-Continent Area Power Pool (MAPP).
The MAPP enhances electric service reliability, and provides the opportunity for
members to enter into various wholesale power transactions and coordinate
planning, installation and operation of new generation and transmission
facilities. The MAPP membership consists of various electric power suppliers
located in North Dakota, South Dakota, eastern Montana, Nebraska, Iowa,
Minnesota, Wisconsin, upper Michigan, Kansas, Manitoba and Saskatchewan, and
marketers and brokers located throughout North America. The electric power
suppliers are investor-owned utilities including the Company, rural electric
generation and transmission cooperatives, public power districts, municipal
electric systems, municipal organizations, and the Western Area Power
Administration - Billings, Montana. MAPP operates pursuant to an agreement that
was approved by MAPP members on March 15, 1996, accepted by the FERC and became
effective on November 1, 1996.
WATER SERVICES
Florida Water is the largest investor owned provider of water and
wastewater services in Florida, serving more than 170,000 customers in 145
service areas. Florida Water maintains 149 water and wastewater facilities
throughout the state with plants ranging in size from 6 connections to greater
than 25,000 connections. Florida Water provides its customers with 14 billion
gallons of water per year primarily from Florida's underground aquifer.
Substantially all of Florida Water's properties used in its water and wastewater
operations are encumbered by a mortgage.
Heater has water and wastewater systems located in subdivisions
surrounding Raleigh, North Carolina and Fayetteville, North Carolina. Water
supply is primarily from ground water deep wells. Community ground water
systems vary in size from 25 connections to 6,000 connections. Some
systems are supplied by purchased water. Heater has approximately 223
systems and 436 wells serving 28,000 customers. Heater also has 8 wastewater
treatment plants, ranging in size from 35,000 gallons per day (gpd) to 250,000
gpd, and 19 lift stations located in its wastewater collection systems. These
systems serve approximately 2,000 customers. Substantially all of Heater's
properties used in its water and wastewater operations are encumbered by a
mortgage.
INVESTMENTS
Property within the Company's real estate operations consists of 2,500
acres of land and approximately 4,000 home sites near Fort Myers, Florida; 1,000
home sites in Citrus County, Florida; and 2,700 home sites and 12,000 acres of
residential, industrial and commercial land at Palm Coast, Florida.
-21-
AUTOMOTIVE SERVICES
The following table sets forth the vehicle auctions currently owned or
leased by ADESA. Each auction has a multi-lane, drive-through auction facility,
as well as additional buildings for reconditioning, registration, maintenance,
body work, and other ancillary and administrative services. Each auction also
has secure parking areas in which it stores vehicles for auction. All vehicle
auction property owned by ADESA is subject to liens securing various notes
payable.
Year No.
Operations Auction
ADESA Auctions Location Commenced Lanes
- - - -------------------------------------------------------------------------------------------------------------------
United States
ADESA Birmingham Moody, Alabama 1987 10
ADESA Sacramento <F1> Sacramento, California 1997 5
ADESA Jacksonville Jacksonville, Florida 1996 6
ADESA South Florida <F1><F2> Opa-Locka, Florida (near Miami) 1994 7
ADESA Southern Indiana <F1><F3> Columbus, Indiana 1997 3
ADESA Indianapolis Plainfield, Indiana 1983 10
ADESA Lexington Lexington, Kentucky 1982 6
ADESA Boston <F1> Framingham, Massachusetts 1995 11
ADESA New Jersey Manville, New Jersey 1996 8
ADESA Buffalo Akron, New York 1992 10
ADESA Charlotte <F1> Charlotte, North Carolina 1994 8
ADESA Cincinnati/Dayton Franklin, Ohio 1986 8
ADESA Cleveland <F1> Northfield, Ohio 1994 8
ADESA Pittsburgh Mercer, Pennsylvania 1971 7
ADESA Knoxville <F1> Lenoir City, Tennessee 1984 6
ADESA Memphis Memphis, Tennessee 1990 6
ADESA Austin <F1> Austin, Texas 1990 6
ADESA Dallas Mesquite, Texas 1990 6
ADESA Houston Houston, Texas 1995 3
ADESA San Antonio San Antonio, Texas 1989 5
ADESA Wisconsin Portage, Wisconsin 1984 5
Canada
ADESA Moncton <F1> Moncton, New Brunswick 1996 2
ADESA Halifax <F1> Lr. Sackville, Nova Scotia 1993 2
ADESA Ottawa Vars, Ontario 1990 5
ADESA Montreal St. Eustache, Quebec 1974 8
- - - -------------------------------------------------------------------------------------------------------------------
<FN>
<F1> Leased auction facilities. (See Note 14.)
<F2> ADESA owns 51 percent of this auction business.
<F3> ADESA owns 80 percent of this auction business.
</FN>
AFC has loan production offices in 57 locations across North America.
Many offices are within auction facilities operated by ADESA and independent
auctions.
Great Rigs leases its fleet of 110 automobile carriers under operating
leases.
ITEM 3. LEGAL PROCEEDINGS.
Material legal and regulatory proceedings are included in the
discussion of the Company's business in Item 1 and are incorporated by reference
herein.
-22-
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.
No matters were submitted to a vote of security holders during the
fourth quarter of 1997.
PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER
MATTERS.
The Company has paid dividends without interruption on its common stock
since 1948. A quarterly dividend of $.51 per share on the common stock was paid
on March 2, 1998 to the holders of record on February 16, 1998. The Company's
common stock is listed on the New York Stock Exchange. Dividends paid per share,
and the high and low prices for the Company's common stock for the periods
indicated as reported by The Wall Street Journal, Midwest Edition, were as
follows:
Dividends
Price Range Paid Per Share
----------- --------------
Quarter High Low Quarterly Annual
- - - --------------------------------------------------------------------------------
1997 - First $ 29 $ 27 1/4 $ .51
- Second 30 5/8 27 .51
- Third 36 5/16 30 1/4 .51
- Fourth 44 35 3/16 .51 $2.04
1996 - First $ 29 3/4 $ 26 1/8 $ .51
- Second 29 26 .51
- Third 28 3/4 26 .51
- Fourth 28 7/8 26 3/8 .51 $2.04
- - - --------------------------------------------------------------------------------
The amount and timing of dividends payable on the Company's common
stock are within the sole discretion of the Company's Board of Directors. In
1997 the Company paid out 82 percent of its per share earnings in dividends.
Through increased earnings, the Company's goal is to reduce dividend payout to
between 75 percent and 80 percent of per share earnings.
The Company's Articles of Incorporation, and Mortgage and Deed of Trust
contain provisions which under certain circumstances would restrict the payment
of common stock dividends. As of December 31, 1997 no retained earnings were
restricted as a result of these provisions. At March 2, 1998 there were
approximately 37,000 common stock shareholders of record.
-23-
ITEM 6. SELECTED FINANCIAL DATA.
Financial information presented in the table below may not be
comparable between periods due to: (1) the Company's purchase of 80 percent of
ADESA, including AFC and Great Rigs, on July 1, 1995, another 3 percent in
January 1996 and the remaining 17 percent in August 1996; and (2) and the
Company's sale of its interest in the paper and pulp business to Consolidated
Papers, Inc. on June 30, 1995.
1997 1996 1995 1994 1993
- - - -------------------------------------------------------------------------------------------------------------------
Millions except per share amounts
Operating Revenue and Income $953.6 $846.9 $672.9 $582.2 $582.5
Income (Loss)
Continuing Operations $77.6 $69.2 $61.9 $59.5 $64.4
Discontinued Operations - - 2.8 1.8 (1.8)
------ ------ ------ ----- ------
Net Income $77.6 $69.2 $64.7 <F1> $61.3 <F2> $62.6
====== ====== ====== ===== ======
Basic and Diluted Earnings Per Share
Continuing Operations $ 2.47 $ 2.28 $ 2.06 $1.99 $2.27
Discontinued Operations - - .10 .07 (.07)
------ ------ ------ ----- ------
Total $ 2.47 $ 2.28 $ 2.16 $2.06 $2.20
====== ====== ====== ===== ======
Dividends Per Share $2.04 $2.04 $2.04 $2.02 $1.98
Total Assets $2,172.3 $2,146.0 $1,947.6 $1,807.8 $1,760.5
Long-Term Debt $685.4 $694.4 $639.5 $601.3 $611.0
Redeemable Preferred Stock $20.0 $20.0 $20.0 $20.0 $20.0
Cumulative Quarterly Income
Preferred Securities $75.0 $75.0 - - -
- - - -------------------------------------------------------------------------------------------------------------------
<FN>
<F1> Included $14.7 million from the recognition of tax benefits associated with
real estate operations and a $3.8 million reduction associated with exiting
the equipment manufacturing business.
<F2> Included $11.8 million from the sale of certain water plant assets, $3.6
million from the recognition of escrow funds associated with real estate
operations, a $5.9 million decrease from the write-off of an investment and
a $3 million loss from the equipment manufacturing business.
</FN>
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS.
The management's discussion and analysis of financial condition and
results of operations appearing on pages 18 through 31 of the Minnesota Power
1997 Annual Report are incorporated by reference in this Form 10-K Annual
Report.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
The financial statements, together with the report thereon of Price
Waterhouse LLP dated January 26, 1998 appearing on pages 32 through 50 of the
Minnesota Power 1997 Annual Report, are incorporated by reference in this Form
10-K Annual Report.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE.
Not applicable.
-24-
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT.
The information required for this Item is incorporated by reference
herein from the "Election of Directors" section in the Company's Proxy Statement
for the 1998 Annual Meeting of Shareholders, except for information with respect
to executive officers which is set forth in Part I hereof.
ITEM 11. EXECUTIVE COMPENSATION.
The information required for this Item is incorporated by reference
herein from the "Compensation of Executive Officers" section in the Company's
Proxy Statement for the 1998 Annual Meeting of Shareholders.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT.
The information required for this Item is incorporated by reference
herein from the "Security Ownership of Certain Beneficial Owners and Management"
section in the Company's Proxy Statement for the 1998 Annual Meeting of
Shareholders.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.
The information required for this Item is incorporated by reference
herein from the "Compensation Committee Interlocks and Insider Participation"
section in the Company's Proxy Statement for the 1998 Annual Meeting of
Shareholders.
-25-
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K.
(a) Certain Documents Filed as Part of Form 10-K.
(1) Financial Statements
Pages in
Annual Report*
--------------
Minnesota Power
Report of Independent Accountants 31
Consolidated Balance Sheet at December 31, 1997
and 1996 32
For the three years ended December 31, 1997
Consolidated Statement of Income 34
Consolidated Statement of Retained Earnings 34
Consolidated Statement of Cash Flows 35
Notes to Consolidated Financial Statements 36-50
- - - ---------------
* Incorporated by reference herein from the Minnesota Power 1997 Annual Report.
Page
----
(2) Financial Statement Schedules
Report of Independent Accountants on Financial
Statement Schedule 32
Minnesota Power and Subsidiaries Schedule:
II-Valuation and Qualifying Accounts
and Reserves 33
All other schedules have been omitted either because the information is
not required to be reported by the Company or because the information is
included in the consolidated financial statements or the notes thereto.
(3) Exhibits including those incorporated by reference
Exhibit
Number
- - - -------
*2 - Agreement and Plan of Merger by and among Minnesota Power &
Light Company, AC Acquisition Sub, Inc., ADESA Corporation and
Certain ADESA Management Shareholders dated February 23, 1995
(filed as Exhibit 2 to Form 8-K dated March 3, 1995, File No.
1-3548).
*3(a)1 - Articles of Incorporation, restated as of July 27, 1988 (filed as
Exhibit 3(a), File No. 33-24936).
*3(a)2 - Certificate Fixing Terms of Serial Preferred Stock A, $7.125
Series (filed as Exhibit 3(a)2, File No. 33-50143).
*3(a)3 - Certificate Fixing Terms of Serial Preferred Stock A, $6.70
Series (filed as Exhibit 3(a)3, File No. 33-50143).
*3(b) - Bylaws as amended January 23, 1991 (filed as Exhibit 3(b), File
No. 33-45549).
-26-
Exhibit
Number
- - - -------
*4(a)1 - Mortgage and Deed of Trust, dated as of September 1, 1945, between
the Company and Irving Trust Company (now The Bank of New York)and
Richard H. West (W.T. Cunningham, successor), Trustees (filed as
Exhibit 7(c), File No. 2-5865).
*4(a)2 - Supplemental Indentures to Mortgage and Deed of Trust:
Reference
Number Dated as of File Exhibit
------ ----------- ---- -------
First March 1, 1949 2-7826 7(b)
Second July 1, 1951 2-9036 7(c)
Third March 1, 1957 2-13075 2(c)
Fourth January 1, 1968 2-27794 2(c)
Fifth April 1, 1971 2-39537 2(c)
Sixth August 1, 1975 2-54116 2(c)
Seventh September 1, 1976 2-57014 2(c)
Eighth September 1, 1977 2-59690 2(c)
Ninth April 1, 1978 2-60866 2(c)
Tenth August 1, 1978 2-62852 2(d)2
Eleventh December 1, 1982 2-56649 4(a)3
Twelfth April 1, 1987 33-30224 4(a)3
Thirteenth March 1, 1992 33-47438 4(b)
Fourteenth June 1, 1992 33-55240 4(b)
Fifteenth July 1, 1992 33-55240 4(c)
Sixteenth July 1, 1992 33-55240 4(d)
Seventeenth February 1, 1993 33-50143 4(b)
Eighteenth July 1, 1993 33-50143 4(c)
Nineteenth February 1, 1997 1-3548 (1996 Form 10-K) 4(c)
4(a)3 - Twentieth Supplemental Indenture, dated as of November 1, 1997,
between the Company and The Bank of New York (formerly Irving
Trust Company) and W.T. Cunningham (successor to Richard H. West),
Trustees.
*4(b) - Mortgage and Deed of Trust, dated as of March 1, 1943, between
Superior Water, Light and Power Company and Chemical Bank & Trust
Company and Howard B. Smith, as Trustees, both succeeded by First
Bank N.A., as Trustee (filed as Exhibit 7(c), File No. 2-8668), as
supplemented and modified by First Supplemental Indenture thereto
dated as of March 1, 1951 (filed as Exhibit 2(d)(1), File No.
2-59690), Second Supplemental Indenture thereto dated as of March
1, 1962 (filed as Exhibit 2(d)1, File No. 2-27794), Third
Supplemental Indenture thereto dated July 1, 1976 (filed as
Exhibit 2(e)1, File No. 2-57478), Fourth Supplemental Indenture
thereto dated as of March 1, 1985 (filed as Exhibit 4(b), File No.
2-78641), Fifth Supplemental Indenture thereto dated as of
December 1, 1992 (filed as Exhibit 4(b)1 to Form 10-K for the year
ended December 31, 1992, File No. 1-3548), Sixth Supplemental
Indenture, dated as of March 24, 1994 (filed as Exhibit 4(b)1 to
Form 10-K for the year ended December 31, 1996, File No. 1-3548),
Seventh Supplemental Indenture, dated as of November 1, 1994
(filed as Exhibit 4(b)2 to Form 10-K for the year ended December
31, 1996, File No. 1-3548) and Eighth Supplemental Indenture,
dated as of January 1, 1997 (filed as Exhibit 4(b)3 to Form 10-K
for the year ended December 31, 1996, File No. 1-3548).
-27-
Exhibit
Number
- - - -------
*4(c) - Indenture, dated as of March 1, 1993, between Southern States
Utilities, Inc. (now Florida Water Services Corporation) and
Nationsbank of Georgia, National Association (now SunTrust Bank,
Central Florida, N.A.), as Trustee (filed as Exhibit 4(d) to Form
10-K for the year ended December 31, 1992, File No. 1-3548), as
supplemented and modified by First Supplemental Indenture, dated
as of March 1, 1993 (filed as Exhibit 4(c)1 to Form 10-K for the
year ended December 31, 1996, File No. 1-3548), Second
Supplemental Indenture, dated as of March 31, 1997 (filed as
Exhibit 4 to Form 10-Q for the quarter ended March 31, 1997, File
No. 1-3548) and Third Supplemental Indenture, dated as of May 28,
1997 (filed as Exhibit 4 to Form 10-Q for the quarter ended June
30, 1997, File No. 1-3548).
*4(d) - Amended and Restated Trust Agreement, dated as of March 1, 1996,
relating to MP&L Capital I's 8.05% Cumulative Quarterly Income
Preferred Securities, between the Company, as Depositor, and The
Bank of New York, The Bank of New York (Delaware), Philip R.
Halverson, David G. Gartzke and James K. Vizanko, as Trustees
(filed as Exhibit 4(a) to Form 10-Q for the quarter ended March
31, 1996, File No. 1-3548).
*4(e) - Amendment No. 1, dated April 11, 1996, to Amended and Restated
Trust Agreement, dated as of March 1, 1996, relating to MP&L
Capital I's 8.05% Cumulative Quarterly Income Preferred Securities
(filed as Exhibit 4(b) to Form 10-Q for the quarter ended March
31, 1996, File No. 1-3548).
*4(f) - Indenture, dated as of March 1, 1996, relating to the Company's
8.05% Junior Subordinated Debentures, Series A, Due 2015, between
the Company and The Bank of New York, as Trustee (filed as Exhibit
4(c) to Form 10-Q for the quarter ended March 31, 1996, File No.
1-3548).
*4(g) - Guarantee Agreement, dated as of March 1, 1996, relating to MP&L
Capital I's 8.05% Cumulative Quarterly Income Preferred
Securities, between the Company, as Guarantor, and The Bank of New
York, as Trustee (filed as Exhibit 4(d) to Form 10-Q for the
quarter ended March 31, 1996, File No. 1-3548).
*4(h) - Agreement as to Expenses and Liabilities, dated as of March 20,
1996, relating to MP&L Capital I's 8.05% Cumulative Quarterly
Income Preferred Securities, between the Company and MP&L Capital
I (filed as Exhibit 4(e) to Form 10-Q for the quarter ended March
31, 1996, File No. 1-3548).
*4(i) - Officer's Certificate, dated March 20, 1996, establishing the
terms of the 8.05% Junior Subordinated Debentures, Series A, Due
2015 issued in connection with the 8.05% Cumulative Quarterly
Income Preferred Securities of MP&L Capital I.
*4(j) - Rights Agreement dated as of July 24, 1996, between Minnesota
Power & Light Company and the Corporate Secretary of Minnesota
Power & Light Company, as Rights Agent (filed as Exhibit 4 to Form
8-K dated August 2, 1996, File No. 1-3548).
*4(k) - Indenture, dated as of May 15, 1996, relating to the ADESA
Corporation's 7.70% Senior Notes, Series A, Due 2006, between
ADESA Corporation and The Bank of New York, as Trustee (filed as
Exhibit 4(k) to Form 10-K for the year ended December 31, 1996,
File No. 1-3548).
*4(l) - Guarantee of Minnesota Power & Light Company, dated as of May
30, 1996, relating to the ADESA Corporation's 7.70% Senior Notes,
Series A, Due 2006 (filed as Exhibit 4(l) to Form 10-K for the
year ended December 31, 1996, File No. 1-3548).
-28-
Exhibit
Number
- - - -------
*4(m) - ADESA Corporation Officer's Certificate 1-D-1, dated May 30,
1996, relating to the ADESA Corporation's 7.70% Senior Notes,
Series A, Due 2006 (filed as Exhibit 4(m) to Form 10-K for the
year ended December 31, 1996, File No. 1-3548).
*10(a) - Asset Holdings III, L.P. Note Purchase Agreement, dated as of
November 22, 1994 (filed as Exhibit 10(i) to Form 10-K for the
year ended December 31, 1995, File No. 1-3548).
*10(b) - Lease and Development Agreement, dated as of November 28, 1994
between Asset Holdings III, L.P., as Lessor and A.D.E. of
Knoxville, Inc., as Lessee (filed as Exhibit 10(j) to Form 10-K
for the year ended December 31, 1995, File No. 1-3548).
*10(c) - Lease and Development Agreement, dated as of November 28, 1994
between Asset Holdings III, L.P., as Lessor and ADESA-Charlotte,
Inc., as Lessee (filed as Exhibit 10(k) to Form 10-K for the year
ended December 31, 1995, File No. 1-3548).
*10(d) - Lease and Development Agreement, dated as of December 21, 1994
between Asset Holdings III, L.P., as Lessor and Auto Dealers
Exchange of Concord, Inc., as Lessee (filed as Exhibit 10(l) to
Form 10-K for the year ended December 31, 1995, File No. 1-3548).
*10(e) - Guaranty and Purchase Option Agreement between Asset Holdings
III, L.P. and ADESA Corporation, dated as of November 28, 1994
(filed as Exhibit 10(m) to Form 10-K for the year ended December
31, 1995, File No. 1-3548).
*10(f) - Receivables Purchase Agreement dated as of December 31, 1996,
among AFC Funding Corporation, as Seller, Automotive Finance
Corporation, as Servicer, Pooled Accounts Receivable Capital
Corporation, as Purchaser, and Nesbitt Burns Securities Inc., as
Agent (filed as Exhibit 10(f) to Form 10-K for the year ended
December 31, 1996, File No. 1-3548).
*10(g) - First Amendment to Receivables Purchase Agreement, dated as of
February 28, 1997, among AFC Funding Corporation, as Seller,
Automotive Finance Corporation, as Servicer, Pooled Accounts
Receivable Capital Corporation, as Purchaser, and Nesbitt Burns
Securities Inc., as Agent (filed as Exhibit 10(g) to Form 10-K for
the year ended December 31, 1996, File No. 1-3548).
*10(h) - Second Amendment to Receivables Purchase Agreement, dated as of
August 15, 1997, among AFC Funding Corporation, as Seller,
Automotive Finance Corporation, as Servicer, Pooled Accounts
Receivable Capital Corporation, as Purchaser, and Nesbitt Burns
Securities Inc., as Agent (filed as Exhibit 10 to Form 10-Q for
the quarter ended September 30, 1997, File No. 1-3548).
*10(i) - Purchase and Sale Agreement dated as of December 31, 1996,
between AFC Funding Corporation and Automotive Finance Corporation
(filed as Exhibit 10(h) to Form 10-K for the year ended December
31, 1996, File No. 1-3548).
+*10(j) - Minnesota Power Executive Annual Incentive Plan, effective January
1, 1996 (filed as Exhibit 10(a) to Form 10-K for the year ended
December 31, 1995, File No. 1-3548).
+*10(k) - Minnesota Power and Affiliated Companies Supplemental Executive
Retirement Plan, as amended and restated, effective August 1, 1994
(filed as Exhibit 10(b) to Form 10-K for the year ended December
31, 1995, File No. 1-3548).
+*10(l) - Executive Investment Plan-I, as amended and restated, effective
November 1, 1988 (filed as Exhibit 10(c) to Form 10-K for the year
ended December 31, 1988, File No. 1-3548).
-29-
Exhibit
Number
- - - -------
+*10(m) - Executive Investment Plan-II, as amended and restated, effective
November 1, 1988 (filed as Exhibit 10(d) to Form 10-K for the year
ended December 31, 1988, File No. 1-3548).
+*10(n) - Deferred Compensation Trust Agreement, as amended and restated,
effective January 1, 1989 (filed as Exhibit 10(f) to Form 10-K for
the year ended December 31, 1988, File No. 1-3548).
+*10(o) - Executive Long-Term Incentive Plan, as amended and restated,
effective January 1, 1994 (filed as Exhibit 10(e) to Form 10-K for
the year ended December 31, 1994, File No. 1-3548).
+*10(p) - Minnesota Power Executive Long-Term Incentive Compensation Plan,
effective January 1, 1996 (filed as Exhibit 10(a) to Form 10-Q for
the quarter ended June 30, 1996, File No. 1-3548).
+*10(q) - Directors' Long-Term Incentive Plan, as amended and restated,
effective January 1, 1994 (filed as Exhibit 10(f) to Form 10-K for
the year ended December 31, 1994, File No. 1-3548).
+*10(r) - Minnesota Power Director Stock Plan, effective January 1, 1995
(filed as Exhibit 10 to Form 10-Q for the quarter ended March 31,
1995, File No. 1-3548).
+*10(s) - Minnesota Power Director Long-Term Stock Incentive Plan,
effective January 1, 1996 (filed as Exhibit 10(b) to Form 10-Q for
the quarter ended June 30, 1996, File No. 1-3548).
12 - Computation of Ratios of Earnings to Fixed Charges and
Supplemental Ratios of Earnings to Fixed Charges.
13 - Minnesota Power 1997 Annual Report - Management's Discussion
and Analysis of Financial Condition and Results of Operations, and
the Company's financial statements listed in Item 14 (a)(1) of
this report.
*21 - Subsidiaries of the Registrant (reference is made to the Company's
Form U-3A-2 for the year ended December 31, 1997, File No. 69-78).
23(a) - Consent of Independent Accountants.
23(b) - Consent of General Counsel.
27 - Financial Data Schedule.
- - - ---------------------
* Incorporated herein by reference as indicated.
+ Management contract or compensatory plan or arrangement required to be
filed as an exhibit to this report pursuant to Item 14(c) of Form 10-K.
(b) Reports on Form 8-K.
Report on Form 8-K dated and filed on February 20, 1998 with respect to
Item 7. Financial Statements and Exhibits.
-30-
REPORT OF INDEPENDENT ACCOUNTANTS
ON FINANCIAL STATEMENT SCHEDULE
To the Board of Directors
of Minnesota Power
Our audits of the consolidated financial statements referred to in our
report dated January 26, 1998 appearing on page 32 of the 1997 Annual Report to
Shareholders of Minnesota Power (which report and consolidated financial
statements are incorporated by reference in this Annual Report on Form 10-K)
also included an audit of the Financial Statement Schedule listed in Item 14(a)
of this Form 10-K. In our opinion, the Financial Statement Schedule presents
fairly, in all material respects, the information set forth therein when read in
conjunction with the related consolidated financial statements.
Price Waterhouse LLP
PRICE WATERHOUSE LLP
Minneapolis, Minnesota
January 26, 1998
-31-
Schedule II
MINNESOTA POWER AND SUBSIDIARIES
VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
FOR THE YEARS ENDED DECEMBER 31, 1997, 1996 AND 1995
Millions
Additions
Balance at --------- Deductions Balance at
Beginning Charged Other from End of
of Year to Income Changes Reserves<F1> Period
- - - -------------------------------------------------------------------------------------------------------------------
Reserve deducted from related assets
Provision for uncollectible accounts
1997 Trade accounts receivable $ 6.6 $ 14.4 $ 0.2 $ 8.6 $12.6
Other accounts receivable 1.5 0.4 - 0.2 1.7
1996 Trade accounts receivable 3.3 4.7 1.4 2.8 6.6
Other accounts receivable 1.2 0.2 0.2 0.1 1.5
1995 Trade accounts receivable 1.0 3.0 1.5 2.2 3.3
Other accounts receivable 2.8 0.2 - 1.8 1.2
Deferred asset valuation allowance
1997 Deferred tax assets 0.7 (0.4) - - 0.3
1996 Deferred tax assets <F2> 8.9 (8.2) - - 0.7
1995 Deferred tax assets <F2> 26.8 (17.9) - - 8.9
- - - -------------------------------------------------------------------------------------------------------------------
<FN>
<F1> Provision for uncollectible accounts includes bad debts written off.
<F2> The deferred tax asset valuation allowance was reduced by $8.2 million in
1996 ($18.4 million in 1995) based on a detailed analysis of projected cash
flow as a result of a new business strategy for real estate operations.
(See Note 15.)
</FN>
-32-
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.
MINNESOTA POWER & LIGHT COMPANY
(Registrant)
Dated: March 25, 1998 By EDWIN L. RUSSELL
------------------------------
Edwin L. Russell
Chairman, President and
Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934,
this report has been signed below by the following persons on behalf of the
registrant and in the capacities and on the dates indicated.
Signature Title Date
--------- ----- ----
EDWIN L. RUSSELL March 25, 1998
- - - ----------------------------- Chairman, President,
Edwin L. Russell Chief Executive Officer
and Director
D.G. GARTZKE March 25, 1998
- - - ----------------------------- Senior Vice President -
D.G. Gartzke Finance and
Chief Financial Officer
MARK A. SCHOBER Controller March 25, 1998
- - - -----------------------------
Mark A. Schober
-33-
Signature Title Date
--------- ----- ----
KATHLEEN BREKKEN Director March 25, 1998
- - - -----------------------------
Kathleen Brekken
MERRILL K. CRAGUN Director March 25, 1998
- - - -----------------------------
Merrill K. Cragun
DENNIS E. EVANS Director March 25, 1998
- - - -----------------------------
Dennis E. Evans
PETER J. JOHNSON Director March 25, 1998
- - - -----------------------------
Peter J. Johnson
GEORGE L. MAYER Director March 25, 1998
- - - -----------------------------
George L. Mayer
PAULA F. MCQUEEN Director March 25, 1998
- - - -----------------------------
Paula F. McQueen
ROBERT S. NICKOLOFF Director March 25, 1998
- - - -----------------------------
Robert S. Nickoloff
JACK I. RAJALA Director March 25, 1998
- - - -----------------------------
Jack I. Rajala
EDWIN L. RUSSELL Director March 25, 1998
- - - -----------------------------
Edwin L. Russell
AREND J. SANDBULTE Director March 25, 1998
- - - -----------------------------
Arend J. Sandbulte
NICK SMITH Director March 25, 1998
- - - -----------------------------
Nick Smith
BRUCE W. STENDER Director March 25, 1998
- - - -----------------------------
Bruce W. Stender
DONALD C. WEGMILLER Director March 25, 1998
- - - -----------------------------
Donald C. Wegmiller
-34-