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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, 1998
/ / Transition Report Pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934
For the transition period from to
---------- ----------
Commission file number 1-3548
MINNESOTA POWER, INC.
(Exact name of registrant as specified in its charter)
Minnesota 41-0418150
(State or other jurisdiction of (I.R.S. Employer Identification No.)
incorporation or organization)
30 West Superior Street, Duluth, Minnesota 55802
(Address of principal executive offices including zip code)
(218) 722-2641
(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Name of Each Stock Exchange
Title of Each Class on Which Registered
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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, Inc. 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 January 29,
1999 was $1,483,868,013.
As of January 29, 1999 there were 36,184,158 shares of Minnesota Power, Inc.
Common Stock, without par value, outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Proxy Statement for the 1999 Annual Meeting of Shareholders are
incorporated by reference in Part III.
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TABLE OF CONTENTS
PART I PAGE
Item 1. Business 1
Electric Operations 1
Electric Sales 2
Purchased Power and Capacity Sales 4
Fuel 4
Regulatory Issues 5
Competition 6
Franchises 7
Environmental Matters 7
Water Services 10
Regulatory Issues 10
Competition 11
Franchises 11
Environmental Matters 11
Automotive Services 12
Competition 12
Environmental Matters 12
Investments 13
Environmental Matters 13
Executive Officers of the Registrant 14
Item 2. Properties 16
Item 3. Legal Proceedings 18
Item 4. Submission of Matters to a Vote of Security Holders 18
PART II
Item 5. Market for the Registrant's Common Equity and
Related Stockholder Matters 18
Item 6. Selected Financial Data 19
Item 7. Management's Discussion and Analysis of Financial
Condition and Results of Operations 21
Consolidated Overview 21
1998 Compared to 1997 23
1997 Compared to 1996 24
Outlook 25
Liquidity and Capital Resources 26
Capital Requirements 27
Market Risk 27
New Accounting Standards 28
Year 2000 28
Item 7A. Quantitative and Qualitative Disclosures about Market Risk 29
Item 8. Financial Statements and Supplementary Data 29
Item 9. Changes in and Disagreements with Accountants on Accounting
and Financial Disclosure 29
PART III
Item 10. Directors and Executive Officers of the Registrant 30
Item 11. Executive Compensation 30
Item 12. Security Ownership of Certain Beneficial Owners
and Management 30
Item 13. Certain Relationships and Related Transactions 30
PART IV
Item 14. Exhibits, Financial Statement Schedules and
Reports on Form 8-K 30
SIGNATURES 34
CONSOLIDATED FINANCIAL STATEMENTS 35
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DEFINITIONS
The following abbreviations or acronyms are used in the text.
Abbreviation or Acronym 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)
Common Stock Minnesota Power, Inc. Common Stock
Company Minnesota Power, Inc. 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.
kWh Kilowatthour(s)
Laskin Laskin Energy Center
Lehigh Lehigh Acquisition Corporation
MAPP Mid-Continent Area Power Pool
MBtu Million British thermal units
Minnesota Power Minnesota Power, Inc. and its Subsidiaries
Minnkota Power Minnkota Power Cooperative, Inc.
MP Telecom Minnesota Power Telecom, Inc.
MP Water Resources MP Water Resources Group, Inc.
MPCA Minnesota Pollution Control Agency
MPUC Minnesota Public Utilities Commission
MW Megawatt(s)
MWh Megawatthour(s)
NCUC North Carolina Utilities Commission
Note___ Note___ to the consolidated financial
statements in Item 14 of this Form 10-K
NPDES National Pollutant Discharge Elimination System
Palm Coast Palm Coast Holdings, Inc.
PAR PAR, Inc.
PCUC Palm Coast Utilities Corporation
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
VCS Vibration Correction Services, Inc.
WPPI Wisconsin Public Power, Inc.
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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;
- Year 2000 issues;
- delays or changes in costs of Year 2000 compliance;
- failure of major suppliers, customers or others with whom the Company
does business to resolve their own Year 2000 issues on a timely basis;
- 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.
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PART I
ITEM 1. BUSINESS
Minnesota Power, Inc., 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, coal
mining and telecommunications; (2) Water Services, which include water and
wastewater services; (3) Automotive Services, which include a network of vehicle
auctions, a finance company, an auto transport company and a vehicle remarketing
company; and (4) Investments, which include a securities portfolio, a 21% equity
investment in a financial guaranty reinsurance and specialty insurance company,
intermediate-term investments and real estate operations. Corporate Charges
represent general corporate expenses, including interest, not specifically
related to any one business segment. As of December 31, 1998 the Company and its
subsidiaries had approximately 7,000 employees, 2,000 of which were not full
time.
Since the inception of the 1996 corporate strategic plan, the Company has
pursued a course of expanding its existing business segments. Acquisitions have
been and will continue to be a primary means of expansion. In 1998 Electric
Operations opened an MPEX office in Minneapolis, at the site of a new
electricity futures and options market, and MP Telecom completed a 300-plus mile
fiber optic network that provides high volume telecommunication links to four
northern Minnesota communities. Also in 1998 Water Services acquired Vibration
Correction Services, Inc., a predictive and corrective maintenance company, and
Automotive Services acquired three auction facilities and added 30 new loan
production offices. In January 1999 Water Services acquired Palm Coast Utilities
Corporation.
Year Ended December 31 1998 1997 1996
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Consolidated Operating Revenue - Millions $1,039.7 $953.6 $846.9
Percentage of Consolidated Operating Revenue
Electric Operations
Retail
Industrial
Taconite Producers 16% 17% 20%
Paper and Pulp Mills 6 7 7
Pipelines and Other Industries 3 4 4
--- --- ---
Total Industrial 25 28 31
Residential 6 7 7
Commercial 6 6 7
Sales to Other Power Suppliers and Marketers 8 7 8
Other Revenue 9 9 9
--- --- ---
Total Electric Operations 54 57 62
Water Services 9 10 10
Automotive Services (a) 32 27 22
Investments 5 6 6
--- --- ---
100% 100% 100%
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(a) The Company purchased 80% of ADESA, including AFC and Great Rigs, on
July 1, 1995, another 3% in January 1996 and the remaining 17% in
August 1996.
For a detailed discussion of results of operations and trends, see Item 7
Management's Discussion and Analysis of Financial Condition and Results of
Operations. For business segment information, see Notes 1 and 2.
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,
1998 Minnesota Power was supplying retail electric service to 124,000
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 and marketers in the Midwest
and Canada. MPEX also contracts with its customers to provide hourly
energy scheduling and power trading services.
minnesota power, inc. 1
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SUPERIOR WATER, LIGHT AND POWER COMPANY sells electricity and natural gas,
and provides water service in northwestern Wisconsin. As of December 31,
1998 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
cost-plus coal supply agreements extending to 2027. Under an agreement
with Square Butte, Minnesota Power purchases approximately 71% 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 11.)
ELECTRIC OUTLET, INC. is a retail store and catalog merchandiser that
sells lifestyle-changing electric products. In 1998 the Company
established alliances with three other utilities to market products with
the Electric Outlet through either a catalog and/or a new Internet
CyberStore.
MINNESOTA POWER TELECOM, INC. provides high volume fiber optic and
microwave communications to businesses and communities across northern
Minnesota.
UPPER MINNESOTA PROPERTIES, INC. has invested in affordable housing
projects located in Electric Operations service territory. This is one of
a variety of economic development projects which the Company participates
in throughout the Electric Operations service territory by providing
resources and expertise.
ELECTRIC SALES
The two major industries in Minnesota Power's electric service territory are
taconite production, and paper and pulp mills. As deregulation of the electric
utility industry approaches, the Company believes the percentage of electric
revenue from sales to other power suppliers and marketers will continue to
increase. The percentage of consolidated revenue from taconite producers, and
paper and pulp mills is expected to decrease as other strategic initiatives add
to consolidated operating revenue. (See table on page 1 that presents percentage
of consolidated operating revenue.)
Approximately 80% of the ore consumed by integrated steel facilities in the
Great Lakes region originates 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 46 million tons in 1998 (47 million tons in 1997; 46 million tons
in 1996). Based on the Company's research of the taconite industry, Minnesota
taconite production for 1999 is anticipated to remain at or near the 1998 level.
While taconite production is expected to continue at annual levels of over 40
million tons, the long-term future of this cyclical industry is less certain.
The record level of steel imports into the United States is adversely affecting
the domestic steel industry. If imports continue at 1998 levels, lower demand
for steel produced in the United States is likely to have an adverse affect on
the taconite producers and the economy as a whole in northern Minnesota.
Representatives of the United States steel industry have asserted that the
imports are unfair and illegal, and have filed anti-dumping trade suits with the
U.S. Department of Commerce. The Company is unable to predict the eventual
impact of this issue on the Company's Electric Operations.
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 past 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
2 minnesota power, inc.
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retail electric rates. Minnesota Power's key account management process provides
customized energy management and electric service to large commercial and
industrial customers. The process allows continuing negotiations with these
customers to explore options to respond to their needs. (See Regulatory Issues
- - Electric Rates.)
Six of the seven taconite producers in Minnesota have collective bargaining
agreements with the United Steel Workers of America. These agreements expire in
August 1999. The Company is unable to predict whether or not any labor disputes
will arise in the course of negotiations and, if such disputes occur, the impact
any dispute would have on the Company's Electric Operations.
Minimum Revenue and Demand Under Contract
As of February 1, 1999
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Minimum Monthly
Annual Revenue Megawatts
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1999 $85.0 million 563
2000 $71.2 million 485
2001 $67.8 million 467
2002 $57.4 million 399
2003 $48.9 million 338
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Based on past experience and projected operating levels, the Company
believes revenue from Large Power Customers will be substantially in
excess of the minimum contract amounts.
<TABLE>
Contract Status for Minnesota Power Large Power Customers
As of February 1, 1999
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<CAPTION>
Earliest
Customer Location Ownership Termination Date
----------------- ----------------------- --------------------------- ------------------
<S> <C> <C> <C>
Eveleth Mines LLC Eveleth, MN 45% Rouge Steel Co. October 31, 2008
40% AK Steel Co.
15% Stelco Inc.
Hibbing Taconite Co. Hibbing, MN 70.3% Bethlehem Steel Corp. December 31, 2008
15% Cleveland-Cliffs Inc.
14.7% Stelco Inc.
Ispat Inland Mining Virginia, MN Ispat Inland Steel Company December 31, 2007
Company
USX Corporation 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 Potlatch Corp. December 31, 2002
Brainerd, MN
Lakehead Pipe Line Deer River, MN Lakehead Pipe Line May 31, 2001
Co. L.P. Floodwood, MN Partners, L.P.
Minnesota Pipeline Staples, MN 60% Koch Pipeline Co. L.P. September 30, 2002
Company Little Falls, MN 40% Marathon Ashland
Park Rapids, MN Petroleum LLC
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</TABLE>
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PURCHASED POWER AND CAPACITY SALES
The Company currently does not buy or sell power on the speculation that prices
will rise or fall. A purchase or sale is generally made to balance the supply or
demand, thereby capping the cost of power or fixing a margin. The Company's
contract provisions, operational flexibility, credit policy and procedures for
purchasing power to cap cost or fix margins are designed to minimize the
Company's risk and exposure in a market with volatile prices.
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 marketing power.
Status of Minnesota Power Purchased Power Contracts
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Entity Contract MW Contract Period
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Participation Power
Purchases (a)
-------------------
Square Butte (b) 322 May 29, 1998 to January 1, 2027
LTV Steel 210 May 1, 1995 through April 30, 2000
Silver Bay Power 78 November 1, 1995 through
October 31, 2000
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(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 to 2027 with Square Butte, Minnesota
Power is currently entitled to approximately 71% of the output of a
455-megawatt coal-fired generating unit located near Center, North
Dakota. (See Note 11.)
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 marketing power.
Status of Minnesota Power Capacity Sales Contracts
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Utility Contract MW Contract Period
------- ----------- ---------------
Participation Power
Sales (a)
-------------------
Interstate Power Company,
a subsidiary of Alliant
Energy Corporation 55 May 1 through October 31 of each
year from 1994 through 2000
35 November 1, 1998 through
April 30, 1999
50 November 1, 1999 through
April 30, 2000
Firm Power Sales (b)
--------------------
Wisconsin Power and Light
Company, a subsidiary of
Alliant Energy
Corporation 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
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(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.
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 1998 was
about 4.2 million tons. As of December 31, 1998 the Company had a coal inventory
of about 437,000 tons. The Company has three coal supply agreements in place
with Montana suppliers. Under these agreements the Company has the tonnage
flexibility to procure 70% to 100% of its total coal requirements. The Company
will obtain coal in 1999 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.
4 minnesota power, inc.
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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. One contract provides for coal deliveries through 2003 to Boswell.
The other contract provides for coal deliveries through 2002 to Laskin via a
Duluth Missabe & Iron Range Railway interchange.
Coal Delivered to Minnesota Power
Year Ended December 31 1998 1997 1996
--------------------------------------------------------------------------
Average Price Per Ton $20.37 $20.26 $19.30
Average Price Per MBtu $1.12 $1.11 $1.06
--------------------------------------------------------------------------
The Square Butte generating unit operated by Minnkota Power 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 1998 was approximately 72 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 an agreement, the Company is obligated to pay its
pro rata share of Square Butte's costs. These costs include the price of lignite
purchased under a cost-plus contract from BNI Coal. (See Item 2 Properties and
Note 11.) 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 36%, 4% and 4%, respectively,
of the Company's 1998 consolidated operating revenue.
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.
The demand charge component of the Company's large power rate schedules is
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 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 customer's 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
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(including fuel costs) to about 2% per year on a cumulative basis. In 1998 the
15 municipal customers purchased 642,960 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% per year on a cumulative basis. SWL&P
purchased 568,471 MWh from the Company in 1998.
The Company also has a contract through 2004 to supply electricity to Dahlberg
Light and Power Company (Dahlberg), a private utility. Dahlberg purchased 87,870
MWh from the Company in 1998.
The Company's hydroelectric facilities, which are located in Minnesota, are
licensed by the FERC. (See Environmental Matters - Water.)
On December 21, 1998 the Company filed a complaint with the FERC against
Northern States Power Company (NSP) claiming that (i) when NSP recently refused
to support an Independent System Operator (ISO) and regional transmission tariff
proposal advanced by members of the Mid-Continent Area Power Pool (MAPP), NSP
breached an agreement with Minnesota Power to work cooperatively for the purpose
of forming a regional ISO and (ii) a separate NSP transmission tariff is not
just and reasonable for further development of a competitive regional energy
market in the Midwest. Instead of the MAPP ISO, NSP favors spinning off its
transmission assets to its shareholders, to be owned and operated as an
independent transmission company (ITC) which would file its own tariffs and
would also lease and operate the transmission assets of Alliant Energy
Corporation, a Wisconsin based utility. Minnesota Power has asked the FERC to
require NSP to honor its agreement with Minnesota Power, to order NSP to join
the existing regional Midwest ISO and participate in a regional transmission
tariff. NSP's Answer (in which it denies Minnesota Power's allegations and
requests dismissal) and intervention motions by other entities were filed by
January 20, 1999. A single, integrated regional tariff coupled with regional
planning and operation of the transmission system would allow the Company and
others to phase into payment of a single tariff and would provide for regional
management of constraints on the bulk transmission system, thus broadening the
markets in which the Company could profitably operate. The Company is unable to
predict how or when the FERC will act on the complaint.
The MAPP ISO was voted down by MAPP membership. It would have served as an
independent entity to oversee the movement of bulk power over the regional
transmission line grid and to maintain fair access to and reliability of
electric service to users under a single regional tariff. MAPP is considering
its options which include remaining unchanged, making another effort to form an
ISO, or joining with another organization. (See Competition - Wholesale.)
MINNESOTA PUBLIC UTILITIES COMMISSION. The Company's retail rates are based on a
1994 MPUC retail rate order which allows for an 11.6% return on common equity
dedicated to utility plant.
Minnesota requires investor owned electric utilities to spend a minimum of 1.5%
of gross annual retail electric revenue on conservation improvement programs
(CIP) each year. The MPUC approved the Company's minimum spending requirement of
$5.5 million for 1998 ($5.1 million for each of 1997 and 1996). In 1998 the
Company spent $10.3 million on CIP ($5.8 million in 1997; $14.4 million in 1996)
and expects to spend a total of $5.6 million during 1999. The MPUC allows
utilities to accumulate, in a deferred account for future recovery, those CIP
expenditures in excess of amounts recovered through current rates. Through
billing adjustment and retail base rates approved by the MPUC, the Company
collected $15.2 million in 1998 ($13.7 million in 1997; $10.8 million in 1996)
for the recovery of current and deferred CIP expenditures, for carrying charges
on deferred expenditures, and for the lost margins associated with power saved
as a result of CIP programs. With respect to the lost margin portion of CIP
expenditure recovery, the MPUC has initiated a proceeding to analyze the
recommendation made by the Minnesota Department of Public Service to
discontinue the recovery of lost margins for CIP investments. If lost margin
recovery is discontinued the Company would realize an annual revenue reduction
of approximately $3.8 million per year. The MPUC intends to determine by May 1,
1999 whether recovery of lost margins will be discontinued. The Company is
unable to predict the outcome of this matter.
COMPETITION
The electric utility industry continues to become more competitive at both the
wholesale and retail levels, particularly in the wholesale markets. Retail
deregulation of the industry is being considered at both the federal and state
levels, and affects 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 competitive
pressures.
WHOLESALE. Minnesota Power's MPEX division conducts an active wholesale power
marketing business, including participation in power and energy markets within
MAPP and other power pools. Minnesota Power signed a three-year agreement,
effective January 1, 1998, whereby MPEX provides Manitoba Hydro with exclusive
hourly power trading and energy scheduling services in the United States.
Manitoba Hydro and Minnesota Power also signed a memorandum of understanding
that establishes an alliance whereby the two utilities market electric energy in
the Midwest, including but not limited to Wisconsin, Michigan and Illinois. The
memorandum strengthens this 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.
6 minnesota power, inc.
<PAGE>
MPEX is reviewing new strategic opportunities for its wholesale marketing
operations in light of the 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 federal
regulatory requirements.
Minnesota Power is a member of MAPP. MAPP recently proposed to form an ISO which
would have been responsible for planning and administering transactions on the
regional transmission system. Since the proposal failed to gain the requisite
vote of approval by MAPP members, MAPP has initiated a survey of its members to
determine the desired future direction of MAPP. Options may include a revised
ISO proposal, joining another regional transmission organization, or
continuation of its role as a reserve sharing pool, regional transmission group,
power and energy market, and providing coordination between member systems with
the new security center. Any member who elects to withdraw from MAPP must first
provide a 3-year notice of their intent to do so, under the MAPP Restated
Agreement. (See Federal Energy Regulatory Commission and 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 working group issued a Wholesale Competition Report in
October 1996 and a Retail Competition Report in November 1997. The MPUC has
begun identifying the steps necessary to successfully implement restructuring at
such time as any state restructuring legislation may be enacted.
LEGISLATION. During 1999 Congress is expected to continue debating 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 1999, 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 supplier to large industrial customers.
Legislative debate continues in both Minnesota and Wisconsin regarding the
future of the electric industry. 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
will likely be introduced to allow customers to choose their electric energy
supplier but the Company does not anticipate that any such legislation will be
passed in 1999. Minnesota's newly elected Governor has not yet made his position
known on this issue and the legislative leadership has not indicated that
electric industry restructuring will become a priority issue. 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 on investor-owned electric utilities. The Wisconsin legislature is also
likely to pursue electric utility industry restructuring, but reliability issues
are expected to receive more legislative attention in 1999.
FRANCHISES
Minnesota Power holds franchises to construct and maintain an electric
distribution and transmission system in 83 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
minnesota power, inc. 7
<PAGE>
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 all of Minnesota Power's generating
facilities. Some moderate reductions in emissions may be necessary for Square
Butte to meet the Phase II sulfur dioxide emission requirements. Square Butte
anticipates meeting its sulfur dioxide requirements through increased use of
existing scrubbers or by purchasing additional allowances. The estimated cost,
at current prices, to meet sulfur dioxide requirements at Square Butte is $0.8
million to $1.1 million 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 approximately $2.0 million on advanced low
emission burner technology and associated control equipment to operate the
Boswell and Laskin facilities at or below the compliance emission limits.
Nitrogen oxide limitations at Square Butte will be met by combustion tuning. 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
of costs.
KYOTO PROTOCOL. On December 11, 1997 the United Nations Framework Convention on
Climate Change (FCCC), Third Conference of Parties (COP) 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% reduction below 1990 emission levels during the period 2008 through
2012. The Protocol must be ratified by the United States Senate; however, the
Protocol does not currently satisfy the guidance provided in a 1997 Senate
resolution. The fourth meeting of the COP signatory to the FCCC was held in
Buenos Aires in November 1998, at which time a schedule targeting 2000 for
completion of key treaty detail negotiations was established. 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 NPDES permits to 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.
8 minnesota power, inc.
<PAGE>
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 (c)
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 first
quarter of 1999. 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 was submitted to the MPCA on
March 30, 1998. The permit is expected to be issued in the first
quarter of 1999. The new permit is expected to contain a requirement
for construction of a new ash disposal pond by December 30, 2000. The
Company expects to spend approximately $3.3 million in 1999 and
another $3.3 million in 2000 to construct the Laskin ash disposal
pond.
(c) A renewal application for this permit was submitted to the MPCA on
December 16, 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
Blanchard 18.0 December 1, 1987 August 24, 2003 (a)
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
Pillager 1.5 April 1, 1998 April 1, 2028
St. Louis River 87.6 July 1, 1995 June 30, 2035 (c)
--------------------------------------------------------------------------
(a) The Company filed notice of its intent to file an application for a
new license with the FERC in August 1998. In November 1998 the FERC
approved the Company's September 1998 request to use alternative
procedures (i.e., collaborative process) in filing the license
application.
(b) The Company filed notice of its intent to file an application for a
new license with the FERC in October 1998. In May 1998 the FERC
approved the Company's March 1998 request to use alternative
procedures (i.e., collaborative process) in filing the license
application.
(c) 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 of Lake Superior Chippewa (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. The court has
consolidated the three petitions for review and suspended the briefing
schedule 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 January 1999, 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.
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 $500,000 was spent through December 31, 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
minnesota power, inc. 9
<PAGE>
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, 1998 Florida Water served
121,000 water customers and 54,000 wastewater treatment customers. In
January 1999 Florida Water purchased Palm Coast Utility Corporation (PCUC)
from a subsidiary of ITT Industries, Inc. (ITT). PCUC provides service to
approximately 15,000 water and 14,000 wastewater customers in Flagler
County, Florida. Rates for PCUC are regulated by Flagler County. (See
Note 4.)
Heater provides water and wastewater treatment services in North Carolina.
As of December 31, 1998 Heater served 28,000 water customers and 2,000
wastewater treatment customers. In 1998 the Company completed its
strategic exit from South Carolina with the sale of Upstate Heater
Utilities.
NON-REGULATED SUBSIDIARIES. AMERICAS' WATER SERVICES CORPORATION was
incorporated in 1997. Headquartered near Chicago, Illinois, Americas'
Water offers contract management, operations and maintenance services for
water and wastewater treatment facilities to governments and industries.
INSTRUMENTATION SERVICES, INC. and VIBRATION CORRECTION SERVICES, INC.
provide 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. VCS was acquired in July 1998.
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.
REGULATORY ISSUES
FLORIDA PUBLIC SERVICE COMMISSION. 1995 RATE CASE. Florida Water requested an
$18.1 million annual 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. The new rates
were implemented in September 1996. In November 1996 Florida Water filed with
the Florida First District Court of Appeals (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 the course of the appeals
process, the FPSC reconsidered an issue in its initial decision and, in June
1997, allowed Florida Water to resume collecting approximately $1 million, on an
annual basis, in new customer fees. On June 10, 1998 the Court of Appeals ruled
in Florida Water's favor on all material issues appealed by Florida Water and
remanded the matter back to the FPSC for action consistent with the Court's
order. The Court of Appeals also overturned its decision in Florida Water's 1991
Rate Case which had required a "functional relationship" between service areas
as a precondition to implementation of uniform rates. On December 15, 1998 the
FPSC granted Florida Water an additional annual revenue increase of
approximately $1.2 million related to several of the issues reversed by the
Court of Appeals, and permitted collection of approximately $2.4 million in
surcharges to reimburse Florida Water for revenue (plus interest) wrongfully
denied in the FPSC's October 1996 order. Florida Water began collecting the new
rates in January 1999 and expects to begin collecting the surcharges during the
first quarter of 1999. The FPSC reopened the record on two remaining issues on
remand from the Court of Appeals regarding the amount of investment in utility
facilities recoverable in rates from current customers. A decision in the
Company's favor would result in additional revenue and surcharges. A hearing
with respect to the two remaining issues has not been scheduled by the FPSC. The
Company is unable to predict the timing or outcome of these proceedings.
1991 RATE CASE REFUNDS. In 1995 the 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 did not require refunds. Florida
Water's potential refund liability at that time was about $12.5 million, which
included interest, to customers who paid more under uniform rates.
10 minnesota power, inc.
<PAGE>
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 (see 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 prospectively 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, arguing that they are entitled to a refund because the
FPSC had no authority to order uniform rates. The Company has appealed the $2.5
million refund order. Initial briefs were filed by all parties on May 22, 1998.
Upon issuance of the June 10, 1998 opinion of the Court of Appeals with respect
to Florida Water's 1995 Rate Case (see 1995 Rate Case) in which the court
reversed its previous ruling that the FPSC was without authority to order
uniform rates, customer groups supporting the FPSC's January 1998 order filed a
motion with the Court of Appeals seeking dismissal of the appeal by customer
groups seeking refunds. Customers seeking refunds filed amended briefs on
September 14, 1998. No provision for refund has been recorded. The Company is
unable to predict the timing or outcome of the appeals process.
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 22 counties
regulated by the FPSC and holds franchises in four 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 NCUC 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.
minnesota power, inc. 11
<PAGE>
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; Great Rigs, an auto transport company; and PAR, a
vehicle remarketing company. The Company acquired 80% of ADESA, including AFC
and Great Rigs, on July 1, 1995. The Company increased its ownership interest to
100% in 1996. Automotive Services plans to grow through increased sales at
existing businesses, selective acquisitions and expanding services.
ADESA is one of the three largest vehicle auction networks in the United
States. Headquartered in Indianapolis, Indiana, ADESA owns and operates 28
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 1998 ADESA acquired three new auction facilities. (See Note 4.)
AUTOMOTIVE FINANCE CORPORATION provides inventory financing for wholesale
and retail automobile dealers who purchase vehicles from ADESA auctions,
independent auctions, other auction chains and other outside sources. AFC
is headquartered in Indianapolis, Indiana, and has 84 loan production
offices which are located at most ADESA auctions, as well as at or near
other auto auctions. These offices provide qualified dealers credit to
purchase vehicles at any of the 400 plus auctions approved by AFC. During
1998 AFC added 30 loan production offices.
GREAT RIGS is one of the nation's largest used automobile transport
carriers with 145 automotive carriers. Headquartered in Moody, Alabama,
Great Rigs offers customers pick up and delivery through 13 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 Ford Motor
Credit, GE Capital, General Motors Acceptance Corp. and Nissan.
PAR provides customized remarketing services to various businesses with
fleet operations. In 1998 PAR began expanding into the "lease-end
services" market. PAR assists leasing agents and lenders in transporting,
remarketing or otherwise liquidating off-lease vehicles by choosing the
most cost-effective end-of-lease option.
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 through its subsidiaries,
including dealer inventory financing, reconditioning services which prepare
vehicles for auction, transporting vehicles and the prompt processing of sales
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 the largest provider of dealer floorplan financing to independent
automobile dealers in North America. AFC's competition includes other specialty
lenders, banks and other financial institutions. AFC has distinguished itself
from its competitors by convenience of payment, quality of service and scope of
services offered. During the fourth quarter of 1998, AFC unveiled its Retail
Alliance Program (RAP). The RAP is an alliance between AFC and retail lenders.
This program will facilitate the retail financing of vehicles sold by dealers
who have a relationship with AFC. Dealers participating in the program will have
the opportunity to buy vehicles, transport them to their location, sell them to
retail customers, finance them through either prime or sub-prime lenders and
provide warranty protection without any cash investment in the vehicles.
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.
12 minnesota power, inc.
<PAGE>
INVESTMENTS
The Investments segment is comprised of an actively traded securities portfolio,
an investment in a specialty insurance and reinsurance company,
intermediate-term investments and real estate operations.
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. Proceeds from the securities
portfolio are available for investment in existing businesses, to fund
strategic initiatives and for other corporate purposes. The Company's
objective is to maintain corporate liquidity between 7% and 10% of total
assets ($160 million to $230 million). The Company's investment in the
securities portfolio at December 31, 1998 was $227 million ($184 million
at December 31, 1997).
REINSURANCE. Minnesota Power owns 21% of Capital Re, a financial guaranty
reinsurance and specialty insurance company, and is Capital Re's largest
shareholder. Capital Re's product lines currently include financial
guaranty, mortgage, title, financial, credit and specialty reinsurance.
Capital Re trades on the New York Stock Exchange under the symbol KRE.
Minnesota Power's equity investment was $133 million at December 31, 1998
($119 million at December 31, 1997). The Company accounts for its
investment in Capital Re under the equity method. (See Note 9.) The
Company intends to maintain its Capital Re holdings as a core component of
the Company's Investments segment.
INTERMEDIATE-TERM INVESTMENTS. Since 1985 the Company has invested about
$11 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 accounts for
the majority of these funds under the equity method. The Company is
committed to invest an additional $16 million over the next nine 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, Toronto
and Winnipeg. The Company holds a 10% note due 2002 for the principal
amount of the loan. The Company also holds detachable warrants that can be
exercised for approximately 25% 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. Through a subsidiary, the Company owns 80% of
Lehigh, a Florida company which through its subsidiaries owns property in
three different locations: (1) Lehigh Acres adjacent to Fort Myers,
Florida; (2) Sugarmill Woods in Citrus County, Florida; and (3) Palm Coast
located between St. Augustine and Daytona Beach, Florida. (See Item 2
Properties.) The real estate strategy is to continue to acquire large
community properties at low cost, add value and sell them at going market
prices.
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.
minnesota power, inc. 13
<PAGE>
EXECUTIVE OFFICERS OF THE REGISTRANT
Initial
Executive Officers Effective Date
- ------------------------------------------------------ --------------
John Cirello, Age 55
Executive Vice President and President and
Chief Executive Officer - MP Water Resources
Group, Inc. July 24, 1995
Donnie R. Crandell, Age 55
Executive Vice President and President - MP Real
Estate Holdings, Inc. January 15, 1999
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 54
Executive Vice President and President - MP Electric July 26, 1995
Executive Vice President and Chief Operating Officer March 1, 1993
Brenda J. Flayton, Age 43
Vice President - Human Resources July 22, 1998
John E. Fuller, Age 55
Executive Vice President and President and
Chief Executive Officer - AFC January 15, 1999
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 50
Vice President - Corporate Development February 10, 1997
David G. Gartzke, Age 55
Senior Vice President - Finance and
Chief Financial Officer December 1, 1994
Vice President - Finance and Chief
Financial Officer March 1, 1993
James P. Hallett, Age 45
Executive Vice President and President and
Chief Executive Officer - ADESA April 23, 1997
President and Chief Executive Officer - ADESA August 21, 1996
President - ADESA Canada, Inc. May 26, 1994
Philip R. Halverson, Age 50
Vice President, General Counsel and Secretary January 1, 1996
General Counsel and Corporate Secretary March 1, 1993
David P. Jeronimus, Age 56
Vice President - Environmental Services February 1, 1999
James A. Roberts, Age 48
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 43
Controller March 1, 1993
James K. Vizanko, Age 45
Treasurer March 1, 1993
Claudia Scott Welty, Age 46
Vice President - Information Technology February 1, 1999
Vice President - Support Services July 1, 1995
14 minnesota power, inc.
<PAGE>
All of the executive officers above, except Mr. Cirello, 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. Laurence Fuller was previously senior vice president, new business
development and strategic planning, for Diners Club International,
a subsidiary of Citicorp, Inc.
Mr. Hallett was previously president of Ottawa Auto Dealers Exchange,
a Canadian vehicle auction business purchased by ADESA.
Mr. Russell was previously group vice president of J.M. Huber
Corporation, a $1.5 billion diversified manufacturing and
natural resources company.
In the five years prior to election to the positions shown above, Ms. Flayton,
Mr. Jeronimus, Mr. Roberts and Ms. Welty held other positions with the Company.
Ms. Flayton was director of human resources and manager of
human resources.
Mr. Jeronimus was director of environmental resources.
Mr. Roberts was director of corporate relations.
Ms. Welty was director of technical support services and co-leader
of organizational development.
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 11, 1999.
minnesota power, inc. 15
<PAGE>
ITEM 2. PROPERTIES
ELECTRIC OPERATIONS. The Company had an annual net peak load of 1,385 MW on
January 12, 1998. 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 5,693,472 46.6%
-----
Laskin Energy Center
Hoyt Lakes, MN 1 1953 55
2 1953 55
-----
110 571,673 4.7
-----
Purchased Steam
M.L. Hibbard
Duluth, MN 3 & 4 1949, 1951 55 17,339 0.1
----- ---------- -----
Total Steam 1,081 6,282,484 51.4
----- ---------- -----
Hydro
Group consisting of
ten stations in MN Various 118 569,977 4.7
----- ---------- -----
Purchased Power
Square Butte burns
lignite in Center, ND 322 2,105,231 17.2
All other - net - 3,270,160 26.7
----- ---------- -----
Total Purchased Power 322 5,375,391 43.9
----- ---------- -----
For the Year Ended December 31, 1998 1,521 12,227,852 100.0%
- --------------------------------------------------------------------------------
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, 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.
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 2008, respectively. All other property
and equipment is owned by BNI Coal.
The Company is a member of the MAPP. MAPP enhances regional electric service
reliability, provides the opportunity for members to enter into various economic
wholesale power transactions and coordinates the planning and operation of
existing as well as the installation of new generation and transmission
facilities. MAPP membership consists of various electric power
16 minnesota power, inc.
<PAGE>
suppliers located in North Dakota, South Dakota, eastern Montana, Nebraska,
Iowa, Minnesota, Wisconsin, upper Michigan, Kansas, Missouri, 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 approximately 200,000 customers and
maintaining 151 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 over 16 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 167 interconnected and stand alone
systems and 431 wells serving 28,000 customers. Heater also has 9 wastewater
treatment plants, ranging in size from 35,000 gallons per day (gpd) to 250,000
gpd, and 12 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.
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.
<TABLE>
<CAPTION>
Year No.
Operations Auction
ADESA Auctions Location Commenced Lanes
- ------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
United States
ADESA Birmingham Moody, Alabama 1987 10
ADESA Sacramento 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 Ark-La-Tex Shreveport, Louisiana 1979 5
ADESA Boston <F1> Framingham, Massachusetts 1995 11
ADESA Lansing Dimondale, Michigan 1976 6
ADESA St. Louis Barnhart, Missouri 1987 3
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 8
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 Halifax, Nova Scotia 1993 3
ADESA Ottawa Vars, Ontario 1990 5
ADESA Montreal St. Eustache, Quebec 1974 8
- ------------------------------------------------------------------------------------------------------------------
<FN>
<F1> Leased auction facilities. (See Note 13.)
<F2> ADESA owns 51% of this auction business.
<F3> ADESA owns 80% of this auction business.
</FN>
</TABLE>
minnesota power, inc. 17
<PAGE>
AFC has loan production offices in 84 locations across North America. Many
offices are within auction facilities operated by ADESA, independent auctions
and other auction chains.
Great Rigs has a fleet of 145 automobile carriers. Seven of these automotive
carriers are owned by the Company, while the remaining 138 are leased under
operating leases.
INVESTMENTS. Through a subsidiary, the Company owns 80% of Lehigh, a Florida
company which through its subsidiaries owns property in three different
locations: (1) Lehigh Acres with 1,600 acres of land and approximately 500 home
sites adjacent to Fort Myers, Florida; (2) Sugarmill Woods with 850 home sites
in Citrus County, Florida; and (3) Palm Coast with 2,400 home sites and 11,200
acres of residential, commercial and industrial land at Palm Coast, Florida.
Palm Coast is a planned community between St. Augustine and Daytona Beach.
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.
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 1998.
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. On January 18, 1999 the Company announced a 5% dividend increase and a
two-for-one stock split. A quarterly dividend of $0.535 per share on the Common
Stock will be paid on March 1, 1999 to the holders of record on February 16,
1999. Assuming timely regulatory approval, the effective date of the stock split
will be March 2, 1999 to shareholders of record at the close of business
February 16, 1999. 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 on a pre-split basis:
Dividends
Price Range Paid Per Share
------------------- ----------------------
Quarter High Low Quarterly Annual
- --------------------------------------------------------------------------------
1998 - First $43 7/16 $39 1/8 $0.51
- Second 42 15/16 38 1/16 0.51
- Third 45 39 1/16 0.51
- Fourth 46 1/4 40 3/4 0.51 $2.04
1997 - First $29 $27 1/4 $0.51
- Second 30 5/8 27 0.51
- Third 36 5/16 30 1/4 0.51
- Fourth 44 35 3/16 0.51 $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 1998 the
Company paid out 76% of its per share earnings in dividends. The Company's goal
is to maintain a dividend payout of 75% to 80% 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, 1998 no retained earnings were
restricted as a result of these provisions. At January 29, 1999 there were
approximately 38,000 Common Stock shareholders of record.
18 minnesota power, inc.
<PAGE>
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% of ADESA, including AFC and
Great Rigs, on July 1, 1995, another 3% in January 1996 and the remaining 17% in
August 1996; and (2) the Company's sale of its interest in the paper and pulp
business to Consolidated Papers, Inc. on June 30, 1995.
<TABLE>
<CAPTION>
Balance Sheet 1998 1997 1996 1995 1994 1993
- --------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
Millions
Assets
Electric Operations $ 771.5 $ 783.5 $ 796.0 $ 800.5 $ 789.8 $ 780.2
Water Services 329.4 322.2 323.9 323.2 295.4 303.7
Automotive Services 186.2 167.1 167.3 123.6 - -
Investments 263.5 252.9 236.5 201.4 355.3 317.7
-------- -------- -------- -------- -------- --------
Total Plant and Other Assets 1,550.6 1,525.7 1,523.7 1,448.7 1,440.5 1,401.6
Current Assets 487.5 385.3 334.8 251.9 266.1 272.0
Other Assets 279.0 277.9 290.2 247.0 101.2 86.9
-------- -------- -------- -------- -------- --------
$2,317.1 $2,188.9 $2,148.7 $1,947.6 $1,807.8 $1,760.5
- --------------------------------------------------------------------------------------------------------------------------
Capitalization and Liabilities
Common Equity $ 785.6 $ 650.0 $ 610.8 $ 584.1 $ 561.7 $ 562.6
Preferred Stock 11.5 11.5 11.5 28.5 28.5 28.5
Redeemable Preferred Stock 20.0 20.0 20.0 20.0 20.0 20.0
Mandatorily Redeemable Preferred
Securities of MP&L Capital I 75.0 75.0 75.0 - - -
Long-Term Debt 672.2 685.4 694.4 639.5 601.3 611.2
-------- -------- -------- -------- -------- --------
1,564.3 1,441.9 1,411.7 1,272.1 1,211.5 1,222.3
Current Liabilities 346.0 342.6 339.7 256.8 182.8 130.3
Other Liabilities 406.8 404.4 397.3 418.7 413.5 407.9
-------- -------- -------- -------- -------- --------
$2,317.1 $2,188.9 $2,148.7 $1,947.6 $1,807.8 $1,760.5
- --------------------------------------------------------------------------------------------------------------------------
Income Statement 1998 1997 1996 1995 1994 1993
- --------------------------------------------------------------------------------------------------------------------------
Millions
Operating Revenue
Electric Operations $ 559.9 $541.9 $529.2 $503.5 $458.4 $457.7
Water Services 95.6 95.5 85.2 66.1 87.5 65.5
Automotive Services 328.4 255.5 183.9 61.6 - -
Investments 55.8 60.7 48.6 41.7 36.3 59.3
-------- ------ ------ ------ ------ ------
1,039.7 953.6 846.9 672.9 582.2 582.5
Expenses
Fuel and Purchased Power 205.7 194.1 190.9 177.0 157.7 170.3
Operations 635.4 579.9 512.2 389.1 300.6 283.8
Interest Expense 64.9 64.2 62.1 48.0 46.7 41.5
-------- ------ ------ ------ ------ ------
906.0 838.2 765.2 614.1 505.0 495.6
Income from Equity Investments 14.8 14.8 11.8 4.2 2.9 5.8
-------- ------ ------ ------ ------ ------
Operating Income 148.5 130.2 93.5 63.0 80.1 92.7
Distributions on Redeemable
Preferred Securities of Subsidiary 6.0 6.0 4.7 - - -
Income Tax Expense 54.0 46.6 19.6 1.1 20.6 28.3
-------- ------ ------ ------ ------ ------
Income from Continuing Operations 88.5 77.6 69.2 61.9 59.5 64.4
Income (Loss) from
Discontinued Operations - - - 2.8 1.8 (1.8)
-------- ------ ------ ------ ------ ------
Net Income 88.5 77.6 69.2 64.7 <F1> 61.3 <F2> 62.6
Preferred Dividends 2.0 2.0 2.4 3.2 3.2 3.3
-------- ------ ------ ------ ------ ------
Earnings Available for Common Stock 86.5 75.6 66.8 61.5 58.1 59.3
Common Stock Dividends 65.0 62.5 59.6 57.9 56.7 53.3
-------- ------ ------ ------ ------ ------
Retained in the Business $ 21.5 $ 13.1 $ 7.2 $ 3.6 $ 1.4 $ 6.0
- --------------------------------------------------------------------------------------------------------------------------
<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
an equipment manufacturing business.
<F2> Included $11.8 million gain from the sale of certain water plant assets,
$3.6 million gain 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 an equipment manufacturing business.
</FN>
</TABLE>
minnesota power, inc. 19
<PAGE>
<TABLE>
<CAPTION>
1998 1997 1996 1995 1994 1993
- ---------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
Shares Outstanding - Millions
Year-End 36.2 33.6 32.8 31.5 31.2 31.2
Average <F1> 32.0 30.6 29.3 28.5 28.2 27.0
Basic Earnings Per Share
Continuing Operations $2.70 $2.47 $2.28 $2.06 $1.99 $2.27
Discontinued Operations - - - .10 .07 (.07)
----- ----- ----- ----- ----- -----
$2.70 $2.47 $2.28 $2.16 $2.06 $2.20
Diluted Earnings Per Share $2.69 $2.47 $2.28 $2.16 $2.06 $2.20
Return on Average Common Equity 12.4% 12.1% 11.3% 10.7% 10.5% 11.5%
Common Equity Ratio 49.9% 44.9% 43.1% 45.6% 45.9% 45.8%
Dividends Paid Per Share $2.04 $2.04 $2.04 $2.04 $2.02 $1.98
Dividend Payout 76% 83% 89% 94% 98% 90%
Book Value Per Share at Year-End $21.72 $19.37 $18.65 $18.56 $17.98 $18.06
Market Price Per Share
High 46 1/4 44 29 3/4 29 1/4 33 36 1/2
Low 38 1/16 27 26 24 1/4 24 3/4 30
Close 44 43 9/16 27 1/2 28 3/8 25 1/4 32 3/4
Market/Book at Year-End 2.03 2.25 1.48 1.53 1.40 1.81
Price Earnings Ratio at Year-End 16.3 17.6 12.1 13.1 12.3 14.9
Dividend Yield at Year-End 4.6% 4.7% 7.4% 7.2% 8.0% 6.0%
Employees 7,003 6,817 6,537 5,649 2,552 2,772
Net Income
Electric Operations $47.4 $43.1 $39.4 $41.0 $40.6 $42.1
Water Services 7.5 8.2 5.4 (1.0) 13.7 1.8
Automotive Services 25.5 14.0 3.7 - - -
Investments 29.6 32.1 38.1 41.3 23.4 32.4
Corporate Charges (21.5) (19.8) (17.4) (19.4) (18.2) (11.9)
----- ----- ----- ----- ----- -----
88.5 77.6 69.2 61.9 59.5 64.4
Discontinued Operations - - - 2.8 1.8 (1.8)
----- ----- ----- ----- ----- -----
$88.5 $77.6 $69.2 $64.7 $61.3 $62.6
Customers - Thousands
Electric 138.1 135.8 135.1 135.8 132.8 133.4
Water and Wastewater 205.1 201.0 197.2 198.4 176.0 185.0
Electric Sales - Millions of MWh 12.0 12.4 13.2 11.5 10.2 9.8
Power Supply - Millions of MWh
Steam Generation 6.3 6.1 6.4 6.0 5.5 5.7
Hydro Generation 0.6 0.6 0.7 0.7 0.7 0.7
Long-Term Purchase - Square Butte 2.1 2.3 2.4 1.9 2.3 2.1
Purchased Power 3.2 3.8 4.4 3.6 2.1 1.9
---- ---- ---- ---- ---- ----
12.2 12.8 13.9 12.2 10.6 10.4
Coal Sold - Thousands of Tons 4.2 4.2 4.5 4.0 4.4 4.2
Water Sold - Billions of Gallons 18.1 16.5 16.0 14.7 14.8 16.1
Vehicles Consigned - Millions 1.5 1.4 1.1 0.5 - -
Capital Expenditures - Millions
Electric Operations $36.1 $34.6 $37.5 $39.4 $50.0 $58.2
Water Services 21.8 22.2 22.2 32.7 27.2 19.1
Automotive Services 22.0 11.2 41.7 42.7 - -
Investments 0.1 0.2 0.1 - 0.6 -
Corporate 0.8 4.0 - - - -
Discontinued Operations - - - 0.7 3.2 43.4
----- ----- ------ ------ ----- ------
$80.8 $72.2 $101.5 $115.5 $81.0 $120.7
- --------------------------------------------------------------------------------------------------------------------------
<FN>
<F1> Excludes unallocated ESOP shares.
</FN>
</TABLE>
20 minnesota power, inc.
<PAGE>
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
CONSOLIDATED OVERVIEW
Improved operating results in 1998 contributed to the 14% increase in net income
and a 9% increase in basic earnings per share. Basic earnings per share of
Common Stock was $2.70 in 1998 ($2.47 in 1997; $2.28 in 1996). Operating revenue
exceeded $1 billion in 1998, setting a new milestone for the Company. Financial
results for all of the Company's business segments reflected ongoing operational
improvements and the successful implementation of the Company's strategic plan.
As in 1997 the most significant growth in 1998 came from Automotive Services
where more auction and financing activity, and business expansion projects
increased net income.
Simultaneous with releasing 1998 financial results in January 1999, the
Company's Board of Directors approved a 5% dividend increase and a two-for-one
stock split on the Common Stock. A quarterly dividend of $0.535 per share will
be paid on March 1, 1999 to the holders of record on February 16, 1999. Assuming
timely regulatory approval, the effective date of the stock split will be March
2, 1999 to shareholders of record at the close of business February 16, 1999.
All share and earnings per share information is presented on a pre-split basis.
The Company measures performance of its operations through careful budgeting and
monitoring of contributions by business segment to consolidated net income.
Corporate Charges represent general corporate expenses, including interest, not
specifically related to any one business segment.
1998 1997 1996
- --------------------------------------------------------------------------------
Millions
Operating Revenue
Electric Operations $ 559.9 $541.9 $529.2
Water Services 95.6 95.5 85.2
Automotive Services 328.4 255.5 183.9
Investments 56.1 60.9 49.9
Corporate Charges (0.3) (0.2) (1.3)
-------- ------ ------
$1,039.7 $953.6 $846.9
-------- ------ ------
Operating Income
Electric Operations $ 79.3 $ 71.7 $63.6
Water Services 12.5 12.7 8.1
Automotive Services (a) 46.9 28.4 7.7
Investments 48.4 50.8 40.5
Corporate Charges (38.6) (33.4) (26.4)
------ ------ -----
$148.5 $130.2 $93.5
------ ------ -----
Net Income
Electric Operations $47.4 $43.1 $39.4
Water Services 7.5 8.2 5.4
Automotive Services (a) 25.5 14.0 3.7
Investments 29.6 32.1 38.1
Corporate Charges (21.5) (19.8) (17.4)
------ ----- -----
$88.5 $77.6 $69.2
- --------------------------------------------------------------------------------
Basic Earnings Per Share of
Common Stock $2.70 $2.47 $2.28
Return on Common Equity 12.4% 12.1% 11.3%
- --------------------------------------------------------------------------------
(a) The Company purchased 80% of ADESA, including AFC and Great Rigs, on
July 1, 1995, another 3% in January 1996 and the remaining 17% in
August 1996.
The following summarizes significant events which impacted earnings for each of
the Company's business segments for the past three years.
ELECTRIC OPERATIONS contributed net income of $47.4 million in 1998 ($43.1
million in 1997; $39.4 million in 1996). Since the establishment of MPEX in
1996, the Company has reported strong sales to other power suppliers and
marketers. Higher profit margins on these sales improved income from Electric
Operations, while unusually mild weather negatively impacted net income in 1998.
In 1997 Electric Operations reflected continued strong demand for electricity
from industrial customers and higher profit margins on sales to other power
suppliers and marketers. Net income in 1997 also included the sale of property
along the St. Louis River to the State of Minnesota to ensure the preservation
of wilderness lands and the sale of rights to microwave frequencies in
accordance with a federal mandate. Gains from these two sales were offset by
start-up costs associated with strategic initiatives and payment to management
of incentive compensation awards related to total shareholder return
performance.
minnesota power, inc. 21
<PAGE>
Total kWh sales were 12.0 billion in 1998 (12.4 billion in 1997; 13.2 billion in
1996, the record high). Kilowatthour sales to other power suppliers and
marketers were lower in 1998 due to milder weather during the winter months and
fewer days of extreme hot weather during the summer months in the Company's
geographic region. In addition, lower precipitation levels in 1998 reduced the
amount of hydro power available from other power suppliers for resale. Retail
sales were 4% lower in 1998 because of the mild winter weather in Minnesota and
northern Wisconsin, reduced demand for paper and crude oil, and some operating
problems experienced by taconite producers in northern Minnesota. In 1997 less
power was available for sale by MPEX because of reduction in transmission
capability damaged by severe spring storms in the Midwest, various generating
unit outages at Company and other plants in the Midwest, and less hydro
generation in Canada.
WATER SERVICES contributed net income of $7.5 million in 1998 ($8.2 million in
1997; $5.4 million in 1996). Financial performance for 1998 reflected higher
rates, customer growth, increased consumption and continued operating
efficiencies. A December 1998 ruling by the FPSC granted Florida Water an
additional annual revenue increase of approximately $1.2 million related to
several issues Florida Water appealed in its 1995 rate case. The ruling also
permits collection of approximately $2.4 million in surcharges to reimburse
Florida Water for revenue (plus interest) wrongfully denied by the FPSC. (See
Item 1. Business - Water Services - Regulatory Issues.) In 1997 Water Services
included a gain from the sale of certain water and wastewater assets to Orange
County, Florida. Financial results for 1997 also reflected a full year of higher
rates allowed by the FPSC in its initial decision in the 1995 Rate Case,
improved operating efficiencies, one-time charges and start-up costs associated
with non-regulated initiatives. In 1996 Water Services included gains from the
strategic sale of two water systems in South Carolina.
AUTOMOTIVE SERVICES contributed net income of $25.5 million in 1998 ($14.0
million in 1997; $3.7 million in 1996). Since 1996 the significant increase in
net income was driven by improved operating efficiencies, the acquisition of
additional auction facilities, higher auction volume and fees, and the rapid
expansion of AFC, the floorplan financing business. In 1998 ADESA added three
new auction facilities (two in 1997; eight in 1996) and received on consignment
1.5 million vehicles (1.4 million in 1997; 1.1 million in 1996). Consigned
vehicles are vehicles offered for sale at ADESA auctions. AFC added 30 new loan
production offices in 1998 (25 in 1997; 13 in 1996). The growth of AFC's
dealer/customer base to 11,500 in 1998 (10,000 in 1997; 4,000 in 1996) has
enabled AFC to finance approximately 500,000 vehicles in 1998 (300,000 in 1997;
140,000 in 1996). In 1998 AFC's expansion was largely attributable to an
agreement with ADT Automotive, Inc. (ADT) which allows AFC to provide floorplan
financing services at 26 ADT auctions. A more conservative allowance for
uncollectible accounts offset a gain from the sale of excess land in 1997.
INVESTMENTS contributed net income of $29.6 million in 1998 ($32.1 million in
1997; $38.1 million in 1996). Financial performance for 1998 reflected dividend
income received from a venture capital investment. The Company's securities
portfolio reported a lower after-tax return due to under performance of certain
investments. Together, the Company's securities portfolio and its equity
investment in Capital Re earned an annualized after-tax return of 6.6% in 1998
(8.6% in 1997; 8.8% in 1996). The Company's investment in the securities
portfolio at December 31, 1998 was approximately $227 million ($184 million at
December 31, 1997). The market value of the Company's $133 million equity
investment in Capital Re was $131 million at December 31, 1998 ($203 million at
December 31, 1997) based on a Capital Re share price of $20 1/16 ($31 1/32
at December 31, 1997).
The market value of the Company's investment in Capital Re dropped significantly
in the second half of 1998 due in part to the volatile financial markets in
August 1998 which negatively impacted the price of equity securities in the
financial services sector. Secondly, Capital Re is the reinsurer of
approximately $156 million in principal amount of three issues of asset-backed
securities issued by Commercial Financial Services Inc. (CFS). At December 31,
1998 approximately $150 million principal amount of the securities were
outstanding. CFS is under investigation by the Securities and Exchange
Commission, and the Oklahoma Securities Commission for allegations of
irregularities relating to certain securities issued by CFS. Although CFS has
not yet missed any bond payments and the assets backing the securities reinsured
by Capital Re are currently performing according to expectations, the
irregularities make it difficult to estimate collection expectations for all
securities issued by CFS, including those reinsured by Capital Re. On December
11, 1998 CFS filed for Chapter 11 bankruptcy protection.
Capital Re is evaluating the CFS reinsurance contingency and is presently unable
to determine the likelihood or amount of possible loss, if any. The financial
information of Capital Re presented in Note 9 and the Company's recorded equity
in Capital Re's 1998 earnings excluded any loss that may result from this
contingency. Capital Re has engaged outside consultants to review the loss
exposure and expects to complete its evaluation of the contingency in the first
quarter of 1999. The Company will record during the first quarter of 1999 its
share of any adjustment to Capital Re's 1998 earnings resulting from this
contingency. (See Note 9.) Changes made late in 1998 in the firm's management
and adjustments to its growth strategy should put Capital Re on course with the
Company's expectations.
In 1996 net income from Real Estate Operations included the recognition of tax
benefits (see Note 14) and the sale of a joint venture.
CORPORATE CHARGES were $21.5 million in 1998 ($19.8 million in 1997; $17.4
million in 1996). Corporate Charges in 1998 included lower interest expenses due
to the availability of cash from the sale of Common Stock offset by higher
expenses associated with benefit incentives, a change in accounting for start-up
costs, and technological and communication improvements made to corporate-wide
systems. In 1997 Corporate Charges reflected increased debt service costs to
finance investments in non-regulated operations and various strategic
initiatives, while 1996 included nine months of distributions with respect to
Cumulative Quarterly Income Preferred Securities issued in March 1996.
22 minnesota power, inc.
<PAGE>
1998 COMPARED TO 1997
OPERATING REVENUE
ELECTRIC OPERATIONS operating revenue was $18.0 million higher in 1998, even
though kilowatthour sales remained at similar levels. This increase was
primarily attributable to a higher average sales price for bulk power sold to
other power suppliers and marketers, and more revenue from fuel clause
adjustments. Bulk sale prices were higher because of storms and hot weather in
the Midwest. Revenue related to the fuel clause adjustment increased in 1998 to
recover the cost of replacement power needed during scheduled outages at Square
Butte and Boswell in 1998, and also for the reduction in hydro generation due to
dry spring conditions. Demand revenue from large power customers was lower in
1998 as a result of successful renegotiation of contracts which extended the
term of the all-requirements contracts, but in turn reduced the demand charge
component. Revenue from residential and gas customers was lower in 1998 because
of the unusually mild winter and warm spring. Operating revenue in 1997 included
$4.4 million in pre-tax gains from the sale of rights to microwave frequencies
and the sale of property along the St. Louis River.
Electric Operating Revenue
Change from 1997
---------------------------------------------------
Millions
Retail Electric Sales $(2.9)
Sales to Other Power Suppliers 10.8
Transmission Revenue 0.3
Conservation Improvement Programs 1.5
Fuel Clause Adjustments 10.1
Coal Revenue 0.3
Gas Sales (2.3)
Other 0.2
-----
$18.0
---------------------------------------------------
WATER SERVICES operating revenue was $0.1 million higher in 1998 because of
increased rates approved by the FPSC in 1998, higher consumption and more
revenue from non-regulated water subsidiaries. Consumption, which was up 10% in
1998, reflected the September 1997 acquisition of LaGrange, a water utility near
Fayetteville, North Carolina and drier than normal weather. Operating revenue in
1997 included a $7.3 million pre-tax gain from the sale of water and wastewater
assets to Orange County, Florida.
AUTOMOTIVE SERVICES operating revenue was $72.9 million higher in 1998 due to a
7% increase in vehicles consigned for sale at auctions, higher auction fees, the
rapid expansion and maturing of AFC and growth at Great Rigs. In 1997 operating
revenue included pre-tax gains totaling $5.7 million from the sale of an auction
facility and excess land.
PORTFOLIO AND REINSURANCE operating revenue was $0.6 million higher in 1998. The
increase reflected $4.3 million of dividend income received from a venture
capital investment, which was offset by reduced income from the securities
portfolio due to under performance of certain investments.
REAL ESTATE OPERATIONS operating revenue was $5.4 million lower in 1998
primarily due to large bulk sales at Palm Coast in 1997.
FUEL AND PURCHASED POWER EXPENSE
ELECTRIC OPERATIONS fuel expense was $3.4 million higher because of more steam
generation and slightly higher coal prices. Purchased power expense was $8.2
million higher because of replacement power needed during scheduled outages and
the average price paid per megawatthour (excluding Square Butte) increased 23%.
OPERATIONS EXPENSE
ELECTRIC OPERATIONS expenses were $2.1 million lower in 1998. Increased costs
for scheduled outages at Boswell, consulting services and the amortization of
deferred charges related to conservation improvement programs were offset by a
reduction in employee pension and early retirement expenses, and lower property
taxes due to the legislative reform of the Minnesota property tax system.
WATER SERVICES expenses were $1.0 million higher in 1998 primarily due to
increased consumption. Additional costs related to the expansion of
non-regulated water subsidiaries were offset by increased operating
efficiencies.
AUTOMOTIVE SERVICES expenses were up $54.6 million due to expenses associated
with the increase in vehicles consigned for sale at auctions, the addition of
three new auction facilities and the rapid expansion of AFC.
REAL ESTATE OPERATIONS expenses (excluding minority interest) from real estate
operations were $2.4 million lower in 1998 because in 1997 there was more sales
activity at Palm Coast.
minnesota power, inc. 23
<PAGE>
INCOME FROM EQUITY INVESTMENTS
PORTFOLIO AND REINSURANCE included $15.1 million of income in 1998 ($14.8
million in 1997) from the Company's investment in Capital Re.
1997 COMPARED TO 1996
OPERATING REVENUE
ELECTRIC OPERATIONS operating revenue was up $12.7 million in 1997. The demand
for electricity by all customer classes was strong in 1997, as was the marketing
of sales to other power suppliers. Revenue from sales to other power suppliers
was 4% lower in 1997 because less power was available. Less power was available
for sale because of higher prices for purchased power, reduction in transmission
capability damaged by severe spring storms in the Midwest, various generating
unit outages at Company and other plants in the Midwest, and less hydro
generation in Canada. While total revenue from sales to other power suppliers
and marketers was lower in 1997, higher profit margins were realized on those
sales. Operating revenue in 1997 included $4.4 million in pre-tax gains from the
sale of rights to microwave frequencies and the sale of property along the St.
Louis River.
Electric Operating Revenue
Change from 1996
-------------------------------------------------------
Millions
Retail Electric Sales $ 1.1
Sales to Other Power Suppliers (3.0)
Transmission Revenue 2.9
Conservation Improvement Programs 2.9
Fuel Clause Adjustments 2.9
Coal Revenue 0.5
Gas Sales 0.4
Other 5.0
-----
$12.7
-------------------------------------------------------
WATER SERVICES operating revenue was $10.3 million higher in 1997 because of
increased rates approved by the FPSC in 1996 for Florida Water customers and a
$7.3 million pre-tax gain from the sale of water and wastewater assets to Orange
County, Florida, in December 1997. These assets served about 4,000 customers.
Also in 1997, Heater acquired LaGrange, a water utility near Fayetteville, North
Carolina, for $3.4 million. The acquisition added 5,300 water customers and
contributed $0.9 million in revenue. The increase in revenue was partially
offset by lower revenue following the sale of two water systems in South
Carolina in 1996. Together the two sales resulted in pre-tax gains of $1.7
million during 1996. Sales were up 3% in 1997, despite heavy rainfall and
continued water conservation efforts by customers. Non-regulated water
subsidiaries contributed $1.2 million more to revenue in 1997.
AUTOMOTIVE SERVICES operating revenue was $71.6 million higher in 1997 primarily
due to more auction fees as a result of a 27% increase in vehicles consigned for
sale at auctions and more revenue from ancillary services, such as
reconditioning and transportation, at ADESA auction facilities. Auction
facilities added in 1996 contributed to the increase in vehicles consigned in
1997. Operating revenue from AFC in 1997 reflected the growth of the floorplan
financing business through expansion of existing loan production offices and the
addition of 25 new office locations. Pre-tax gains totaling $5.7 million from
the sale of an auction facility and excess land were also included in 1997
operating revenue.
PORTFOLIO AND REINSURANCE operating revenue from the securities portfolio
was $1.4 million higher in 1997 because the Company's average portfolio balance
was larger.
REAL ESTATE OPERATIONS operating revenue was $9.6 million higher in 1997
primarily due to increased sales from Palm Coast operations. Financial results
for Real Estate Operations reflected twelve months of Palm Coast operations in
1997 compared to less than nine months in 1996. In 1996 operating revenue
included $3.7 million from the sale of Lehigh's joint venture investment in a
resort and golf course.
FUEL AND PURCHASED POWER EXPENSE
ELECTRIC OPERATIONS purchased power expense was $3.0 million higher because the
average price paid per megawatthour (excluding Square Butte) increased 20%.
24 minnesota power, inc.
<PAGE>
OPERATIONS EXPENSE
ELECTRIC OPERATIONS operating expenses increased $2.6 million in 1997.
Depreciation expense increased $3.0 million, while reform of the Minnesota
property tax system reduced property taxes by $2.8 million in 1997. Start-up
costs associated with strategic initiatives and incentive compensation awards to
management related to total shareholder return performance also contributed to
higher operating expenses in 1997.
WATER SERVICES operating expenses were $7.2 million higher in 1997 primarily due
to start-up costs associated with the Company's non-regulated water
subsidiaries. Approximately $2 million of one-time charges relating to the
amount of investment in utility facilities were also included in operating
expenses in 1997. These higher operating expenses were tempered by improved
operating efficiencies at Florida Water.
AUTOMOTIVE SERVICES operating expenses were $52.7 million higher in 1997.
Operating expenses associated with the auction facilities reflected the 27%
increase in vehicles consigned and increased ancillary services. These operating
expenses were tempered by improved efficiencies and cost controls at auction
facilities. The expansion of AFC's floorplan financing business also contributed
to higher operating expenses in 1997.
REAL ESTATE OPERATIONS expenses (excluding minority interest) were $6.1 million
higher in 1997. The increase was attributed to more sales activity and
additional expenses as a result of Palm Coast operations.
INCOME FROM EQUITY INVESTMENTS
PORTFOLIO AND REINSURANCE included $14.8 million of income in 1997 ($11.8
million in 1996) from the Company's investment in Capital Re.
INCOME TAX EXPENSE
PORTFOLIO AND REINSURANCE income tax expense was $5.7 million higher in 1997
because of increased operating income, while 1996 reflected a one-time tax
benefit for an IRS audit adjustment.
REAL ESTATE OPERATIONS included the recognition of $8.2 million of tax benefits
at Lehigh in 1996. The Company's portion of the 1996 tax benefits was $6.6
million. (See Note 14.)
OUTLOOK
ELECTRIC OPERATIONS. The contribution from Electric Operations is expected to
remain stable as the industry continues to restructure. Electric Operations
intends to seek additional cost saving alternatives and efficiencies, and expand
non-regulated services to maintain its contribution to net income. The Company's
subsidiary, MP Telecom, which provides high volume fiber optic and microwave
communications to businesses and communities across northern Minnesota, intends
to connect other northern Minnesota communities as well as extend the
communication network to the Minneapolis-St. Paul metro area.
Annual taconite production in Minnesota was 46 million tons in 1998 (47 million
tons in 1997; 46 million tons in 1996). Based on the Company's research of the
taconite industry, Minnesota taconite production for 1999 is anticipated to
remain at or near the 1998 level. While taconite production is expected to
continue at annual levels of over 40 million tons, the long-term future of this
cyclical industry is less certain.
The record level of steel imports into the United States is adversely affecting
the domestic steel industry. If imports continue at 1998 levels, lower demand
for steel produced in the United States is likely to have an adverse affect on
the taconite producers and the economy as a whole in northern Minnesota.
Representatives of the United States steel industry have asserted that the
imports are unfair and illegal, and have filed anti-dumping trade suits with the
U.S. Department of Commerce. The Company is unable to predict the eventual
impact of this issue on the Company's Electric Operations.
Six of the seven taconite producers in Minnesota have collective bargaining
agreements with the United Steel Workers of America. These agreements expire in
August 1999. The Company is unable to predict whether or not any labor disputes
will arise in the course of negotiations and, if such disputes occur, the impact
any dispute would have on the Company's Electric Operations. Contracts with
these Large Power Customers provide for deferral without interest 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.
WATER SERVICES. Florida Water will continue to position itself by selectively
acquiring targeted water systems. In January 1999 Florida Water purchased Palm
Coast Utility Corporation which provides service to approximately 15,000 water
and 14,000 wastewater customers in Flagler County, Florida. (See Note 4.) The
strategic emphasis at Heater is growth in North Carolina. Both Florida Water and
Heater operate in states that are currently experiencing rapid population
growth, which should contribute to customer growth. Water Services has been
laying the groundwork for future growth in several new areas of the water
business. These non-regulated subsidiaries have been marketing the Company's
maintenance and water and wastewater management expertise to industrial and
governmental customers promoting privatization of these services.
minnesota power, inc. 25
<PAGE>
AUTOMOTIVE SERVICES. Auto auction sales are expected to rise at a rate of 6% to
8% annually. With the increased popularity of leasing and the high cost of new
vehicles, the same vehicles may come to auction more than once. Automotive
Services expects to participate in the industry's growth through selective
acquisitions and expanded services. ADESA and AFC continue to focus on growth in
the volume of vehicles consigned and financed, increased ancillary services, and
operating and technological efficiencies. Great Rigs plans to participate in
growth of auction volume and work to enhance market share.
INVESTMENTS. PORTFOLIO AND REINSURANCE. The Company's objective is to maintain
corporate liquidity between 7% and 10% of total assets ($160 to $230 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 portfolio is hedged against market downturns and aimed at
an after-tax return between 7% and 9%. 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 environment.
Actual returns will be partially dependent on general market conditions. The
Company intends to maintain its Capital Re holdings as a core component of the
Company's Investments segment. REAL ESTATE OPERATIONS. The Company may, from
time to time, acquire large residential community properties at low cost, add
value and sell them at current market prices in order to continue a consistent
earnings contribution from this business.
LIQUIDITY AND CAPITAL RESOURCES
A primary goal of the strategic plan is to improve cash flow from operations.
Since 1996 cash from operating activities has increased 84% (up 10% from 1997 to
1998; up 66% from 1996 to 1997). This has been accomplished due to operating
results, better management of working capital throughout the Company and capital
expenditure discipline. The Company's strategy includes growing the business
both with expanded facilities and operations (see Capital Requirements), and
through acquisitions and planned divestitures.
In May 1998 the Company filed a shelf registration statement with the Securities
and Exchange Commission (SEC) pursuant to Rule 415 under the Securities Act of
1933 with respect to 3.0 million original issue shares of Common Stock. In
September 1998 2,093,000 shares of the Company's Common Stock were sold in a
public offering at $43.75 per share. Total net proceeds of approximately $89
million were used to repay outstanding commercial paper, to fund strategic
initiatives and for capital expenditures. Net proceeds not immediately used for
the above purposes were invested in the Company's securities portfolio. The
Company may sell the remaining shares registered in May 1998 if warranted by
market conditions and the Company's capital requirements. The offer and sale of
such shares shall be made only by means of a prospectus. The increase in the
number of shares of Common Stock outstanding as of December 31, 1998 had an
immaterial dilutive impact on earnings per share for the 1998 periods.
Working capital, if and when needed, generally is provided by the sale of
commercial paper. In addition, securities investments can be liquidated to
provide funds for reinvestment in existing businesses or acquisition of new
businesses, and approximately 4 million original issue shares of Common Stock
are available for issuance through the DRIP. Minnesota Power's $60 million bank
line of credit provides liquidity for the Company's commercial paper program.
The amount and timing of future sales of the Company's securities will depend
upon market conditions and the specific needs of the Company. The Company may
from time to time sell securities to meet capital requirements, to provide for
the retirement or early redemption of issues of long-term debt and preferred
stock, to reduce short-term debt and for other corporate purposes.
A substantial amount of ADESA's working capital is generated internally from
payments made by vehicle purchasers. However, ADESA uses commercial paper issued
by the Company to meet short-term working capital requirements arising from the
timing of payment obligations to vehicle sellers and the availability of funds
from vehicle purchasers. During the sales process, ADESA does not typically take
title to vehicles.
AFC also uses commercial paper issued by the Company to meet its operational
requirements. AFC offers short-term on-site financing for dealers to purchase
vehicles at auctions in exchange for a security interest in those vehicles. The
financing is provided through the earlier of the date the dealer sells the
vehicle or a general borrowing term of 30 to 45 days. In May 1998 AFC executed
an Administration Agreement with ADT Automotive, Inc. (ADT) which has led to an
arrangement whereby AFC is providing floorplan financing services at 26 ADT
auctions. In total AFC has 84 loan production offices (54 at December 31, 1997).
AFC continues to sell eligible finance receivables on a revolving basis through
a private securitization structure which expires at the end of 2001. Third party
purchasers have agreed to purchase up to $225 million of finance receivables,
subject to certain eligibility criteria. At December 31, 1998 $202.9 million of
finance receivables had been sold under the structure ($145.0 million at
December 31, 1997), and AFC's securitization residual interest was $20.1 million
($12.3 million at December 31, 1997). Proceeds from the sale of the receivables
were used to repay borrowings from the Company and fund vehicle inventory
purchases for AFC's customers.
ADESA acquired the assets of Greater Lansing Auto Auction in Lansing, Michigan
and I-55 Auto Auction in St. Louis, Missouri on April 30, 1998, and Ark-La-Tex
Auto Auction in Shreveport, Louisiana on May 27, 1998 for a combined purchase
price of $23.8 million. The Company initially acquired these assets with
internally generated funds and issued commercial paper which was later repaid by
the issuance of Common Stock.
26 minnesota power, inc.
<PAGE>
Minnesota Power's electric utility first mortgage bonds and secured pollution
control bonds are currently rated Baa1 by Moody's Investors Service and A by
Standard and Poor's. The disclosure of these securities ratings is not a
recommendation to buy, sell or hold the Company's securities.
On January 18, 1999 the Company announced a 5% dividend increase and a
two-for-one stock split on its Common Stock. A quarterly dividend of $0.535 per
share on the Common Stock will be paid on March 1, 1999 to the holders of record
on February 16, 1999. Assuming timely regulatory approval, the effective date of
the stock split will be March 2, 1999 to shareholders of record at the close of
business February 16, 1999. In 1998 the Company paid out 76% (83% in 1997; 89%
in 1996) of its per share earnings in dividends. Minnesota Power's goal is to
maintain a dividend payout of 75% to 80% of per share earnings.
CAPITAL REQUIREMENTS
Consolidated capital expenditures totaled $81 million in 1998 ($72 million in
1997; $101 million in 1996). Expenditures in 1998 included $36 million for
Electric Operations, $22 million for Water Services, $22 million for Automotive
Services and $1 million for corporate purposes. Internally generated funds and
funds from original issue equity securities were the primary sources of funding
these capital expenditures.
Capital expenditures are expected to be $98 million in 1999 and total about $400
million for 2000 through 2003. The 1999 amount includes $47 million for electric
system component replacement and upgrades, telecommunication fiber and coal
handling equipment; $26 million to expand water and wastewater treatment
facilities to accommodate customer growth, to meet environmental standards and
for water conservation initiatives; and $25 million for on-going improvements at
existing vehicle auction facilities and associated computer systems. The Company
expects to use internally generated funds and original issue equity securities
to fund these capital expenditures.
MARKET RISK
The Company's securities portfolio has exposure to both price and interest rate
risk. Investments held principally for near-term sale are classified as trading
securities and recorded at fair value. Trading securities consist primarily of
the common stock of publicly traded companies, with utilities being the largest
industry sector. Investments held for an indefinite period of time are
classified as available-for-sale securities and also recorded at fair value. The
available-for-sale securities portfolio consists primarily of the preferred
stock of utilities and financial institutions with investment grade debt
ratings.
In strategies designed to reduce market risks, the Company sells common stock
short and enters into short sales of treasury futures contracts. Selling common
stock short is intended to reduce price risks associated with securities in the
Company's trading securities portfolio. The stock sold short consists primarily
of the stock of companies in similar industries. Treasury futures are used as a
hedge to reduce interest rate risks associated with holding fixed dividend
preferred stocks included in the Company's available-for-sale portfolio.
Generally, treasury future contracts mature in 90 days.
December 31, 1998 Fair Value
--------------------------------------------------------------
Millions
Trading Securities Portfolio $169.9 (a)
Available-For-Sale Securities Portfolio $73.5 (b)
--------------------------------------------------------------
(a) Net of $3.8 million in unrealized losses on common stock
sold short. The notional fair value of outstanding short
sales of common stock was approximately 85% of the fair
value of the trading securities portfolio.
(b) Net of $4.1 million in realized losses on treasury futures
contracts sold short. The notional fair value of
outstanding sales of treasury futures contracts was $24.5
million which represents 192 contracts with a notional
basis of $25.0 million.
The Company is also subject to interest rate risk through outstanding debt. The
majority of the Company's long-term debt is fixed-rate. (See Note 12.)
Short-term debt consists primarily of commercial paper. (See Note 7.)
In December 1998 Florida Water entered into a ten-year interest rate swap
agreement on a notional amount of $35 million. Under the agreement, Florida
Water makes quarterly payments at a variable interest rate based upon The Bond
Market Association Municipal Swap Index weekly floating average plus 58 basis
points (3.4% at December 31, 1998) and receives payments based on a fixed rate
of 4.79%.
minnesota power, inc. 27
<PAGE>
NEW ACCOUNTING STANDARDS
In June 1998 the FASB issued SFAS No. 133, "Accounting for Derivative
Instruments and Hedging Activities," effective for fiscal years beginning after
June 15, 1999. SFAS 133 establishes accounting and reporting standards requiring
that every derivative instrument be recorded on the balance sheet as either an
asset or liability measured at fair value. SFAS 133 requires that changes in the
derivative's fair value be recognized currently in earnings unless specific
hedge accounting criteria are met. Special accounting for qualifying hedges
allows a derivative's gains and losses to offset the related results on the
hedged item. The adoption of SFAS 133 is expected to be immaterial to the
Company's financial position and results of operations.
In November 1998 the Emerging Issues Task Force of the FASB reached a final
consensus on EITF 98-10, "Accounting for Contracts Involved in Energy Trading
and Risk Management Activities," which is effective for years beginning after
December 15, 1998. The EITF requires that energy trading contracts be marked to
market with gains and losses included in earnings. The adoption of EITF 98-10 is
expected to be immaterial to the Company's financial position and results of
operations.
YEAR 2000
The Year 2000 issue relates to computer systems that recognize the year in a
date field using only the last two digits. Unless corrected, the Year 2000 may
be interpreted as 1900, causing errors or shutdowns in computer systems which
may, in turn, disrupt operations.
STATE OF READINESS. The Company has been addressing the Year 2000 issue for five
years. In the ordinary course of business, it has replaced, or is in the process
of replacing, many of its major computer systems with new systems that have been
designed to be Year 2000 compliant. These updated systems handle critical
aspects of the Company's operations, including energy management and generation
control for Electric Operations, and customer information and financial
management Company-wide.
Each of the business segments has its own Year 2000 plan, which has been
reviewed and is being monitored by a corporate-level Year 2000 Risk Assessment
Team. The Company's plan for Year 2000 readiness involves four phases:
inventory, evaluation, remediation and contingency planning. Testing is an
ongoing and integral part of the evaluation, remediation and contingency
planning phases.
INVENTORY. Each business segment has performed an extensive inventory of
its information technology systems and other systems that use embedded
microprocessors (collectively, "Systems"). The business processes
supported by each System have been prioritized based on the degree of
impact business operations would encounter if the System were disrupted.
The inventory phase also includes identifying third parties with whom the
Company has material relationships. The degree to which each business
segment depends on third party support varies. Water Services, Automotive
Services and Real Estate Operations have identified minimal risk in most
areas. Where a third party is critical to a business process, efforts have
been initiated to obtain Year 2000 compliance information to identify the
degree of risk exposure the Company may encounter. Electric Operations is
working with its large power customers to share Year 2000 information and
determine their readiness. In addition, Electric Operations is working
with its fuel and transportation providers in an effort to ensure adequate
supplies of fuel.
The electric industry is unique in its reliance on the integrity of the
power pool grid to support and maintain reliable, efficient operations.
Preparation for the Year 2000 by Electric Operations is linked to the Year
2000 compliance efforts of other utilities as well as to those of its
major customers whose loads support the integrity of the power pool grid.
Electric Operations is coordinating its Year 2000 efforts with the plans
established by the North American Electric Reliability Council under the
direction of the U.S. Department of Energy and is also working with the
MAPP Year 2000 Task Force and a utility industry consortium to obtain and
share utility-specific Year 2000 compliance information.
The internal inventory phase was substantially completed in June 1998.
Regular contact with third parties with whom the Company has material
relationships will continue throughout 1999.
EVALUATION. This phase involves computer program code review and testing,
vendor contacts, System testing and fully-integrated System testing where
practical. The objective of this phase is to develop and update the
remediation plan. Some Systems, upon inspection, are determined to be
non-compliant and are immediately placed on the remediation schedule. Some
Systems require testing to determine compliance status. As of February 9,
1999 the evaluation phase was substantially complete.
REMEDIATION. In this phase each System is either fixed, replaced or
removed. Critical Systems fixed or replaced will be tested again for Year
2000 compliance. Remediation is expected to be substantially complete by
June 30, 1999. The Company estimates that as of February 9, 1999 the
remediation phase is approximately 17% complete.
28 minnesota power, inc.
<PAGE>
CONTINGENCY PLANNING. Each business segment is currently developing
contingency plans designed to continue critical processes in the event the
Company experiences Year 2000 disruptions despite remediation and testing.
Plans under development include establishment of internal communications
and securing adequate on-site supplies of critical materials. Contingency
plans also will be tested. Contingency plans are expected to be developed
by June 30, 1999. The Company estimates that as of February 9, 1999 the
contingency planning phase is approximately 20% complete.
COSTS. In the ordinary course of business over the last five years, the Company
has replaced major business and operating computer systems. These systems should
require minimal remediation efforts because of their recent implementation.
Formal Year 2000 readiness plans were established in March 1998. Since that
time, the Company has incurred $1.2 million in expenses primarily for labor
associated with inventory, evaluation and remediation efforts. The Company
estimates its remaining costs to prepare for the Year 2000 will be $5 million to
$9 million, the majority of which are non-labor costs and will be incurred in
1999. Funds to address Year 2000 issues have been provided for in the Company's
existing budgets. These costs include the assignment of existing personnel to
Year 2000 projects, maintenance and repair expenses, and capitalized
improvements. To date no critical projects have been deferred because of Year
2000 issues. The Company does not anticipate that its costs associated with Year
2000 readiness will materially impact the Company's earnings in any year.
RISKS. Based upon information to date, the Company believes that, in the most
reasonably likely worst-case scenario, Year 2000 issues could result in abnormal
operating conditions, such as short-term interruption of generation,
transmission and distribution functions within Electric Operations, as well as
Company-wide loss of system monitoring and control functions, and loss of voice
communications. These conditions, along with power outages due to possible
instability of the regional electric transmission grid, could result in
temporary interruption of service to customers. The Company does not believe the
overall impact of this scenario will have a material impact on its financial
condition or operations due to the anticipated short-term nature of
interruptions.
----------------------------
Readers are cautioned that forward-looking statements including those contained
above, should be read in conjunction with the Company's disclosures under the
heading: "SAFE HARBOR STATEMENT UNDER THE PRIVATE SECURITIES LITIGATION REFORM
ACT OF 1995" located in the preface of this Form 10-K.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
See Item 7 Management's Discussion and Analysis of Results of Operations and
Financial Condition - Market Risk for information related to quantitative and
qualitative disclosure about market risk.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
See the Company's consolidated financial statements as of December 31, 1998 and
1997 and for each of the three years in the period ended December 31, 1998, and
supplementary data, herein, which are indexed in Item 14(a).
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
Not applicable.
minnesota power, inc. 29
<PAGE>
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The information required for this Item is incorporated by reference herein and
will be set forth under the "Election of Directors" section in the Company's
Proxy Statement for the 1999 Annual Meeting of Shareholders, except for
information with respect to executive officers which is set forth in Part I
hereof. The 1999 Proxy Statement will be filed with the Securities and Exchange
Commission within 120 days after the end of the Company's 1998 fiscal year.
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 1999 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 1999 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 1999 Annual Meeting of Shareholders.
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a) Certain Documents Filed as Part of this Form 10-K.
Pages
(1) Financial Statements
Minnesota Power
Report of Independent Accountants 36
Consolidated Balance Sheet at December 31, 1998 and 1997 37
For the Three Years Ended December 31, 1998
Consolidated Statement of Income 38
Consolidated Statement of Cash Flows 39
Consolidated Statement of Common Stock Equity 40
Notes to Consolidated Financial Statements 41-57
(2) Financial Statement Schedules
Report of Independent Accountants on Financial
Statement Schedule 58
Schedule II - Minnesota Power Valuation and Qualifying
Accounts and Reserves 59
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
30 minnesota power, inc.
<PAGE>
Exhibit
Number
*2 - Agreement and Plan of Merger by and among the 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, amended and restated as of May 27, 1998
(filed as Exhibit 4(a) to Form 8-K dated June 3, 1998, File
No. 1-3548).
*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 effective May 27, 1998 (filed as Exhibit 4(b), to
Form 8-K dated June 3, 1998, File No. 1-3548).
*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:
Number Dated as of Reference 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)
Twentieth November 1, 1997 1-3548 (1997 Form 10-K) 4(a)3
*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).
minnesota power, inc. 31
<PAGE>
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 (filed as Exhibit 4(i) to Form
10-K for the year ended December 31, 1996, File No. 1-3548).
*4(j) - Rights Agreement dated as of July 24, 1996, between the Company and
the Corporate Secretary of the 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 the 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).
*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).
32 minnesota power, inc.
<PAGE>
Exhibit
Number
*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) - Power Purchase and Sale Agreement between the Company and Square
Butte Electric Cooperative, dated as of May 29, 1998 (filed as
Exhibit 10 to Form 10-Q for the quarter ended June 30, 1998, File No.
1-3548).
+*10(k) - 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(l) - 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(m) - 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).
+*10(n) - 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(o) - 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(p) - 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(q) - 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(r) - 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(s) - 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(t) - 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.
*21 - Subsidiaries of the Registrant (reference is made to the Company's
Form U-3A-2 for the year ended December 31, 1998, File No. 69-78).
23(a) - Consent of Independent Accountants.
23(b) - Consent of General Counsel.
27 - Financial Data Schedules.
- --------------------------------------------------
* 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.
None.
minnesota power, inc. 33
<PAGE>
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, the registrant has duly caused this report to be signed on its
behalf by the undersigned, thereunto duly authorized.
MINNESOTA POWER, INC.
Dated: February 9, 1999 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 Chairman, President, February 9, 1999
- --------------------------- Executive Officer and Director
Edwin L. Russell
David G. Gartzke Senior Vice President - Finance February 9, 1999
- --------------------------- and Chief Financial Officer
David G. Gartzke
Mark A. Schober Controller February 9, 1999
- ---------------------------
Mark A. Schober
Kathleen A. Brekken Director February 9, 1999
- ---------------------------
Kathleen A. Brekken
Merrill K. Cragun Director February 9, 1999
- ---------------------------
Merrill K. Cragun
Dennis E. Evans Director February 9, 1999
- ---------------------------
Dennis E. Evans
Peter J. Johnson Director February 9, 1999
- ---------------------------
Peter J. Johnson
George L. Mayer Director February 9, 1999
- ---------------------------
George L. Mayer
Jack I. Rajala Director February 9, 1999
- ---------------------------
Jack I. Rajala
Arend J. Sandbulte Director February 9, 1999
- ---------------------------
Arend J. Sandbulte
Nick Smith Director February 9, 1999
- ---------------------------
Nick Smith
Bruce W. Stender Director February 9, 1999
- ---------------------------
Bruce W. Stender
Donald C. Wegmiller Director February 9, 1999
- ---------------------------
Donald C. Wegmiller
34 minnesota power, inc.
<PAGE>
Minnesota Power, Inc.
Consolidated Financial Statements
For the Years Ended December 31, 1998, 1997 and 1996
with
Report of Independent Accountants
and
Report of Management
<PAGE>
REPORTS
INDEPENDENT ACCOUNTANTS [Logo]
To the Shareholders and
Board of Directors of Minnesota Power
In our opinion, the accompanying consolidated balance sheet and the related
consolidated statements of income, of cash flows and of common stock equity
present fairly, in all material respects, the financial position of Minnesota
Power and its subsidiaries at December 31, 1998 and 1997, and the results of
their operations and their cash flows for each of the three years in the period
ended December 31, 1998, in conformity with generally accepted accounting
principles. These financial statements are the responsibility of the Company's
management; our responsibility is to express an opinion on these financial
statements based on our audits. We conducted our audits of these statements in
accordance with generally accepted auditing standards which require that we plan
and perform the audit to obtain reasonable assurance about whether the financial
statements are free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in the financial
statements, assessing the accounting principles used and significant estimates
made by management, and evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for the opinion expressed
above.
PricewaterhouseCoopers LLP
PricewaterhouseCoopers LLP
Minneapolis, Minnesota
January 14, 1999
MANAGEMENT
The consolidated financial statements and other financial information were
prepared by management, which is responsible for their integrity and
objectivity. The financial statements have been prepared in conformity with
generally accepted accounting principles and necessarily include some amounts
that are based on informed judgments and best estimates and assumptions of
management.
To meet its responsibilities with respect to financial information, management
maintains and enforces a system of internal accounting controls designed to
provide assurance, on a cost effective basis, that transactions are carried out
in accordance with management's authorizations and that assets are safeguarded
against loss from unauthorized use or disposition. The system includes an
organizational structure which provides an appropriate segregation of
responsibilities, careful selection and training of personnel, written policies
and procedures, and periodic reviews by the internal audit department. In
addition, the Company has a personnel policy which requires all employees to
maintain a high standard of ethical conduct. Management believes the system is
effective and provides reasonable assurance that all transactions are properly
recorded and have been executed in accordance with management's authorization.
Management modifies and improves its system of internal accounting controls in
response to changes in business conditions. The Company's internal audit staff
is charged with the responsibility for determining compliance with Company
procedures.
Three directors of the Company, not members of management, serve as the Audit
Committee. The Board of Directors, through its Audit Committee, oversees
management's responsibilities for financial reporting. The Audit Committee meets
regularly with management, the internal auditors and the independent accountants
to discuss auditing and financial matters and to assure that each is carrying
out its responsibilities. The internal auditors and the independent accountants
have full and free access to the Audit Committee without management present.
PricewaterhouseCoopers LLP, independent accountants, are engaged to express an
opinion on the financial statements. Their audit is conducted in accordance with
generally accepted auditing standards and includes a review of internal controls
and tests of transactions to the extent necessary to allow them to report on the
fairness of the operating results and financial condition of the Company.
Edwin L. Russell David G. Gartzke
Edwin L. Russell David G. Gartzke
Chairman, President and Chief Executive Officer Chief Financial Officer
36 minnesota power, inc.
<PAGE>
CONSOLIDATED FINANCIAL STATEMENTS
MINNESOTA POWER CONSOLIDATED BALANCE SHEET
December 31 1998 1997
- --------------------------------------------------------------------------------
Millions
Assets
Plant and Investments
Electric Operations $ 771.5 $ 783.5
Water Services 329.4 322.2
Automotive Services 186.2 167.1
Investments 263.5 252.9
-------- --------
Total Plant and Investments 1,550.6 1,525.7
-------- --------
Current Assets
Cash and Cash Equivalents 89.4 57.9
Trading Securities 169.9 123.5
Accounts Receivable - Net 156.1 146.4
Fuel, Material and Supplies 24.0 25.0
Prepayments and Other 48.1 32.5
-------- --------
Total Current Assets 487.5 385.3
-------- --------
Other Assets
Goodwill 169.8 158.9
Deferred Regulatory Charges 56.1 64.4
Other 53.1 54.6
-------- --------
Total Other Assets 279.0 277.9
-------- --------
Total Assets $2,317.1 $2,188.9
- --------------------------------------------------------------------------------
Capitalization and Liabilities
Capitalization
Common Stock Without Par Value, 130.0
Shares Authorized 36.2 and 33.6
Shares Outstanding $ 529.0 $ 416.0
Unearned ESOP Shares (62.5) (65.9)
Accumulated Other Comprehensive Income 1.5 3.8
Retained Earnings 317.6 296.1
-------- --------
Total Common Stock Equity 785.6 650.0
Cumulative Preferred Stock 11.5 11.5
Redeemable Serial Preferred Stock 20.0 20.0
Company Obligated Mandatorily Redeemable
Preferred Securities of Subsidiary MP&L
Capital I Which Holds Solely Company Junior
Subordinated Debentures 75.0 75.0
Long-Term Debt 672.2 685.4
-------- --------
Total Capitalization 1,564.3 1,441.9
-------- --------
Current Liabilities
Accounts Payable 123.3 97.0
Accrued Taxes, Interest and Dividends 62.9 66.5
Notes Payable and Long-Term Debt Due
Within One Year 90.0 133.8
Other 69.8 45.3
-------- --------
Total Current Liabilities 346.0 342.6
-------- --------
Other Liabilities
Accumulated Deferred Income Taxes 153.4 151.3
Contributions in Aid of Construction 108.2 102.6
Deferred Regulatory Credits 55.2 60.7
Other 90.0 89.8
-------- --------
Total Other Liabilities 406.8 404.4
-------- --------
Commitments and Contingencies
-------- --------
Total Capitalization and Liabilities $2,317.1 $2,188.9
- --------------------------------------------------------------------------------
The accompanying notes are an integral part of these statements.
minnesota power, inc. 37
<PAGE>
MINNESOTA POWER CONSOLIDATED STATEMENT OF INCOME
For the Year Ended December 31 1998 1997 1996
- --------------------------------------------------------------------------------
Millions except per share amounts
Operating Revenue
Electric Operations $ 559.9 $541.9 $529.2
Water Services 95.6 95.5 85.2
Automotive Services 328.4 255.5 183.9
Investments 55.8 60.7 48.6
-------- ------ ------
Total Operating Revenue 1,039.7 953.6 846.9
-------- ------ ------
Operating Expenses
Fuel and Purchased Power 205.7 194.1 190.9
Operations 635.4 579.9 512.2
Interest Expense 64.9 64.2 62.1
-------- ------ ------
Total Operating Expenses 906.0 838.2 765.2
-------- ------ ------
Income from Equity Investments 14.8 14.8 11.8
-------- ------ ------
Operating Income 148.5 130.2 93.5
Distributions on Redeemable Preferred
Securities of Subsidiary 6.0 6.0 4.7
Income Tax Expense 54.0 46.6 19.6
-------- ------ ------
Net Income 88.5 77.6 69.2
Dividends on Preferred Stock 2.0 2.0 2.4
-------- ------ ------
Earnings Available for Common Stock $ 86.5 $ 75.6 $ 66.8
-------- ------ ------
Average Shares of Common Stock
Basic 32.0 30.6 29.3
Diluted 32.1 30.6 29.3
Earnings Per Share of Common Stock
Basic $2.70 $2.47 $2.28
Diluted $2.69 $2.47 $2.28
Dividends Per Share of Common Stock $2.04 $2.04 $2.04
- --------------------------------------------------------------------------------
The accompanying notes are an integral part of these statements.
38 minnesota power, inc.
<PAGE>
MINNESOTA POWER CONSOLIDATED STATEMENT OF CASH FLOWS
For the Year Ended December 31 1998 1997 1996
- --------------------------------------------------------------------------------
Millions
Operating Activities
Net Income $ 88.5 $ 77.6 $ 69.2
Income From Equity Investments - Net of
Dividends Received (13.7) (13.9) (11.0)
Depreciation and Amortization 75.0 70.8 65.1
Deferred Income Taxes 1.1 2.0 (11.8)
Pre-Tax Gain on Sale of Plant (0.6) (14.0) (1.6)
Changes In Operating Assets and
Liabilities - Net of the Effects
of Subsidiary Acquisitions
Trading Securities (46.4) (36.7) (46.8)
Accounts Receivable (9.7) 20.0 (17.5)
Fuel, Material and Supplies 1.0 (1.8) 3.2
Accounts Payable 26.4 20.9 (0.1)
Other Current Assets and Liabilities 5.1 (5.0) 15.2
Other - Net 19.6 12.5 15.7
------ ------ ------
Cash From Operating Activities 146.3 132.4 79.6
------ ------ ------
Investing Activities
Proceeds From Sale of Investments
in Securities 35.2 47.7 43.1
Proceeds From Sale of Plant 1.4 19.4 8.8
Additions to Investments (33.1) (42.5) (76.7)
Additions to Plant (80.8) (72.2) (101.5)
Acquisition of Subsidiaries - Net of
Cash Acquired (23.8) (2.4) (66.9)
Other - Net 2.3 17.5 6.5
------ ------ ------
Cash For Investing Activities (98.8) (32.5) (186.7)
------ ------ ------
Financing Activities
Issuance of Long-Term Debt 2.0 176.7 205.5
Issuance of Company Obligated Mandatorily
Redeemable Preferred Securities of
Subsidiary MP&L Capital I - Net - - 72.3
Issuance of Common Stock 111.0 19.7 19.0
Changes in Notes Payable - Net (48.1) (27.2) 56.3
Reductions of Long-Term Debt (10.0) (187.8) (155.3)
Redemption of Preferred Stock - - (17.6)
Dividends on Preferred and Common Stock (67.0) (64.5) (62.0)
------ ------ ------
Cash From (For) Financing Activities (12.1) (83.1) 118.2
------ ------ ------
Effect of Exchange Rate Changes on Cash (3.9) (1.7) 0.1
------ ------ ------
Change in Cash and Cash Equivalents 31.5 15.1 11.2
Cash and Cash Equivalents at Beginning
of Period 57.9 42.8 31.6
------ ------ ------
Cash and Cash Equivalents at End of Period $ 89.4 $ 57.9 $ 42.8
------ ------ ------
Supplemental Cash Flow Information
Cash Paid During the Period For
Interest - Net of Capitalized $63.0 $66.2 $54.4
Income Taxes $54.4 $31.3 $25.5
- --------------------------------------------------------------------------------
The accompanying notes are an integral part of these statements.
minnesota power, inc. 39
<PAGE>
MINNESOTA POWER CONSOLIDATED STATEMENT OF COMMON STOCK EQUITY
<TABLE>
<CAPTION>
Accumulated
Total Other Unearned
Common Retained Comprehensive Common ESOP
Stock Equity Earnings Income Stock Shares
- ------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
Millions
Balance at December 31, 1995 $584.1 $276.2 $3.1 $377.7 $(72.9)
Comprehensive Income
Net Income 69.2 69.2
Other Comprehensive Income - Net of Tax
Unrealized Losses on Securities - Net (0.5) (0.5)
Foreign Currency Translation Adjustments 0.1 0.1
------
Total Comprehensive Income 68.8
Common Stock Issued - Net 16.5 16.5
Dividends Declared (62.0) (62.0)
Redemption of Preferred Stock (0.4) (0.4)
ESOP Shares Earned 3.8 3.8
------ ------ ---- ------ ------
Balance at December 31, 1996 610.8 283.0 2.7 394.2 (69.1)
Comprehensive Income
Net Income 77.6 77.6
Other Comprehensive Income - Net of Tax
Unrealized Gains on Securities - Net 2.8 2.8
Foreign Currency Translation Adjustments (1.7) (1.7)
------
Total Comprehensive Income 78.7
Common Stock Issued - Net 21.8 21.8
Dividends Declared (64.5) (64.5)
ESOP Shares Earned 3.2 3.2
------ ------ ---- ------ ------
Balance at December 31, 1997 650.0 296.1 3.8 416.0 (65.9)
Comprehensive Income
Net Income 88.5 88.5
Other Comprehensive Income - Net of Tax
Unrealized Gains on Securities - Net 1.6 1.6
Foreign Currency Translation Adjustments (3.9) (3.9)
------
Total Comprehensive Income 86.2
Common Stock Issued - Net 113.0 113.0
Dividends Declared (67.0) (67.0)
ESOP Shares Earned 3.4 3.4
------ ------ ---- ------ ------
Balance at December 31, 1998 $785.6 $317.6 $1.5 $529.0 $(62.5)
- --------------------------------------------------------------------------------------------------------------------------
</TABLE>
The accompanying notes are an integral part of these statements.
40 minnesota power, inc.
<PAGE>
NOTES TO FINANCIAL STATEMENTS
1 BUSINESS SEGMENTS
Millions
<TABLE>
<CAPTION>
Investments
--------------------
Electric Water Automotive Portfolio & Real Corporate
For the Year Ended December 31 Consolidated Operations Services Services<F1> Reinsurance Estate Charges
- ---------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C> <C>
1998
Operating Revenue $1,039.7 $559.9 $95.6 $328.4<F2> $22.7 $33.4 $ (0.3)
Operation and Other Expense 766.1 411.3 61.0 256.1 3.3 19.2<F4> 15.2
Depreciation and Amortization 75.0 47.1 11.8 15.7 - 0.1 0.3
Interest Expense 64.9 22.1 10.3 9.7 - - 22.8
Income from Equity Investments 14.8 (0.1) - - 14.9 - -
-------- ------ ----- ------ ----- ----- ------
Operating Income (Loss) 148.5 79.3 12.5 46.9 34.3 14.1 (38.6)
Distributions on Redeemable
Preferred Securities of Subsidiary 6.0 1.7 - - - - 4.3
Income Tax Expense (Benefit) 54.0 30.2 5.0 21.4 12.7 6.1 (21.4)
-------- ------ ----- ------ ----- ----- ------
Net Income (Loss) $ 88.5 $ 47.4 $ 7.5 $ 25.5 $21.6 $ 8.0 $(21.5)
-------- ------ ----- ------ ----- ----- ------
Total Assets $2,317.1 $999.9 $376.0 $529.3<F3> $334.9 $76.7 $0.3
Accumulated Depreciation
and Amortization $775.6 $596.1 $135.2 $42.7 - $1.6 -
Construction Work in Progress $17.2 $5.7 $10.7 $0.8 - - -
Capital Expenditures $80.8 $36.1 $21.8 $22.0 - $0.1 $0.8
- ---------------------------------------------------------------------------------------------------------------------------
1997
Operating Revenue $953.6 $541.9 $95.5 $255.5<F2> $22.1 $38.8 $ (0.2)
Operation and Other Expense 703.2 403.7 60.6 203.2 2.1 21.9<F4> 11.7
Depreciation and Amortization 70.8 45.2 11.2 14.0 - 0.1 0.3
Interest Expense 64.2 21.3 11.0 9.9 - 0.8 21.2
Income from Equity Investments 14.8 - - - 14.8 - -
------ ------ ----- ------ ----- ----- ------
Operating Income (Loss) 130.2 71.7 12.7 28.4 34.8 16.0 (33.4)
Distributions on Redeemable
Preferred Securities of Subsidiary 6.0 1.6 - - - - 4.4
Income Tax Expense (Benefit) 46.6 27.0 4.5 14.4 12.1 6.6 (18.0)
------ ------ ----- ------ ----- ----- ------
Net Income (Loss) $ 77.6 $ 43.1 $ 8.2 $ 14.0 $22.7 $ 9.4 $(19.8)
------ ------ ----- ------ ----- ----- ------
Total Assets $2,188.9 $973.9 $384.7 $474.7<F3> $288.2 $66.7 $0.7
Accumulated Depreciation
and Amortization $713.2 $562.1 $122.9 $26.9 - $1.3 -
Construction Work in Progress $26.2 $11.2 $9.6 $5.4 - - -
Capital Expenditures $72.2 $34.6 $22.2 $11.2 - $0.2 $4.0
- ---------------------------------------------------------------------------------------------------------------------------
1996
Operating Revenue $846.9 $529.2 $85.2 $183.9<F2> $20.7 $29.2 $ (1.3)
Operation and Other Expense 638.0 400.9 53.6 152.8 2.7 17.1<F4> 10.9
Depreciation and Amortization 65.1 42.2 11.0 11.7 - 0.2 -
Interest Expense 62.1 22.5 12.5 11.7 - 1.2 14.2
Income from Equity Investments 11.8 - - - 11.8 - -
------ ------ ----- ------ ----- ----- ------
Operating Income (Loss) 93.5 63.6 8.1 7.7 29.8 10.7 (26.4)
Distributions on Redeemable
Preferred Securities of Subsidiary 4.7 1.3 - - - - 3.4
Income Tax Expense (Benefit) 19.6 22.9 2.7 4.0 6.4 (4.0)<F5> (12.4)
------ ------ ----- ----- ----- ----- ------
Net Income (Loss) $ 69.2 $ 39.4 $ 5.4 $ 3.7 $23.4 $14.7 $(17.4)
------ ------ ----- ----- ----- ----- ------
Total Assets $2,148.7 $995.8 $371.2 $459.5<F3> $255.7 $64.7 $1.8
Accumulated Depreciation
and Amortization $662.4 $533.5 $113.8 $14.1 - $1.0 -
Construction Work in Progress $22.7 $4.0 $7.1 $11.6 - - -
Capital Expenditures $101.5 $37.5 $22.2 $41.7 - $0.1 -
- ---------------------------------------------------------------------------------------------------------------------------
<FN>
<F1> Purchased 80% of ADESA, including AFC and Great Rigs, on July 1, 1995,
another 3% in January 1996 and the remaining 17% in August 1996.
<F2> Included $30.6 million of Canadian operating revenue in 1998 ($22.4 million
in 1997; $18.4 million in 1996).
<F3> Included $24.9 million of Canadian assets in 1998 ($19.8 million in 1997;
$21.2 million in 1996).
<F4> Included $2.0 million of minority interest in 1998 ($2.3 million in 1997;
$3.7 million in 1996).
<F5> Included $8.2 million of tax benefits in 1996. (See Note 14.)
</FN>
</TABLE>
minnesota power, inc. 41
<PAGE>
2 OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES
FINANCIAL STATEMENT PREPARATION. Minnesota Power prepares its financial
statements in conformity with generally accepted accounting principles. These
principles require management to make informed judgments, best estimates and
assumptions that affect the reported amounts of assets, liabilities, revenue and
expenses. Actual results could differ from those estimates.
PRINCIPLES OF CONSOLIDATION. The consolidated financial statements include the
accounts of the Company and all of its majority owned subsidiary companies. All
material intercompany balances and transactions have been eliminated in
consolidation. Information for prior periods has been reclassified to present
comparable information for all periods.
NATURE OF OPERATIONS AND REVENUE RECOGNITION. Minnesota Power is a broadly
diversified service company that has operations in four principal business
segments. The Electric Operations, Water Services and Automotive Services
segments were determined based on products and services provided. The
Investments segment was determined based on short-term corporate liquidity needs
and the need to provide financial flexibility to pursue strategic initiatives in
the other business segments. The Company measures performance of its operations
through careful budgeting and monitoring of contributions by business segment to
consolidated net income. Corporate Charges consist of expenses incurred by the
Company's corporate headquarters and interest and preferred stock expense not
specifically identifiable to a business segment. Management's policy is to not
allocate these expenses to business segments.
ELECTRIC OPERATIONS. Electric Operations generate, transmit, distribute and
market electricity. Electric service is provided to 138,000 customers in
northeastern Minnesota and northwestern Wisconsin. Large Power Customers, which
include five taconite producers, four paper and pulp mills, and two pipeline
companies, purchase about half of the electricity the Company sells under
all-requirements contracts with expiration dates extending from May 2001 through
December 2008. (See Item 1 - Electric Operations - Large Power Customers in
this Form 10-K.) BNI Coal, a wholly owned subsidiary, mines and sells lignite
coal to two North Dakota mine-mouth generating units, one of which is Square
Butte. Square Butte supplies approximately 71% (322 MW) of its output to
Minnesota Power under a long-term contract. (See Note 11.)
Electric rates are under the jurisdiction of various state and federal
regulatory authorities. Billings are rendered on a cycle basis. Revenue is
accrued for service provided but not billed. Electric rates include adjustment
clauses which bill or credit customers for fuel and purchased energy costs above
or below the base levels in rate schedules and bill retail customers for the
recovery of CIP expenditures not collected in base rates.
WATER SERVICES. Water Services include several wholly owned subsidiaries of the
Company. Florida Water is the largest investor owned supplier of water and
wastewater utility services in Florida. Heater provides water and wastewater
services primarily in North Carolina. In total, 164,000 water and 70,000
wastewater treatment customers are served. Water and wastewater rates are under
the jurisdiction of various state and county regulatory authorities. Billings
are rendered on a cycle basis. Revenue is accrued for services provided but not
billed. Instrumentation Services, Inc., U.S. Maintenance and Management, and
Vibration Correction Services, Inc. provide predictive and preventive
maintenance services to water utility companies and other industrial operations
in the United States. Americas' Water offers contract management, operations and
maintenance services to governments and industries.
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; Great Rigs, an auto transport company;
and PAR, a vehicle remarketing company. ADESA is one of the three largest
vehicle auction networks in the United States. ADESA owns and operates 28
vehicle auctions in the United States and Canada through which used cars and
other vehicles are purchased and sold by 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. PAR provides customized remarketing services, including
transporting and liquidating off-lease vehicles, to various businesses with
fleet operations. AFC provides inventory financing for wholesale and retail
automobile dealers who purchase vehicles at ADESA auctions, independent auctions
and other auction chains. AFC has 84 loan production offices located across the
United States and Canada. These offices provide qualified dealers credit to
purchase vehicles at any of the 400 plus auctions approved by AFC. Great Rigs is
one of the nation's largest used automobile transport companies with 145
automotive carriers. It offers customers pick up and delivery service through 13
strategically located transportation hubs in the United States. ADESA and Great
Rigs recognize revenue when services are performed. AFC revenue is comprised of
gains on sales of receivables, and interest, fee and servicer income. As is
customary for finance companies, AFC's revenue is reported net of interest
expense of $1.8 million in 1998 ($1.5 million in 1997; $2.2 million in 1996).
INVESTMENTS. The Company's securities portfolio is intended to provide stable
earnings and liquidity. Proceeds from the securities portfolio are available for
reinvestment in existing businesses, to fund strategic initiatives and for other
corporate purposes. The Company has a 21% ownership in Capital Re, a financial
guaranty reinsurance and specialty insurance company, accounted for using the
equity method. Investments also include intermediate-term investments in venture
capital funds that invest in developing utility technologies, and an 80%
ownership in Lehigh, a Florida company which through its subsidiaries owns real
estate in Florida. Real estate revenue is recognized on the accrual basis.
42 minnesota power, inc.
<PAGE>
PLANT DEPRECIATION. Plant is recorded at original cost, and is reported on the
balance sheet net of accumulated depreciation. Expenditures for additions and
significant replacements and improvements are capitalized; maintenance and
repair costs are expensed as incurred. When utility plant is retired or
otherwise disposed of, the cost less net proceeds is normally charged to
accumulated depreciation and no gain or loss is recognized. Contributions in aid
of construction relate to water utility assets, and are amortized over the
estimated life of the associated asset. This amortization reduces depreciation
expense.
Depreciation is computed using the estimated useful lives of the various classes
of plant. In 1998 average depreciation rates for the electric, water and
automotive segments were 3.5%, 2.6% and 4.1%, respectively (3.4%, 2.7% and 4.1%,
respectively, in 1997; 3.2%, 2.6% and 3.5%, respectively, in 1996).
ACCOUNTS RECEIVABLE. Accounts receivable is reported on the balance sheet net of
reserves and includes finance receivables from the floorplan financing business
and real estate operations. The reserves for uncollectible accounts are based on
management's evaluation of the receivable portfolio under current conditions,
the size of the portfolio, overall portfolio quality, review of specific
problems and such other factors which in management's judgment deserve
recognition in estimating losses.
AFC sells eligible finance receivables on a revolving basis through a private
securitization structure which expires at the end of 2001. Third party
purchasers have agreed to purchase up to $225 million of finance receivables,
subject to certain eligibility criteria. At December 31, 1998 $202.9 million of
finance receivables had been sold under the structure ($145.0 million at
December 31, 1997), and AFC's securitization residual interest was $20.1 million
($12.3 million at December 31, 1997). The residual interest is recorded in
prepayments and other assets at estimated fair value, with unrealized gains and
losses recognized in earnings. Fair value is based upon estimates of future cash
flows, using assumptions that market participants would use to value such
instruments, including estimates of anticipated credit losses over the life of
the receivables sold. A discount rate was not used due to the short-term nature
of the receivables sold.
Accounts Receivable
December 31 1998 1997
- --------------------------------------------------------------------------------
Millions
Trade Accounts Receivable $116.0 $106.2
Less Reserve for Doubtful Accounts 6.0 5.1
------ ------
110.0 101.1
------ ------
Finance Receivables 252.6 193.1
Less Amount Sold 202.9 145.0
Reserve for Doubtful Accounts 3.6 2.8
------ ------
46.1 45.3
------ ------
Total Accounts Receivable $156.1 $146.4
- --------------------------------------------------------------------------------
FUEL, MATERIAL AND SUPPLIES. Fuel, material and supplies are stated at the
lower of cost or market. Cost is determined by the average cost method.
GOODWILL. Goodwill primarily relates to the Automotive Services segment and
represents the excess of cost over net assets of businesses acquired.
Amortization is computed on a straight-line basis over a 40 year period.
DEFERRED REGULATORY CHARGES AND CREDITS. The Company's utility operations are
subject to the provisions of SFAS 71, "Accounting for the Effects of Certain
Types of Regulation." The Company capitalizes as deferred regulatory charges
incurred costs which are probable of recovery in future utility rates. Deferred
regulatory credits represent amounts expected to be credited to customers in
rates. (See Note 3.)
UNAMORTIZED EXPENSE, DISCOUNT AND PREMIUM ON DEBT. Expense, discount and premium
on debt are deferred and amortized over the lives of the related issues.
CASH AND CASH EQUIVALENTS. The Company considers all investments purchased
with maturities of three months or less to be cash equivalents.
FOREIGN CURRENCY TRANSLATION. Results of operations for Automotive Services'
Canadian subsidiaries are translated into United States dollars using the
average exchange rates during the period. Assets and liabilities are translated
into United States dollars using the exchange rate on the balance sheet date,
except for intangibles and fixed assets, which are translated at historical
rates.
minnesota power, inc. 43
<PAGE>
3 REGULATORY MATTERS
The Company files for periodic rate revisions with the Minnesota Public
Utilities Commission (MPUC), the Federal Energy Regulatory Commission (FERC),
the Florida Public Service Commission (FPSC) and other state and county
regulatory authorities. The MPUC had regulatory authority over approximately 67%
in 1998 (68% in 1997; 69% in 1996) of the Company's total electric operating
revenue. Interim rates in Minnesota and Florida are placed into effect, subject
to refund with interest, pending a final decision by the appropriate commission.
ELECTRIC RATES. Retail deregulation of the electric industry is being considered
at both the federal and state level. 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 competitive pressures. While Congress is not expected to
pass legislation in 1999, 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.
WATER AND WASTEWATER RATES. 1995 RATE CASE. Florida Water requested an $18.1
million annual 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. The new rates were
implemented in September 1996. In November 1996 Florida Water filed with the
Florida First District Court of Appeals (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 the course of the appeals
process, the FPSC reconsidered an issue in its initial decision and, in June
1997, allowed Florida Water to resume collecting approximately $1 million, on an
annual basis, in new customer fees. On June 10, 1998 the Court of Appeals ruled
in Florida Water's favor on all material issues appealed by Florida Water and
remanded the matter back to the FPSC for action consistent with the Court's
order. The Court of Appeals also overturned its decision in Florida Water's 1991
Rate Case which had required a "functional relationship" between service areas
as a precondition to implementation of uniform rates. On December 15, 1998 the
FPSC granted Florida Water an additional annual revenue increase of
approximately $1.2 million related to several of the issues reversed by the
Court of Appeals, and permitted collection of approximately $2.4 million in
surcharges to reimburse Florida Water for revenue (plus interest) wrongfully
denied in the FPSC's October 1996 order. Florida Water began collecting the new
rates in January 1999 and expects to begin collecting the surcharges during the
first quarter of 1999. The FPSC reopened the record on two remaining issues on
remand from the Court of Appeals regarding the amount of investment in utility
facilities recoverable in rates from current customers. A decision in the
Company's favor would result in additional revenue and surcharges. A hearing
with respect to the two remaining issues has not been scheduled by the FPSC. The
Company is unable to predict the timing or outcome of these proceedings.
1991 RATE CASE REFUNDS. In 1995 the 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 did not require refunds. Florida
Water's potential refund liability at that time was 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 (see 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 prospectively 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, arguing that they are entitled to a refund because the
FPSC had no authority to order uniform rates. The Company has appealed the $2.5
million refund order. Initial briefs were filed by all parties on May 22, 1998.
Upon issuance of the June 10, 1998 opinion of the Court of Appeals with respect
to Florida Water's 1995 Rate Case (see 1995 Rate Case) in which the court
reversed its previous ruling that the FPSC was without authority to order
uniform rates, customer groups supporting the FPSC's January 1998 order filed a
motion with the Court of Appeals seeking dismissal of the appeal by customer
groups seeking refunds. Customers seeking refunds filed amended briefs on
September 14, 1998. No provision for refund has been recorded. The Company is
unable to predict the timing or outcome of the appeals process.
DEFERRED REGULATORY CHARGES AND CREDITS. Based on current rate treatment,
the Company believes all deferred regulatory charges are probable of recovery.
44 minnesota power, inc.
<PAGE>
Deferred Regulatory Charges and Credits
December 31 1998 1997
- --------------------------------------------------------------------------------
Millions
Deferred Charges
Income Taxes $17.9 $21.5
Conservation Improvement Programs 18.8 17.7
Early Retirement Plan - 2.8
Postretirement Benefits 2.8 5.4
Premium on Reacquired Debt 6.2 6.9
Other 10.4 10.1
----- -----
56.1 64.4
Deferred Credits
Income Taxes 55.2 60.7
----- -----
Net Deferred Regulatory Charges $ 0.9 $ 3.7
- --------------------------------------------------------------------------------
4 ACQUISITIONS AND DIVESTITURES
ACQUISITION OF LAGRANGE. In 1997 the NCUC approved the transfer of LaGrange
Waterworks Corporation, a water utility near Fayetteville, North Carolina, to
Heater. The Company exchanged 96,000 shares of common stock, with a market value
of approximately $3.4 million, for all the outstanding shares of LaGrange and
accounted for the transaction as a pooling of interests. The acquisition added
5,300 water customers. Financial results prior to the acquisition were not
material.
ACQUISITION OF PALM COAST. In April 1996 Palm Coast Holdings, Inc., a wholly
owned subsidiary of Lehigh Acquisition Corporation, acquired real estate assets
(Palm Coast) from ITT Community Development Corp. and other affiliates of ITT
Industries, Inc. (ITT) for $34 million. These assets included developed
residential lots, a real estate contract receivables portfolio and approximately
13,000 acres of commercial and other land. Palm Coast is a planned community
located between St. Augustine and Daytona Beach, Florida. In January 1999
Florida Water purchased Palm Coast Utility Corporation (PCUC) from ITT for $16.5
million plus $1,000 per water connection for eight years. The transaction will
be accounted for by the purchase method in 1999. PCUC provides service to
approximately 15,000 water and 14,000 wastewater customers in Flagler County,
Florida.
ACQUISITION OF ISI. In April 1996 MP Water Resources acquired all the
outstanding common stock of Instrumentation Services, Inc., a predictive
maintenance service business, in exchange for 96,526 shares of Minnesota Power
common stock. The acquisition was accounted for as a pooling of interests.
Financial results prior to the acquisition were not material.
ACQUISITION OF ADESA. The Company acquired 80% of ADESA on July 1, 1995,
increased its ownership interest to 83% in January 1996 and acquired the
remaining 17% interest in August 1996. The total purchase price was $227
million. The step acquisitions were accounted for by the purchase method.
Accordingly, ADESA earnings have been included in the Company's consolidated
financial statements based on the ownership interest as of the date of each
acquisition. Acquired goodwill and other intangible assets are being amortized
using the straight line method.
ACQUISITION OF AUCTION FACILITIES. ADESA acquired the assets of Greater Lansing
Auto Auction in Lansing, Michigan and I-55 Auto Auction in St. Louis, Missouri
in April 1998, and Ark-La-Tex Auto Auction in Shreveport, Louisiana in May 1998
for a combined purchase price of $23.8 million. The acquisitions were accounted
for using the purchase method and resulted in additional goodwill of
$16.3 million. Financial results for these three auctions have been included in
the Company's consolidated financial statements since the dates of acquisition.
Financial results prior to the acquisition were not material.
In September 1996 Minnesota Power exchanged 473,006 shares of its common stock
for all the outstanding common stock of Alamo Auto Auction, Inc. and Alamo Auto
Auction Houston, Inc. These acquisitions were accounted for as pooling of
interests. Financial results prior to the acquisitions were not material.
SALE OF WATER PLANT ASSETS. In December 1997 Florida Water sold water and
wastewater assets to Orange County in Florida for $13.1 million. The facilities
served about 4,000 customers. The transaction resulted in a $4.7 million
after-tax gain which was included in the Company's 1997 earnings.
In March 1996 Heater of Seabrook, Inc., a wholly owned subsidiary of Heater,
sold all of its water and wastewater utility assets to the Town of Seabrook
Island, South Carolina for $5.9 million. This sale was negotiated in
anticipation of an eminent domain action by the Town of Seabrook Island, South
Carolina. In December 1996 Heater sold its Columbia, South Carolina area water
systems to South Carolina Water and Sewer, L.L.C. The Seabrook and Columbia
systems served a total of 6,500 customers. The transactions resulted in a $1
million after-tax gain which was included in the Company's 1996 earnings.
minnesota power, inc. 45
<PAGE>
5 JOINTLY OWNED ELECTRIC FACILITY
The Company owns 80% of the 535 megawatt Boswell Energy Center Unit 4 (Boswell
Unit 4). While the Company operates the plant, certain decisions with respect to
the operations of Boswell Unit 4 are subject to the oversight of a committee on
which the Company and Wisconsin Public Power, Inc. (WPPI), the owner of the
other 20% of Boswell Unit 4, have equal representation and voting rights. Each
owner must provide its own financing and is obligated to pay its ownership share
of operating costs. The Company's share of direct operating expenses of Boswell
Unit 4 is included in operating expense on the consolidated statement of income.
The Company's 80% share of the original cost included in electric plant at
December 31, 1998 was $304 million ($305 million at December 31, 1997). The
corresponding provision for accumulated depreciation was $143 million ($136
million at December 31, 1997).
6 FINANCIAL INSTRUMENTS
SECURITIES INVESTMENTS. Securities investments are managed by selected outside
managers as well as internal managers. Investments held principally for
near-term sale are classified as trading securities and included in current
assets at fair value. Changes in the fair value of trading securities are
recognized in earnings. Trading securities consist primarily of the common stock
of publicly traded companies, with utilities being the largest industry sector.
Investments held for an indefinite period of time are classified as
available-for-sale securities and included in plant and investments, or other
current assets at fair value. Unrealized gains and losses on available-for-sale
securities are included in accumulated other comprehensive income, net of tax.
Unrealized losses on available-for-sale securities that are other than temporary
are recognized in earnings. Realized gains and losses are computed on each
specific investment sold. Available-for-sale securities consist primarily of the
preferred stock of utilities and financial institutions with investment grade
debt ratings.
Available-For-Sale Securities
- --------------------------------------------------------------------------------
Millions
At December 31 Year Ended December 31
----------------------------- -----------------------------------------
Net Unrealized
Gain (Loss)
Gross Unrealized Gross Realized in Other
---------------- Fair Sales -------------- Comprehensive
Cost Gain (Loss) Value Proceeds Gain (Loss) Income
----- ---- ------ ----- -------- ---- ------ --------------
1998 $70.9 $7.7 $(5.1) $73.5 $35.7 $1.7 $(2.3) $1.3
1997 $60.5 $4.3 $(3.5) $61.3 $47.7 $0.7 $(1.4) $0.2
1996 $68.0 $1.9 $(2.1) $67.8 $43.1 $0.9 $(1.4) $1.0
- --------------------------------------------------------------------------------
Capital Re had unrealized gains from securities classified as
available-for-sale, and the Company's share, net of tax, was $5.5 million at
December 31, 1998 ($5.0 million at December 31, 1997). The unrealized gains from
Capital Re are recorded in accumulated other comprehensive income.
The net unrealized loss included in earnings for trading securities in 1998
was $0.7 million ($2 million gain in 1997; $0.9 million gain in 1996).
OFF-BALANCE-SHEET FINANCIAL INSTRUMENTS AND RISKS. In portfolio strategies
designed to reduce market risks, the Company sells common stock securities short
and enters into short sales of treasury futures contracts. Selling common stock
securities short is intended to reduce market price risks associated with
securities in the Company's trading securities portfolio. Realized and
unrealized gains and losses from short sales of common stock securities are
included in investment income. Treasury futures are used as a hedge to reduce
interest rate risks associated with holding fixed dividend preferred stocks
included in the Company's available-for-sale portfolio. Changes in market values
of treasury futures are recognized as an adjustment to the carrying amount of
the underlying hedged item. Gains and losses on treasury futures are deferred
and recognized in investment income concurrently with gains and losses arising
from the underlying hedged item. Generally, treasury futures contracts entered
into have a maturity date of 90 days.
In December 1998 Florida Water entered into a new interest rate swap agreement
with a notional amount of $35.1 million to hedge its fixed rate long-term debt.
Under the new ten-year agreement, Florida Water makes quarterly payments at a
variable rate based upon The Bond Market Association Municipal Swap Index weekly
floating average plus 58 basis points (3.4% at December 31, 1998) and receives
payments based on a fixed rate of 4.79%. This agreement is subject to market
risk due to interest rate fluctuation.
46 minnesota power, inc.
<PAGE>
The notional amounts summarized below do not represent amounts exchanged and are
not a measure of the Company's financial exposure. The amounts exchanged are
calculated on the basis of these notional amounts and other terms which relate
to the change in interest rates or securities prices. The Company continually
evaluates the credit standing of counterparties and market conditions, and does
not expect any material adverse impact to its financial position from these
financial instruments.
Off-Balance-Sheet Financial Instruments
December 31 1998 1997
- --------------------------------------------------------------------------------
Millions
Fair Value Fair Value
Notional Benefit Notional Benefit
Amount (Obligation) Amount (Obligation)
-------- ------------ -------- ------------
Short Stock Sales Outstanding $74.4 $(3.8) $54.0 $(2.7)
Treasury Futures $25.0 $ 0.5 $27.1 $(0.4)
Interest Rate Swap $35.1 $(0.4) $30.0 $(0.2)
- --------------------------------------------------------------------------------
FAIR VALUE OF FINANCIAL INSTRUMENTS. With the exception of the items listed
below, the estimated fair values of all financial instruments approximate the
carrying amount. The fair values for the items below were based on quoted market
prices for the same or similar instruments.
Financial Instruments
December 31 1998 1997
- --------------------------------------------------------------------------------
Millions
Carrying Fair Carrying Fair
Amount Value Amount Value
-------- ------ -------- ------
Long-Term Debt $672.2 $717.3 $685.4 $707.4
Redeemable Serial Preferred Stock $20.0 $21.3 $20.0 $21.5
Quarterly Income Preferred Securities $75.0 $76.1 $75.0 $76.9
- --------------------------------------------------------------------------------
CONCENTRATION OF CREDIT RISK. Financial instruments that subject the Company to
concentrations of credit risk consist primarily of accounts receivable. The
Company sells electricity to about 15 customers in northern Minnesota's
taconite, pipeline, paper and wood products industries. At December 31, 1998 and
1997 receivables from these customers totaled approximately $9 million. The
Company does not obtain collateral to support utility receivables, but monitors
the credit standing of major customers.
7 SHORT-TERM BORROWINGS AND COMPENSATING BALANCES
The Company has bank lines of credit, which make financing available through
short-term bank loans and provide support for commercial paper. At December 31,
1998 the Company had bank lines of credit aggregating $74 million ($84 million
at December 31, 1997). At the end of 1998, $34 million was available for use
($84 million at December 31, 1997). At December 31, 1998 the Company had issued
commercial paper with a face value of $41 million ($130 million in 1997), with
liquidity provided by bank lines of credit and the Company's securities
portfolio.
Certain lines of credit require a commitment fee of 0.085%. Interest rates on
commercial paper and borrowings under the lines of credit ranged from 5.7% to
7.75% at December 31, 1998 (6.1% to 8.5% at December 31, 1997). The weighted
average interest rate on short-term borrowings at December 31, 1998 was 5.8%
(6.3% at December 31, 1997). The total amount of compensating balances at
December 31, 1998 and 1997, was immaterial.
minnesota power, inc. 47
<PAGE>
8 COMMON STOCK AND EARNINGS PER SHARE
The Articles of Incorporation, mortgage and preferred stock purchase agreements
of the Company contain provisions that, under certain circumstances, would
restrict the payment of common stock dividends. As of December 31, 1998 no
retained earnings were restricted as a result of these provisions.
Summary of Common Stock Shares Equity
- --------------------------------------------------------------------------------
Millions
Balance at December 31, 1995 31.5 $377.7
1996 Employee Stock Purchase Plan - 0.7
Dividend Reinvestment and Stock Purchase Plan 0.7 18.5
Other 0.6 (2.7)
---- ------
Balance at December 31, 1996 32.8 394.2
1997 Employee Stock Purchase Plan - 0.9
Dividend Reinvestment and Stock Purchase Plan 0.6 18.6
Other 0.2 2.3
---- ------
Balance at December 31, 1997 33.6 416.0
1998 Public Offering 2.1 89.9
Employee Stock Purchase Plan - 0.9
Dividend Reinvestment and Stock Purchase Plan 0.4 17.1
Other 0.1 5.1
---- ------
Balance December 31, 1998 36.2 $529.0
- --------------------------------------------------------------------------------
COMMON STOCK SPLIT. On January 15, 1999 the Board of Directors approved a
two-for-one Common Stock split. Subject to regulatory approval, the effective
date of the stock split will be March 2, 1999 to stockholders of record on
February 16, 1999. Pro forma basic earnings per share on a post-split basis
would have been $1.35 in 1998 ($1.24 in 1997; $1.14 in 1996).
COMMON STOCK ISSUANCE. In September 1998 2.1 million shares of the Company's
Common Stock were sold in a public offering at $43.75 per share. Total net
proceeds of approximately $89 million were used to repay outstanding commercial
paper, to fund strategic initiatives and for capital expenditures. Net proceeds
not immediately used for the above purposes were invested in the Company's
securities portfolio.
SHAREHOLDER RIGHTS PLAN. In 1996 the Board of Directors of the Company adopted a
rights plan (Rights Plan) pursuant to which it declared a dividend distribution
of one preferred share purchase right (Right) for each outstanding share of
common stock to shareholders of record at the close of business on July 24, 1996
(the Record Date) and authorized the issuance of one Right with respect to each
share of common stock that becomes outstanding between the Record Date and July
23, 2006, or such earlier time as the Rights are redeemed.
Each Right will be exercisable to purchase one one-hundredth of a share of
Junior Serial Preferred Stock A, without par value, at an exercise price of $90,
subject to adjustment, following a distribution date which shall be the earlier
to occur of (i) 10 days following a public announcement that a person or group
(Acquiring Person) has acquired, or obtained the right to acquire, beneficial
ownership of 15% or more of the outstanding shares of common stock (Stock
Acquisition Date) or (ii) 15 business days (or such later date as may be
determined by the Board of Directors prior to the time that any person becomes
an Acquiring Person) following the commencement of, or a public announcement of
an intention to make, a tender or exchange offer if, upon consummation thereof,
such person would meet the 15% threshold.
Subject to certain exempt transactions, in the event that the 15% threshold is
met, each holder of a Right (other than the Acquiring Person) will thereafter
have the right to receive, upon exercise at the then current exercise price of
the Right, common stock (or, in certain circumstances, cash, property or other
securities of the Company) having a value equal to two times the exercise price
of the Right. If, at any time following the Stock Acquisition Date, the Company
is acquired in a merger or other business combination transaction or 50% or more
of the Company's assets or earning power are sold, each Right will entitle the
holder (other than the Acquiring Person) to receive, upon exercise at the then
current exercise price of the Right, common stock of the acquiring or surviving
company having a value equal to two times the exercise price of the Right.
Certain stock acquisitions will also trigger a provision permitting the Board of
Directors to exchange each Right for one share of common stock.
The Rights are nonvoting and expire on July 23, 2006, unless redeemed by the
Company at a price of $.01 per Right at any time prior to the time a person
becomes an Acquiring Person. The Board of Directors has authorized the
reservation of one million shares of Junior Serial Preferred Stock A for
issuance under the Rights Plan in the event of exercise of the Rights.
The exercise price and the number of shares of Junior Serial Preferred Stock A
issuable upon exercise of the Rights will be adjusted proportionately upon
completion of the pending two-for-one Common Stock split.
48 minnesota power, inc.
<PAGE>
EARNINGS PER SHARE. The difference between basic and diluted earnings per share
arises from outstanding stock options and performance share awards granted under
the Company's Executive and Director Long-Term Incentive Compensation Plans.
(See Note 17.)
Reconciliation of Basic and Diluted Basic Stock Performance Diluted
Earnings Per Share EPS Options Share Awards EPS
----------------------------------------------------------------------------
1998
Earnings Available for Common
Stock - Millions $86.5 - - $86.5
Common Shares - Millions 32.0 - 0.1 32.1
Per Share $2.70 - - $2.69
----------------------------------------------------------------------------
Stock options granted in January 1998 (0.2 million) were antidilutive and not
included in determining 1998 diluted earnings per share because the exercise
price exceeded the average market price of the Company's Common Stock in 1998.
There was no difference between basic and diluted earnings per share in 1997 and
1996. (See Note 17 for stock options granted in January 1999.)
9 INVESTMENT IN CAPITAL RE
The Company has a 21% equity investment in Capital Re, a New York Stock Exchange
listed company engaged in financial guaranty reinsurance and specialty
insurance. The Company uses the equity method to account for this investment.
Capital Re has not yet publicly released financial information for the year
ended December 31, 1998. As a result, financial information of Capital Re for
the nine months ended September 30, 1998 is included in the table below.
Minnesota Power's recorded equity income was based on an estimate of Capital
Re's earnings for the entire year.
Nine Months Ended Year Ended December 31
September 30 ----------------------
Capital Re Financial Information 1998 1997 1996
----------------------------------------------------------------------------
Millions
Capital Re
Investment Portfolio $1,132.3 $1,008.0 $901.1
Other Assets $338.3 $337.6 $255.3
Liabilities $369.8 $327.5 $255.0
Deferred Revenue $393.7 $402.1 $337.1
Net Revenue $181.8 $201.7 $144.9
Net Income $54.5 $70.1 $56.5
Year Ended December 31 1998 1997 1996
----------------------------------------------------------------------------
Minnesota Power's Interest
Equity in Earnings $15.1 $14.8 $11.8
Accumulated Equity in Undistributed
Earnings $81.4 $67.5 $53.7
Equity Investment $133.4 $118.8 $102.3
Fair Value of Investment $131.0 $202.6 $152.3
Equity Ownership 21% 21% 21%
----------------------------------------------------------------------------
Capital Re is the reinsurer of approximately $156 million in principal amount of
three issues of asset-backed securities issued by Commercial Financial Services
Inc. (CFS). At December 31, 1998 approximately $150 million principal amount of
the securities were outstanding. CFS is under investigation by the Securities
and Exchange Commission, and the Oklahoma Securities Commission for allegations
of irregularities relating to certain securities issued by CFS. Although CFS has
not missed any bond payments and the assets backing the securities reinsured by
Capital Re are currently performing according to expectations, the
irregularities make it difficult to estimate collection expectations for all
securities issued by CFS, including those reinsured by Capital Re. On December
11, 1998 CFS filed for Chapter 11 bankruptcy protection.
Capital Re is evaluating the CFS reinsurance contingency and is presently unable
to determine the likelihood or amount of possible loss, if any. The financial
information of Capital Re presented above and the Company's recorded equity in
Capital Re's 1998 earnings excludes any loss that may result from this
contingency. Capital Re has engaged outside consultants to review the loss
exposure and expects to complete its evaluation of the contingency in the first
quarter of 1999. The Company will record during the first quarter of 1999 its
share of any adjustment to Capital Re's 1998 earnings resulting from this
contingency.
minnesota power, inc. 49
<PAGE>
10 PREFERRED STOCK
<TABLE>
<CAPTION>
Preferred Stock
December 31 1998 1997
- -----------------------------------------------------------------------------------------------------------------
<S> <C> <C>
Millions
Cumulative Preferred Stock
Preferred Stock, $100 Par Value, 116,000 Shares Authorized;
5% Series - 113,358 Shares Outstanding, Callable at $102.50 Per Share $11.5 $11.5
----- -----
Redeemable Serial Preferred Stock
Serial Preferred Stock A, Without Par Value, 2,500,000 Shares Authorized;
$6.70 Series - 100,000 Shares Outstanding,
Mandatory Redemption 2002, Callable in 2000 at $100 Per Share $10.0 $10.0
$7.125 Series - 100,000 Shares Outstanding,
Mandatory Redemption 2002, Callable in 2000 at $100 Per Share 10.0 10.0
----- -----
Total Redeemable Serial Preferred Stock $20.0 $20.0
- -----------------------------------------------------------------------------------------------------------------
</TABLE>
11 SQUARE BUTTE POWER PURCHASE AGREEMENT
The Company has had a power purchase agreement with Square Butte since 1977 to
provide a long-term supply of low-cost energy to customers in the Company's
service territory and to meet power pool reserve requirements. Square Butte, a
North Dakota cooperative corporation, owns a 455-megawatt coal-fired generating
unit (Unit) near Center, North Dakota. The Unit is adjacent to a generating unit
owned by Minnkota Power Cooperative, Inc. (Minnkota), a North Dakota cooperative
corporation whose Class A members are also members of Square Butte. Minnkota
serves as the operator of the Unit and also purchases power from Square Butte.
In May 1998 the Company and Square Butte entered into a new power purchase
agreement (1998 Agreement), replacing the 1977 agreement. The Company extended
by 20 years, to January 1, 2027, its access to Square Butte's low-cost
electricity and eliminated its unconditional obligation for all of Square
Butte's costs if not paid by Square Butte when due. The 1998 Agreement was
reached in conjunction with the termination of Square Butte's previous leveraged
lease financing arrangement and refinancing of associated debt.
Similar to the previous agreement, the Company is initially entitled to
approximately 71% of the Unit's output under the 1998 Agreement. After 2005 and
upon compliance with a two-year advance notice requirement, Minnkota has the
option to reduce the Company's entitlement by 5% annually, to a minimum of 50%.
Under the 1998 Agreement, the Company is obligated to pay its pro rata share of
Square Butte's costs based on the Company's entitlement to Unit output. The
Company's payment obligation is suspended if Square Butte fails to deliver any
power, whether produced or purchased, for a period of one year. Under the 1977
agreement the Company was unconditionally obligated to pay all of Square Butte's
costs, if not paid by Square Butte when due. Square Butte's fixed costs consist
primarily of debt service. At December 31, 1998 Square Butte had total debt
outstanding of $351.4 million. Total annual debt service for Square Butte is
expected to be approximately $36 million in each of the years 1999 through 2002
and $23 million in 2003. Variable operating costs include the price of coal
purchased from BNI Coal, a subsidiary of Minnesota Power, under a long-term
contract.
The Company's cost of power purchased from Square Butte during 1998 was $58.2
million ($56.9 million in 1997; $58.2 million in 1996). This reflects the
Company's pro rata share of total Square Butte costs based on the 71% output
entitlement in 1998, 1997 and 1996. Included in this amount was the Company's
pro rata share of interest expense of $14.6 million ($12.4 million in 1997;
$13.2 million in 1996). The Company's payments to Square Butte are approved as
purchased power expense for ratemaking purposes by both the MPUC and FERC.
50 minnesota power, inc.
<PAGE>
12 LONG-TERM DEBT
Long-Term Debt
December 31 1998 1997
- --------------------------------------------------------------------------------
Millions
Minnesota Power
First Mortgage Bonds
6 1/4% Series Due 2003 $ 25.0 $ 25.0
6.68% Series Due 2007 20.0 20.0
7% Series Due 2007 60.0 60.0
7 1/2% Series Due 2007 35.0 35.0
7 3/4% Series Due 2007 55.0 55.0
7% Series Due 2008 50.0 50.0
6% Pollution Control Series E Due 2022 111.0 111.0
Variable Demand Revenue Refunding Bonds
Series 1997 A, B, C and D, Due 2007-2020 39.0 39.0
Pollution Control Revenue Bonds, 6.875%, Due 2002 4.8 4.8
Leveraged ESOP Loan, 9.125%, Due 1999-2004 10.2 11.3
Other Long-Term Debt, Variable, Due 2001-2013 7.4 7.3
Subsidiary Companies
First Mortgage Bonds, 8.46%, Due 2013 54.8 54.9
Senior Notes, Series A, 7.70%, Due 2006 90.0 90.0
Industrial Development Revenue Bonds, 6.50%, Due 2025 35.1 35.1
First Mortgage Bonds, 8.01%, Due 2017 28.0 28.0
Other Long-Term Debt, 6.1-8 7/8%, Due 1999-2026 55.9 63.7
Less Due Within One Year (9.0) (4.7)
------ ------
Total Long-Term Debt $672.2 $685.4
- --------------------------------------------------------------------------------
The aggregate amount of long-term debt maturing during 1999 is $9.0 million
($9.0 million in 2000; $13.6 million in 2001; $13.9 million in 2002; and $36.1
million in 2003). Substantially all Company electric and water plant is subject
to the lien of the mortgages securing various first mortgage bonds.
At December 31, 1998 subsidiaries of the Company had long-term bank lines of
credit aggregating $13.8 million ($20.0 million at December 31, 1997). Drawn
portions on these lines of credit aggregate $0 at December 31, 1998 ($4.5
million at December 31, 1997) and are included in subsidiary companies other
long-term debt.
13 LEASING AGREEMENTS
ADESA leases three auction facilities which have five year lease terms ending in
2000 with no renewal options. Beginning the fifth year of the lease ADESA has an
option to purchase the facilities at an aggregate price of $26.5 million. In the
event the purchase option is not exercised, ADESA has guaranteed any deficiency
in sales proceeds the lessor realizes in disposing of the leased properties
should the selling price fall below $25.7 million. ADESA is entitled to any
excess sales proceeds over the option price. ADESA has also guaranteed the
payment of principal and interest on the lessor's indebtedness which consists of
$25.7 million of 9.82% mortgage notes, due April 1, 2000.
The Company leases other properties and equipment in addition to those listed
above pursuant to operating and capital lease agreements with terms expiring
through 2009. The aggregate amount of future minimum lease payments for capital
and operating leases during 1999 is $17.9 million ($11.2 million in 2000; $7.6
million in 2001; $5.5 million in 2002; and $2.9 million in 2003). Total rent
expense was $15.6 million in 1998 ($10 million in 1997; $7.4 million in 1996).
minnesota power, inc. 51
<PAGE>
14 INCOME TAX EXPENSE
Income Tax Expense
Year Ended December 31 1998 1997 1996
- --------------------------------------------------------------------------------
Millions
Current Tax Expense
Federal $38.5 $31.9 $23.6
Foreign 4.9 3.2 2.8
State 9.8 10.0 6.1
----- ------ ------
53.2 45.1 32.5
----- ------ ------
Deferred Tax Expense (Benefit)
Federal 0.9 4.8 0.3
Foreign (0.4) (0.1) (1.1)
State (0.4) (1.5) (1.9)
----- ------ ------
0.1 3.2 (2.7)
----- ------ ------
Change in Valuation Allowance 2.3 (0.4) (8.2)
----- ------ ------
Deferred Tax Credits (1.6) (1.3) (2.0)
----- ------ ------
Total Income Tax Expense $54.0 $46.6 $19.6
- --------------------------------------------------------------------------------
Reconciliation of Taxes from Federal
Statutory Rate to Total Income
Tax Expense
Year Ended December 31 1998 1997 1996
- --------------------------------------------------------------------------------
Millions
Tax Computed at Federal Statutory Rate $49.8 $43.5 $31.1
Increase (Decrease) in Tax
State Income Taxes -
Net of Federal Income Tax Benefit 6.6 5.6 2.9
Change in Valuation Allowance 2.3 (0.4) (8.2)
Dividend Received Deduction (2.7) (2.0) (1.9)
Tax Credits (2.4) (2.2) (1.9)
Other 0.4 2.1 (2.4)
----- ------ ------
Total Income Tax Expense $54.0 $46.6 $19.6
- --------------------------------------------------------------------------------
Deferred Tax Assets and Liabilities
December 31 1998 1997
- --------------------------------------------------------------------------------
Millions
Deferred Tax Assets
Contributions in Aid of Construction $ 20.3 $ 19.8
Lehigh Basis Difference 9.7 15.3
Deferred Compensation Plans 18.9 15.6
Depreciation 13.0 12.9
Investment Tax Credits 20.8 22.2
Postemployment Benefits 7.8 6.4
Other 42.3 35.0
------ ------
Gross Deferred Tax Assets 132.8 127.2
Deferred Tax Asset Valuation Allowance (2.6) (0.3)
------ ------
Total Deferred Tax Assets 130.2 126.9
------ ------
Deferred Tax Liabilities
Depreciation 198.9 200.3
Allowance for Funds Used
During Construction 15.0 18.2
Income from Equity Investments 10.1 7.7
Investment Tax Credits 29.6 31.3
Other 30.0 20.7
------ ------
Total Deferred Tax Liabilities 283.6 278.2
------ ------
Accumulated Deferred Income Taxes $153.4 $151.3
- --------------------------------------------------------------------------------
52 minnesota power, inc.
<PAGE>
TAX BENEFITS. When SFAS 109 "Accounting for Income Taxes" was adopted in 1993,
the tax basis of assets owned by Lehigh Corporation exceeded the book basis.
Based upon management's best judgment at the time, the tax assets related to the
basis difference were reduced by a valuation reserve due to tax rules which
potentially limited the tax benefits available to the Company. Following the
Palm Coast real estate acquisition in 1996, management anticipated that
sufficient taxable income would exist to realize the Lehigh tax benefits despite
the restrictive tax rules. In 1996 the remaining valuation reserve of $8.2
million related to the Lehigh tax assets was reversed.
UNDISTRIBUTED EARNINGS. No provision has been made for taxes on $19.1 million of
pre-1993 undistributed earnings of Capital Re, an investment accounted for under
the equity method. Those earnings have been and are expected to continue to be
reinvested. The Company estimates that $7.9 million of tax would be payable on
the pre-1993 undistributed earnings of Capital Re if the Company should sell its
investment. The Company has recognized the income tax impact on undistributed
earnings of Capital Re earned since January 1, 1993.
Undistributed earnings of the Company's foreign subsidiaries were approximately
$9.7 million at December 31, 1998 ($6.6 million at December 31, 1997). Foreign
undistributed earnings are considered to be indefinitely reinvested, and,
accordingly, no provision for United States federal and state income taxes has
been provided thereon. Upon distribution of foreign undistributed earnings in
the form of dividends or otherwise, the Company would be subject to both United
States income tax (subject to an adjustment, for foreign tax credits) and
withholding taxes payable to Canada. Determination of the amount of unrecognized
deferred United States income tax liability is not practical due to the
complexities associated with its hypothetical calculations; however,
unrecognized foreign tax credit carryforwards would be available to reduce some
portion of the United States liability. Withholding taxes of approximately $0.5
million would be payable upon remittance of all previously unremitted earnings
at December 31, 1998 ($0.3 million at December 31, 1997).
15 OTHER COMPREHENSIVE INCOME
<TABLE>
<CAPTION>
Other Comprehensive Income Pre-Tax Tax Expense Net-of-Tax
Year Ended December 31 Amount (Benefit) Amount
- ---------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
Millions
1996
Unrealized Loss on Securities $(0.2) $0.3 $(0.5)
Foreign Currency Translation Adjustments 0.1 - 0.1
----- ---- -----
Other Comprehensive Loss $(0.1) $0.3 $(0.4)
----- ---- -----
1997
Unrealized Gain on Securities $ 3.6 $0.8 $ 2.8
Foreign Currency Translation Adjustments (1.7) - (1.7)
----- ---- -----
Other Comprehensive Income $ 1.9 $0.8 $ 1.1
----- ---- -----
1998
Unrealized Gain on Securities
Arising During the Year $ 1.9 $0.7 $ 1.2
Less: Gain (Loss) Recognized in Net Income (0.6) (0.2) (0.4)
----- ---- -----
Net Unrealized Gain 2.5 0.9 1.6
Foreign Currency Translation Adjustments (3.9) - (3.9)
----- ---- -----
Other Comprehensive Loss $(1.4) $0.9 $(2.3)
- ---------------------------------------------------------------------------------------------------------------------
</TABLE>
Accumulated other comprehensive income at December 31, 1998 consisted of $7.1
million ($5.5 million at December 31, 1997) in net unrealized gains on
securities and $(5.6) million ($(1.7) million at December 31, 1997) in foreign
currency translation adjustments.
minnesota power, inc. 53
<PAGE>
16 MANDATORILY REDEEMABLE PREFERRED SECURITIES OF SUBSIDIARY
MP&L Capital I (Trust) was established as a wholly owned business trust of the
Company for the purpose of issuing common and preferred securities (Trust
Securities). In March 1996 the Trust publicly issued three million 8.05%
Cumulative Quarterly Income Preferred Securities (QUIPS), representing preferred
beneficial interests in the assets held by the Trust. The proceeds from the sale
of the QUIPS, and from common securities of the Trust issued to the Company,
were used by the Trust to purchase from the Company $77.5 million of 8.05%
Junior Subordinated Debentures, Series A, Due 2015 (Subordinated Debentures),
resulting in net proceeds to the Company of $72.3 million. Holders of the QUIPS
are entitled to receive quarterly distributions at an annual rate of 8.05% of
the liquidation preference value of $25 per security. The Company has the right
to defer interest payments on the Subordinated Debentures which would result in
the similar deferral of distributions on the QUIPS during extension periods up
to 20 consecutive quarters. The Company is the owner of all the common trust
securities, which constitute approximately 3% of the aggregate liquidation
amount of all the Trust Securities. The sole asset of the Trust is Subordinated
Debentures, interest on which is deductible by the Company for income tax
purposes. The Trust will use interest payments received on the Subordinated
Debentures it holds to make the quarterly cash distributions on the QUIPS.
The QUIPS are subject to mandatory redemption upon repayment of the Subordinated
Debentures at maturity or upon redemption. The Company has the option to redeem
the Subordinated Debentures upon the occurrence of certain events and, in any
event, may do so at any time on or after March 20, 2001.
The Company has guaranteed, on a subordinated basis, payment of the Trust's
obligations.
17 EMPLOYEE STOCK AND INCENTIVE PLANS
EMPLOYEE STOCK OWNERSHIP PLAN. The Company sponsors an Employee Stock Ownership
Plan (ESOP) with two leveraged accounts.
A 1989 leveraged ESOP account covers all eligible nonunion Minnesota and
Wisconsin utility and corporate employees. The ESOP used the proceeds from a
$16.5 million loan (15 year term at 9.125%), guaranteed by the Company, to
purchase 600,000 shares of Company Common Stock on the open market. These shares
fund an annual benefit of not less than 2% of participants' salaries.
A 1990 leveraged ESOP account covers Minnesota and Wisconsin utility and
corporate employees who participated in the non-leveraged ESOP plan prior to
August 1989. In 1990 the ESOP issued a $75 million note (term not to exceed 25
years at 10.25%) to the Company as consideration for 2.8 million shares of newly
issued Common Stock. These shares are used to fund an annual benefit at least
equal to the value of (a) dividends on shares held in the 1990 leveraged ESOP
which are used to make loan payments, and (b) tax benefits obtained from
deducting eligible dividends.
The loans will be repaid with dividends received by the ESOP and with employer
contributions. ESOP shares acquired with the loans were initially pledged as
collateral for the loans. The ESOP shares are released from collateral and
allocated to participants based on the portion of total debt service paid in the
year. The ESOP shares that collateralize the loans are not included in the
number of average shares used to calculate basic and diluted earnings per share.
ESOP Compensation and Interest Expense
Year Ended December 31 1998 1997 1996
-----------------------------------------------------------------------------
Millions
Interest Expense $1.0 $1.1 $1.2
Compensation Expense 2.8 1.7 1.8
---- ---- ----
Total $3.8 $2.8 $3.0
-----------------------------------------------------------------------------
ESOP Shares
December 31 1998 1997
-----------------------------------------------------------------------------
Millions
Allocated Shares 1.8 1.8
Unreleased Shares 2.4 2.5
--- ---
Total ESOP Shares 4.2 4.3
-----------------------------------------------------------------------------
Fair Value of Unreleased Shares $104.0 $108.5
-----------------------------------------------------------------------------
54 minnesota power, inc.
<PAGE>
EMPLOYEE STOCK PURCHASE PLAN. The Company has an Employee Stock Purchase Plan
that permits eligible employees to buy up to $23,750 per year of Company Common
Stock at 95% of the market price. At December 31, 1998, 498,200 shares had been
issued under the plan and 145,900 shares were held in reserve for future
issuance.
STOCK OPTION AND AWARD PLANS. The Company has an Executive Long-Term Incentive
Compensation Plan (Executive Plan) and a Director Long-Term Stock Incentive Plan
(Director Plan), both of which became effective in January 1996. The Executive
Plan allows for the grant of up to 2.1 million shares of Common Stock to key
employees of the Company. The maximum number of shares of Common Stock available
for grant under the Executive Plan may be increased by the number of such shares
purchased on the open market. To date, these grants have taken the form of stock
options, performance share awards and restricted stock awards. The Director Plan
allows for the grant of up to 150,000 shares of Common Stock to nonemployee
directors of the Company. Each nonemployee director receives an annual grant of
725 stock options and a biennial grant of performance shares equal to $10,000 in
value of Common Stock at the date of grant.
Stock options are exercisable at the market price of common shares on the date
the options are granted, and vest in equal annual installments over two years
with expiration ten years from the date of grant. Performance shares are earned
over multi-year time periods and are contingent upon the attainment of certain
performance goals of the Company. Restricted stock vests once certain periods of
time have elapsed.
The Company has elected to account for its stock-based compensation plans in
accordance with APB Opinion No. 25 "Accounting for Stock Issued to Employees,"
and accordingly, compensation expense has not been recognized for stock options
granted. Compensation expense is recognized over the vesting periods for
performance and restricted share awards based on the market value of the
Company's Common Stock, and was approximately $3 million in 1998 ($4 million in
1997; $1 million in 1996). Pro forma net income and earnings per share under
SFAS No. 123 "Accounting for Stock-Based Compensation" have not been presented
because such amounts are not materially different from actual amounts reported.
This may not be representative of the pro forma effects for future years if
additional awards are granted.
<TABLE>
<CAPTION>
Stock Option Activity 1998 1997 1996
-------------------------------------------------------------------------------------------------------------
Average Average Average
Exercise Exercise Exercise
Options Price Options Price Options Price
-------- -------- ------- -------- ------- --------
<S> <C> <C> <C> <C> <C> <C>
Outstanding, Beginning of Year 333,700 $27.78 122,300 $28.63 - -
Granted 209,900 $43.25 237,900 $27.38 126,800 $28.63
Exercised (56,300) $27.90 (2,100) $28.63 - -
Canceled (3,300) $33.46 (24,400) $27.86 (4,500) $28.63
------- ------- -------
Outstanding, End of Year 484,000 $34.41 333,700 $27.78 122,300 $28.63
------- ------- -------
Exercisable, End of Year 180,500 $27.97 54,600 $28.63 - -
-------------------------------------------------------------------------------------------------------------
Fair Value of Options Granted
During the Year $10.29 $6.54 $6.76
-------------------------------------------------------------------------------------------------------------
</TABLE>
At December 31, 1998 the 484,000 options outstanding consist of 275,300 with an
exercise price of $27.38 to $28.63, and 208,700 with an exercise price of
$43.25. The options with an exercise price of $27.38 to $28.63 have an average
remaining contractual life of 7.7 years with 180,500 exercisable on December 31,
1998 at an average price of $27.97. The options with an exercise price of $43.25
have an average remaining contractual life of 9 years with none exercisable at
year end.
Performance Share Award Activity 1998 1997 1996
------------------------------------------------------------------------------
Number of Performance Share Awards Granted 93,000 33,700 96,900
Fair Value at Date of Grant - Millions $4.0 $0.9 $2.8
------------------------------------------------------------------------------
Performance share awards granted in 1996 and 1997 have been earned. A portion of
these shares was issued in 1998 with the balance to be issued in 1999 and 2000.
Awards granted in 1998 are contingent upon the attainment of certain future
Company performance goals.
A total of 4,000 shares of restricted stock was granted in 1998 (9,000 in 1997;
24,000 in 1996). In January 1999 the Company granted stock options to purchase
approximately 350,000 shares of Common Stock (exercise price of $43.88 per
share) and approximately 8,000 performance share awards.
minnesota power, inc. 55
<PAGE>
18 PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS
The Company's electric and corporate operations have noncontributory defined
benefit pension plans covering eligible employees. Benefits under a defined
benefit plan for Florida Water operations were frozen as of December 31, 1996
and a curtailment expense of $0.8 million was accrued in 1998 for future costs
associated with termination of the plan. This curtailment expense is not
included in pension expense below. At December 31, 1998 approximately 9% of the
defined benefit pension plan assets were invested in Company Common Stock. The
Company has defined contribution pension plans covering eligible employees, for
which the aggregate annual cost was $3.9 million ($3.2 million in 1997; $2.0
million in 1996). The Company provides certain health care and life insurance
benefits for retired employees in the electric, corporate and water operations.
The deferred regulatory charge for postretirement health and life benefits is
being amortized over five years ending in 1999.
Pension Health and Life
Actuarial Assumptions 1998 1997 1998 1997
-------------------------------------------------------------------------------
Discount Rate 6.75% 7.75% 6.75% 7.75%
Expected Return on Plan Assets 10.0% 9.0% 9.0% 9.0%
Rate of Compensation Increase 3.5-4.5% 4.0-8.0% 3.5-4.5% 4.0-8.0%
Health Care Cost Trend Rate - - 8.6% 9.4%
-------------------------------------------------------------------------------
The assumed health care cost trend rate declines gradually to a rate of 5.0% by
2002.
Plan Status Pension Health and Life
At September 30 1998 1997 1998 1997
------------------------------------------------------------------------------
Millions
Change in Benefit Obligation
Obligation, Beginning of Year $218.8 $205.5 $50.7 $ 53.3
Service Cost 4.1 3.6 2.3 2.6
Interest Cost 16.3 15.8 3.8 4.1
Actuarial Loss (Gain) 19.8 8.3 3.6 (7.8)
Participant Contributions - - 0.7 0.7
Benefits Paid (14.4) (14.4) (2.5) (2.2)
------ ------ ----- ------
Obligation, End of Year 244.6 218.8 58.6 50.7
------ ------ ----- ------
Change in Plan Assets
Fair Value, Beginning of Year 270.8 233.0 20.4 10.9
Actual Return on Assets 9.8 51.1 1.4 3.0
Employer Contribution - - 7.6 8.0
Participant Contributions - - 0.7 0.7
Benefits Paid (14.4) (14.4) (2.5) (2.2)
Other 1.3 1.1 - -
------ ------ ----- ------
Fair Value, End of Year 267.5 270.8 27.6 20.4
------ ------ ----- ------
Funded Status 22.9 52.0 (31.0) (30.3)
Unrecognized Amounts
Net Gain (31.4) (64.4) (18.8) (23.0)
Prior Service Cost 4.7 5.2 (3.8) (4.1)
Transition Obligation 1.2 1.4 37.3 40.0
Other - - - (1.1)
------ ------ ----- ------
Liability Recognized $ (2.6) $ (5.8) $(16.3) $(18.5)
------------------------------------------------------------------------------
56 minnesota power, inc.
<PAGE>
Benefit Expense
Year Ended December 31 1998 1997 1996
- --------------------------------------------------------------------------------
Millions
Pension Benefits
Service Cost $ 4.1 $ 3.6 $ 3.7
Interest Cost 16.3 15.8 15.1
Expected Return on Assets (23.2) (19.5) (18.5)
Amortized Amounts
Unrecognized Gain (1.1) (0.8) (0.3)
Prior Service Cost 0.5 0.6 0.7
Transition Obligation 0.2 0.2 0.2
----- ----- -----
(3.2) (0.1) 0.9
Early Retirement Expense 2.8 4.7 4.7
----- ----- -----
Net Expense (Credit) $(0.4) $ 4.6 $ 5.6
----- ----- -----
Postretirement Health and Life Benefits
Service Cost $ 2.3 $ 2.5 $ 2.7
Interest Cost 3.8 4.1 4.2
Expected Return on Assets (1.7) (1.3) (1.0)
Amortized Amounts
Unrecognized Gain (1.3) (0.6) -
Transition Obligation 2.3 2.6 2.5
----- ----- -----
5.4 7.3 8.4
Amortization of Deferred Charge 2.7 2.7 2.7
----- ----- -----
Net Expense $ 8.1 $10.0 $11.1
- --------------------------------------------------------------------------------
For postretirement health and life benefits, a 1% increase in the assumed health
care cost trend rate would result in a $6.9 million and $0.8 million increase in
the benefit obligation and total service and interest costs, respectively; a 1%
decrease would result in a $5.6 million and $0.8 million decrease in the benefit
obligation and total service and interest costs, respectively.
19 QUARTERLY FINANCIAL DATA (UNAUDITED)
Information for any one quarterly period is not necessarily indicative of the
results which may be expected for the year.
Quarter Ended Mar. 31 Jun. 30 Sept. 30 Dec. 31
-------------------------------------------------------------------------------
Millions Except Earnings Per Share
1998
Operating Revenue $246.6 $269.2 $266.3 $257.6
Operating Income $28.9 $43.1 $44.9 $31.6
Net Income $18.5 $22.8 $25.8 $21.4
Earnings Available for Common Stock $18.0 $22.3 $25.3 $20.9
Earnings Per Share of Common Stock
Basic $0.58 $0.71 $0.79 $0.62
Diluted $0.58 $0.71 $0.79 $0.61
-------------------------------------------------------------------------------
1997
Operating Revenue $222.1 $230.4 $246.2 $254.9
Operating Income $26.4 $32.8 $40.3 $30.7
Net Income $16.1 $18.7 $23.2 $19.6
Earnings Available for Common Stock $15.6 $18.2 $22.7 $19.1
Basic and Diluted Earnings Per Share
of Common Stock $0.52 $0.60 $0.73 $0.62
- -------------------------------------------------------------------------------
minnesota power, inc. 57
<PAGE>
REPORT OF INDEPENDENT ACCOUNTANTS [LOGO]
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 14, 1999 appearing on page 36 of this 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.
PricewaterhouseCoopers LLP
PricewaterhouseCoopers LLP
Minneapolis, Minnesota
January 14, 1999
58 minnesota power, inc.
<PAGE>
<TABLE>
MINNESOTA POWER SCHEDULE II
VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
<CAPTION>
Additions
Balance at --------------------- Deductions Balance at
Beginning Charged Other From End of
For the Year Ended December 31 of Year to Income Changes Reserves <F1> Period
- ----------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
Millions
Reserve Deducted From Related Assets
Reserve For Uncollectible Accounts
1998 Trade Accounts Receivable $5.1 $5.4 - $4.5 $6.0
Finance Receivables 2.8 2.8 - 2.0 3.6
1997 Trade Accounts Receivable 4.2 5.7 $0.2 5.0 5.1
Finance Receivables 2.5 0.8 - 0.5 2.8
1996 Trade Accounts Receivable 2.3 2.1 1.4 1.6 4.2
Finance Receivables 2.2 1.4 0.2 1.3 2.5
Deferred Asset Valuation Allowance
1998 Deferred Tax Assets 0.3 2.3 - - 2.6
1997 Deferred Tax Assets 0.7 (0.4) - - 0.3
1996 Deferred Tax Assets <F2> 8.9 (8.2) - - 0.7
- ----------------------------------------------------------------------------------------------------------------------------
<FN>
<F1> Reserve for uncollectible accounts includes bad debts written off.
<F2> The deferred tax asset valuation allowance was reduced by $8.2 million in
1996 based on anticipated taxable income following the 1996 acquisition of
Palm Coast real estate assets. (See Note 14.)
</FN>
</TABLE>
minnesota power, inc. 59
<PAGE>
EXHIBIT INDEX
Exhibit
Number
*2 - Agreement and Plan of Merger by and among the 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, amended and restated as of May 27, 1998
(filed as Exhibit 4(a) to Form 8-K dated June 3, 1998, File
No. 1-3548).
*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 effective May 27, 1998 (filed as Exhibit 4(b), to
Form 8-K dated June 3, 1998, File No. 1-3548).
*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:
Number Dated as of Reference 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)
Twentieth November 1, 1997 1-3548 (1997 Form 10-K) 4(a)3
*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).
<PAGE>
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 (filed as Exhibit 4(i) to Form
10-K for the year ended December 31, 1996, File No. 1-3548).
*4(j) - Rights Agreement dated as of July 24, 1996, between the Company and
the Corporate Secretary of the 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 the 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).
*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).
<PAGE>
Exhibit
Number
*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) - Power Purchase and Sale Agreement between the Company and Square
Butte Electric Cooperative, dated as of May 29, 1998 (filed as
Exhibit 10 to Form 10-Q for the quarter ended June 30, 1998, File No.
1-3548).
+*10(k) - 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(l) - 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(m) - 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).
+*10(n) - 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(o) - 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(p) - 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(q) - 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(r) - 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(s) - 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(t) - 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.
*21 - Subsidiaries of the Registrant (reference is made to the Company's
Form U-3A-2 for the year ended December 31, 1998, File No. 69-78).
23(a) - Consent of Independent Accountants.
23(b) - Consent of General Counsel.
27 - Financial Data Schedules.
- ----------------------------------------
* 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.
<PAGE>
<TABLE>
Exhibit 12
Minnesota Power, Inc.
Computation of Ratios of Earnings to Fixed Charges and
Supplemental Ratios of Earnings to Fixed Charges
<CAPTION>
For the Year Ended
----------------------------------------------------------------------
December 31,
----------------------------------------------------------------------
1994 1995 1996 1997 1998
------- ------- ------- ------- -------
(Millions except ratios)
<S> <C> <C> <C> <C> <C>
Income from Continuing Operations
Per Consolidated Statement of Income $ 59.5 $ 61.9 $ 69.2 $ 77.6 $ 88.5
Add (Deduct)
Current income tax expense 24.1 13.4 31.4 44.7 52.9
Deferred income tax expense (benefit) (1.0) (11.3) (9.8) 3.2 2.7
Deferred investment tax credits (2.5) (0.9) (2.0) (1.3) (1.6)
Undistributed income from less than
50% owned equity investments (7.5) (9.1) (11.0) (13.9) (14.1)
Minority interest (0.9) 0.2 3.3 2.3 2.0
------- ------- ------- ------- -------
71.7 54.2 81.1 112.6 130.4
------- ------- ------- ------- -------
Fixed charges
Interest on long-term debt 48.1 45.7 52.4 50.4 48.5
Capitalized interest - 1.4 1.5 1.5 1.0
Other interest charges - net 7.4 7.9 10.2 14.3 17.1
Interest component of all rentals 5.8 3.7 2.5 3.7 5.7
Distributions on redeemable
preferred securities of subsidiary - - 4.7 6.0 6.0
------- ------- ------- ------- -------
Total fixed charges 61.3 58.7 71.3 75.9 78.3
------- ------- ------- ------- -------
Earnings before income taxes and fixed
charges (excluding capitalized interest) $133.0 $111.5 $150.9 $187.0 $207.7
======= ======= ======= ======= =======
Ratio of earnings to fixed charges 2.17 1.90 2.12 2.46 2.65
======= ======= ======= ======= =======
Earnings before income taxes and fixed
charges (excluding capitalized interest) $133.0 $111.5 $150.9 $187.0 $207.7
Supplemental charges 14.4 13.5 14.4 12.0 14.5
------- ------- ------- ------- -------
Earnings before income taxes and fixed
and supplemental charges (excluding
capitalized interest) $147.4 $125.0 $165.3 $199.0 $222.2
======= ======= ======= ======= =======
Total fixed charges $ 61.3 $ 58.7 $ 71.3 $ 75.9 $ 78.3
Supplemental charges 14.4 13.5 14.4 12.0 14.5
------- ------- ------- ------- -------
Fixed and supplemental charges $ 75.7 $ 72.2 $ 85.7 $ 87.9 $ 92.8
======= ======= ======= ======= =======
Supplemental ratio of earnings to fixed
charges <F1> 1.95 1.73 1.93 2.26 2.39
======= ======= ======= ======= =======
- -------------------------
<FN>
<F1> The supplemental ratio of earnings to fixed charges includes the Company's
obligation under a contract with Square Butte Electric Cooperative (Square
Butte) which extends through 2027, pursuant to which the Company is
entitled to approximately 71% of the output of a 455-megawatt coal-fired
generating unit (Unit). The Company is obligated to pay its pro rata share
of Square Butte's costs based on Unit output entitlement. The Company's
payment obligation is suspended if Square Butte fails to deliver any power,
whether produced or purchased, for a period of one year. Square Butte's
fixed costs consist primarily of debt service. Variable operating costs
include the price of coal purchased from BNI Coal, a subsidiary of
Minnesota Power, under a long-term contract. (See Note 11.)
</FN>
</TABLE>
<PAGE>
Exhibit 23(a)
CONSENT OF INDEPENDENT ACCOUNTANTS
We hereby consent to the incorporation by reference in the Registration
Statements on Form S-8 (Nos. 33-51989, 333-26755, 333-16463, 333-16445) of
Minnesota Power, Inc. of our report dated January 14, 1999 appearing on page 36
of this Annual Report on Form 10-K. We also consent to the incorporation by
reference of our report on the Financial Statement Schedule, which appears on
page 58 of this Form 10-K.
We also consent to the incorporation by reference in the Prospectus constituting
part of the Registration Statement on Form S-3 (Nos. 33-45551, 333-07963,
333-02109, 333-40797, 333-52161, 333-58945) of Minnesota Power, Inc. of our
report dated January 14, 1999 appearing on page 36 of this Annual Report on Form
10-K. We also consent to the incorporation by reference of our report on the
Financial Statement Schedule, which appears on page 58 of this Form 10-K.
PricewaterhouseCoopers LLP
PRICEWATERHOUSECOOPERS LLP
Minneapolis, Minnesota
February 9, 1999
<PAGE>
Exhibit 23(b)
CONSENT OF GENERAL COUNSEL
The statements of law and legal conclusions under "Item 1. Business" in the
Company's Annual Report on Form 10-K for the year ended December 31, 1998 have
been reviewed by me and are set forth therein in reliance upon my opinion as an
expert.
I hereby consent to the incorporation by reference of such statements of law and
legal conclusions in Registration Statement Nos. 33-45551, 333-07963, 333-02109,
333-40797, 333-52161, and 333-58945 on Form S-3, and Registration Statement Nos.
33-51989, 333-26755, 333-16463 and 333-16445 on Form S-8.
Philip R. Halverson
Philip R. Halverson
Duluth, Minnesota
February 9, 1999
<TABLE> <S> <C>
<ARTICLE> UT
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM MINNESOTA
POWER'S CONSOLIDATED BALANCE SHEET, STATEMENT OF INCOME, AND STATEMENT OF CASH
FLOW FOR THE PERIOD ENDED DECEMBER 31, 1998, AND IS QUALIFIED IN ITS ENTIRETY BY
REFERENCE TO SUCH FINANCIAL STATEMENTS.
</LEGEND>
<MULTIPLIER> 1,000,000
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-START> JAN-01-1998
<PERIOD-END> DEC-31-1998
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 1,101
<OTHER-PROPERTY-AND-INVEST> 450
<TOTAL-CURRENT-ASSETS> 487
<TOTAL-DEFERRED-CHARGES> 56
<OTHER-ASSETS> 223
<TOTAL-ASSETS> 2,317
<COMMON> 529
<CAPITAL-SURPLUS-PAID-IN> 0
<RETAINED-EARNINGS> 318
<TOTAL-COMMON-STOCKHOLDERS-EQ> 785
95
12
<LONG-TERM-DEBT-NET> 672
<SHORT-TERM-NOTES> 81
<LONG-TERM-NOTES-PAYABLE> 0
<COMMERCIAL-PAPER-OBLIGATIONS> 0
<LONG-TERM-DEBT-CURRENT-PORT> 9
0
<CAPITAL-LEASE-OBLIGATIONS> 0
<LEASES-CURRENT> 0
<OTHER-ITEMS-CAPITAL-AND-LIAB> 601
<TOT-CAPITALIZATION-AND-LIAB> 2,317
<GROSS-OPERATING-REVENUE> 1,040
<INCOME-TAX-EXPENSE> 54
<OTHER-OPERATING-EXPENSES> 841
<TOTAL-OPERATING-EXPENSES> 906
<OPERATING-INCOME-LOSS> 149
<OTHER-INCOME-NET> 9 <F1>
<INCOME-BEFORE-INTEREST-EXPEN> 154
<TOTAL-INTEREST-EXPENSE> 65
<NET-INCOME> 89
2
<EARNINGS-AVAILABLE-FOR-COMM> 87
<COMMON-STOCK-DIVIDENDS> 65
<TOTAL-INTEREST-ON-BONDS> 47
<CASH-FLOW-OPERATIONS> 146
<EPS-PRIMARY> 2.70
<EPS-DILUTED> 2.69
<FN>
<F1>Includes $15 million of Income from Equity Investments and $6 million for
Distributions on Redeemable Preferred Securities of Subsidiary.
</FN>
</TABLE>
<TABLE> <S> <C>
<ARTICLE> UT
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM MINNESOTA
POWER'S CONSOLIDATED BALANCE SHEET, STATEMENT OF INCOME, AND STATEMENT OF CASH
FLOW FOR THE PERIOD ENDED DECEMBER 31, 1997, AND IS QUALIFIED IN ITS ENTIRETY BY
REFERENCE TO SUCH FINANCIAL STATEMENTS.
</LEGEND>
<RESTATED>
<MULTIPLIER> 1,000,000
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> DEC-31-1997
<PERIOD-START> JAN-01-1997
<PERIOD-END> DEC-31-1997
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 1,106
<OTHER-PROPERTY-AND-INVEST> 420
<TOTAL-CURRENT-ASSETS> 385
<TOTAL-DEFERRED-CHARGES> 64
<OTHER-ASSETS> 214
<TOTAL-ASSETS> 2,189
<COMMON> 416
<CAPITAL-SURPLUS-PAID-IN> 0
<RETAINED-EARNINGS> 296
<TOTAL-COMMON-STOCKHOLDERS-EQ> 650
95
12
<LONG-TERM-DEBT-NET> 685
<SHORT-TERM-NOTES> 129
<LONG-TERM-NOTES-PAYABLE> 0
<COMMERCIAL-PAPER-OBLIGATIONS> 0
<LONG-TERM-DEBT-CURRENT-PORT> 5
0
<CAPITAL-LEASE-OBLIGATIONS> 0
<LEASES-CURRENT> 0
<OTHER-ITEMS-CAPITAL-AND-LIAB> 551
<TOT-CAPITALIZATION-AND-LIAB> 2,189
<GROSS-OPERATING-REVENUE> 954
<INCOME-TAX-EXPENSE> 47
<OTHER-OPERATING-EXPENSES> 774
<TOTAL-OPERATING-EXPENSES> 838
<OPERATING-INCOME-LOSS> 130
<OTHER-INCOME-NET> 9 <F1>
<INCOME-BEFORE-INTEREST-EXPEN> 142
<TOTAL-INTEREST-EXPENSE> 64
<NET-INCOME> 78
2
<EARNINGS-AVAILABLE-FOR-COMM> 76
<COMMON-STOCK-DIVIDENDS> 63
<TOTAL-INTEREST-ON-BONDS> 49
<CASH-FLOW-OPERATIONS> 132
<EPS-PRIMARY> 2.47
<EPS-DILUTED> 2.47
<FN>
<F1>Includes $15 million of Income from Equity Investments and $6 million for
Distributions on Redeemable Preferred Securities of Subsidiary.
</FN>
</TABLE>
