<PAGE>
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, 1999
/ / 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 55802-2093
(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
------------------- ---------------------------
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 31,
2000 was $1,253,552,320.
As of January 31, 2000 there were 73,492,184 shares of Minnesota Power, Inc.
Common Stock, without par value, outstanding.
Documents Incorporated by Reference
Portions of the Proxy Statement for the 2000 Annual Meeting of Shareholders are
incorporated by reference in Part III.
Minnesota Power, Inc.
<PAGE>
TABLE OF CONTENTS
PART I PAGE
Item 1. Business 1
Electric Services 2
Electric Sales 3
Purchased Power and Capacity Sales 5
Fuel 6
Regulatory Issues 6
Competition 9
Franchises 10
Environmental Matters 10
Automotive Services 12
Competition 13
Environmental Matters 14
Water Services 14
Regulatory Issues 14
Competition 15
Franchises 15
Environmental Matters 15
Investments 16
Environmental Matters 16
Executive Officers of the Registrant 17
Item 2. Properties 18
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 19
Item 6. Selected Financial Data 20
Item 7. Management's Discussion and Analysis of Financial Condition
and Results of Operations 22
Consolidated Overview 22
1999 Compared to 1998 23
1998 Compared to 1997 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 28
Item 8. Financial Statements and Supplementary Data 28
Item 9. Changes in and Disagreements with Accountants on Accounting
and Financial Disclosure 28
PART III
Item 10. Directors and Executive Officers of the Registrant 29
Item 11. Executive Compensation 29
Item 12. Security Ownership of Certain Beneficial Owners
and Management 29
Item 13. Certain Relationships and Related Transactions 29
PART IV
Item 14. Exhibits, Financial Statement Schedules and Reports
on Form 8-K 30
SIGNATURES 34
CONSOLIDATED FINANCIAL STATEMENTS 35
i Minnesota Power, Inc.
<PAGE>
DEFINITIONS
The following abbreviations or acronyms are used in the text.
Abbreviation or Acronym Term
----------------------- --------------------------------------------------
ACE ACE Limited
ADESA ADESA Corporation
ADT ADT Automotive, Inc.
AFC Automotive Finance Corporation
Americas' Water Americas' Water Services Corporation
AutoVIN AutoVIN, Inc.
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
DOC Minnesota Department of Commerce
DRIP Dividend Reinvestment and Stock Purchase Plan
EPA Environmental Protection Agency
ESOP Employee Stock Ownership Plan
FERC Federal Energy Regulatory Commission
Florida Water Florida Water Services Corporation
Form 10-K Minnesota Power's Annual Report on Form 10-K
Form 10-Q Minnesota Power's Quarterly Report on Form 10-Q
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
LS Power LS Power, LLC
Manheim Manheim Auctions, Inc.
MAPP Mid-Continent Area Power Pool
MBtu Million British thermal units
Mid South Mid South Water Systems, Inc.
Minnesota Power Minnesota Power, Inc. and its Subsidiaries
Minnkota Power Minnkota Power Cooperative, Inc.
MP Telecom Minnesota Power Telecom, Inc.
MPCA Minnesota Pollution Control Agency
MPUC Minnesota Public Utilities Commission
MW Megawatt(s)
MWh Megawatthour(s)
NCUC North Carolina Utilities Commission
NDDH North Dakota Department of Health
Note___ Note___ to the consolidated financial statements
indexed in Item 14(a) of this Form 10-K
NPDES National Pollutant Discharge Elimination System
Palm Coast Palm Coast Holdings, Inc.
PAR PAR, Inc.
PCUC Palm Coast Utility Corporation
PSCW Public Service Commission of Wisconsin
Rainy River Rainy River Energy Corporation
SFAS Statement of Financial Accounting Standards No.
Square Butte Square Butte Electric Cooperative
SWL&P Superior Water, Light and Power Company
VCS Vibration Correction Services, Inc.
WPPI Wisconsin Public Power, Inc.
Minnesota Power, Inc. ii
<PAGE>
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 Congress, state legislatures, the FERC, the MPUC, the FPSC, the NCUC
and the PSCW, with respect to allowed rates of return, industry and rate
structure, acquisition and disposal of assets and facilities, operation
and construction of plant facilities, recovery of purchased power, and
present or prospective wholesale and retail competition (including but
not limited to retail wheeling and transmission costs);
- economic and geographic factors including political and economic risks;
- changes in and compliance with environmental and safety laws and
policies;
- weather conditions;
- population growth rates and demographic patterns;
- competition for retail and wholesale customers;
- pricing and transportation of commodities;
- market demand, including structural market changes;
- changes in tax rates or policies or in rates of inflation;
- changes in project costs;
- unanticipated changes in operating expenses and capital expenditures;
- capital market conditions;
- competition for new energy development opportunities; and
- legal and administrative proceedings (whether civil or criminal) and
settlements that influence the business and profitability of the Company.
Any forward-looking statement speaks only as of the date on which such statement
is made, and the Company undertakes no obligation to update any forward-looking
statement to reflect events or circumstances after the date on which such
statement is made or to reflect the occurrence of unanticipated events. New
factors emerge from time to time and it is not possible for management to
predict all of such factors, nor can it assess the impact of any such factor on
the business or the extent to which any factor, or combination of factors, may
cause results to differ materially from those contained in any forward-looking
statement.
iii Minnesota Power, Inc.
<PAGE>
PART I
ITEM 1. BUSINESS
Minnesota Power, Inc., a multi-services company incorporated under the laws of
the State of Minnesota in 1906, has operations in four business segments: (1)
Electric Services, which include electric and gas services, coal mining and
telecommunications; (2) Automotive Services, which include a network of vehicle
auctions, a finance company, an auto transport company, a vehicle remarketing
company and a company that provides field information services; (3) Water
Services, which include water and wastewater services and (4) Investments, which
include a securities portfolio, 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, 1999 the Company and its subsidiaries had approximately 8,000 employees,
2,000 of which were not full time.
Since the inception of the 1996 corporate strategic plan, the Company has
pursued and will continue to pursue a course of expanding its existing business
segments. Acquisitions have been and will continue to be a primary means of
expansion. In 1999 Electric Services announced plans to: (1) form an alliance
with Great River Energy to combine power supply assets and customer loads for
power pool operations; (2) construct in partnership with Wisconsin Public
Service Corporation a 250-mile, 345-kilovolt transmission line from Wausau,
Wisconsin, to Duluth, Minnesota; and (3) build a 90-MW natural gas-fired power
plant near the city of Superior, Wisconsin. Also in 1999, Rainy River entered
into a 15-year, 275-MW power purchase agreement with a subsidiary of LS Power
which is expected to begin in 2002. MP Telecom announced it is expanding its
network through construction of a 208-mile fiber optic route into southern
Minnesota. Automotive Services acquired two new vehicle auction facilities, one
in Des Moines, Iowa, and one in Vancouver, British Columbia. Two additional
vehicle auction facilities are in the process of being built, one in Calgary,
Alberta, and the other near Los Angeles, California. A third vehicle auction
facility in Concord, Massachusetts, is being remodeled and reopened. Automotive
Services also acquired AutoVIN, the Automated Vehicle Information Network, which
is a provider of field information services to the automotive industry. Water
Services acquired PCUC in Florida and Mid South in North Carolina. Within the
Investments segment the Company exchanged its investment in Capital Re for
shares of ACE and, through a subsidiary, purchased real estate property in Cape
Coral, Florida.
Year Ended December 31 1999 1998 1997
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Consolidated Operating Revenue - Millions $1,131.8 $1,039.3 $953.6
Percentage of Consolidated Operating Revenue
Electric Services
Retail
Industrial
Taconite Producers 13% 16% 17%
Paper and Pulp Mills 5 6 7
Pipelines and Other Industries 3 3 4
--- --- ---
Total Industrial 21 25 28
Residential 6 6 7
Commercial 6 6 6
Sales to Other Power Suppliers 9 8 7
Other Revenue 7 9 9
--- --- ---
Total Electric Services 49 54 57
Automotive Services 36 32 27
Water Services 10 9 10
Investments 5 5 6
--- --- ---
100% 100% 100%
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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.
Minnesota Power, Inc. 1
<PAGE>
ELECTRIC SERVICES
Electric Services generate, transmit, distribute and market electricity. In
addition Electric Services include coal mining, telecommunications, engineering,
operating and maintenance services, and economic development projects in and
near the Company's service area. Electric Services 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, 1999 Minnesota
Power was supplying retail electric service to 126,000 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 16 municipal distribution systems and one
private utility. In addition, Minnesota Power provides wholesale electric
service to its wholly owned subsidiary, SUPERIOR WATER, LIGHT AND POWER COMPANY,
which sells electricity and natural gas, and provides water service in
northwestern Wisconsin. As of December 31, 1999 SWL&P served 14,000 electric
customers, 11,000 natural gas customers and 10,000 water customers. MPEX, a
division of Minnesota Power, is an expansion of the Company's inter-utility
marketing group which has been a buyer and seller of capacity and energy for
over 25 years in the wholesale power market. The customers of MPEX are other
power suppliers in the Midwest and Canada. MPEX also contracts with its
customers to provide hourly energy scheduling and power trading services. MPEX
leases an office located in Minneapolis, Minnesota.
The Company had an annual net peak load of 1,411 MW on January 11, 1999.
Information with respect to existing power supply sources is shown below.
Unit Year Net Winter Net Electric
1999 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 353
4 1980 429
-----
920 5,554,707 47.2%
-----
Laskin Energy Center
Hoyt Lakes, MN 1 1953 55
2 1953 55
-----
110 570,635 4.8
-----
Purchased Steam
M.L. Hibbard
Duluth, MN 3 & 4 1949, 1951 53 20,953 0.2
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Total Steam 1,083 6,146,295 52.2
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Hydro
Group consisting of ten
stations in MN Various 115 730,211 6.2
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Purchased Power
Square Butte burns
lignite in Center, ND 322 2,326,259 19.8
All other - net - 2,561,511 21.8
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Total Purchased Power 322 4,887,770 41.6
----- ---------- -----
Total 1,520 11,764,276 100.0%
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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
(1,258 miles) and less than 115 kV (6,323 miles). The Company owns and operates
177 substations with a total capacity of 8,531 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
Services.
2 Minnesota Power, Inc.
<PAGE>
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.
BNI COAL, a wholly owned subsidiary of Minnesota Power, 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 5.) 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 between 2000
and 2008. All other property and equipment is owned by BNI Coal.
ELECTRIC OUTLET, INC., a wholly owned subsidiary of Minnesota Power, is a retail
store, catalog and e-commerce merchandiser that sells lifestyle-changing
electric products. The Electric Outlet established alliances with ten other
utilities to market products with the Electric Outlet through either a catalog
and/or the Internet CyberStore. The Electric Outlet continues to pursue
alliances with other utilities.
MINNESOTA POWER TELECOM, INC., a wholly owned subsidiary of Minnesota Power,
provides high capacity fiber optic based communication services to businesses
and communities across Minnesota and in Wisconsin. MP Telecom customers include
wireless providers, competitive local exchange carriers, common carriers and
larger bandwidth users such as universities, medical facilities and
technology-based businesses. In addition, MP Telecom operates a commercial
Internet service provider business. In 1999 Murphy McGinnis Interactive, a
subsidiary of Murphy McGinnis Media, and MP Telecom announced the formation of
an alliance to provide residential Internet access to northeastern Minnesota and
northwestern Wisconsin. The relationship will complement MP Telecom's existing
Internet and data management service offerings to large business and commercial
accounts.
MP Telecom owns or has rights on approximately 1,000 route miles of fiber optic
communications. These route miles contain multiple fibers giving MP Telecom a
total of approximately 38,000 fiber miles. MP Telecom also owns considerable
optronic equipment that is used to `light up' the fiber optic cable and provide
customer bandwidth services. Most of the locations from which MP Telecom
services customers are leased from third parties.
RAINY RIVER ENERGY CORPORATION, a wholly owned subsidiary of Minnesota Power,
holds ownership and power purchase positions in merchant generation, as well as
provides engineering, and operating and maintenance services to new and existing
generating facilities.
UPPER MINNESOTA PROPERTIES, INC., a wholly owned subsidiary of Minnesota Power,
has invested in affordable housing projects located in the Company's service
territory. This is one of a variety of economic development projects which the
Company participates in throughout the Electric Services 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 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.)
Approximately 80% of the ore consumed by integrated steel facilities in the
Great Lakes region originates from five taconite customers of Minnesota Power.
Taconite, an iron-bearing rock of relatively low iron content that 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 43
million tons in 1999 (46 million tons in 1998; 47 million tons in 1997). Based
on the Company's research of the taconite industry, Minnesota taconite
production for 2000 is anticipated to be above the 1999 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.
Minnesota Power, Inc. 3
<PAGE>
Steel imports continue to depress steel prices and is the critical issue facing
the American steel industry which includes the taconite industry. Total imports
for the 11 months ended November 30, 1999 were 12% higher than the same period
in 1997, the last record year prior to the unprecedented import surge of 1998.
Steel imports are in large part the result of global overcapacity. Prices for
1999 continued to be nearly 25% lower compared to the same period in 1998. In
1998 the United States imported a record 42 million tons of steel, which
represented an 83% increase over the 23 million-ton average for each of the
previous eight years (1990-1997).
Domestic production of steel for the ten months ended October 31, 1999 was
approximately 87 million net tons, down slightly for the same period in 1998.
Capacity utilization for the industry during that same period was 82.6%, down
from 88.2% for the same period in 1998. The continued lower worldwide demand for
steel produced in the United States is having an adverse affect on northern
Minnesota's taconite producers and the economy of northern Minnesota in general.
Steel markets in Asia, however, are showing signs of a recovery. A strengthening
global market coupled with continued strong domestic demand for steel may begin
to bring global supply and demand into better balance. The Company is unable to
predict the eventual impact of this problem on the Company's Electric Services.
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 megawatts subject to a demand charge on a periodic (power
pool season) basis and require that a portion of their megawatt 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 any electric service requirements from the Company for the duration of
their contracts. The rates and corresponding revenue associated with capacity
and energy provided under these contracts are subject to change through the same
regulatory process governing all retail electric rates. Minnesota Power'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.)
Minimum Revenue and Demand Under Contract
As of February 1, 2000
--------------------------------------------------------------------------
Minimum Monthly
Annual Revenue Megawatts
-------------- ---------
2000 $76.5 million 523
2001 $68.7 million 473
2002 $58.3 million 405
2003 $51.4 million 354
2004 $46.1 million 322
--------------------------------------------------------------------------
Based on projected operating levels, the Company believes revenue from
Large Power Customers will be substantially in excess of the minimum
contract amounts.
4 Minnesota Power, Inc.
<PAGE>
<TABLE>
Contract Status for Minnesota Power Large Power Customers
As of February 1, 2000
-------------------------------------------------------------------------------------------------------------------
<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 Company Virginia, MN Ispat Inland Steel Company December 31, 2007
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, 2006
Boise Cascade Corp. International Falls, MN Boise Cascade Corp. December 31, 2002
Lake Superior Paper Industries and Duluth, MN Consolidated Papers, Inc. July 31, 2008
Superior Recycled Fiber Industries
Potlatch Corp. Cloquet, MN Potlatch Corp. December 31, 2004
Brainerd, MN
Lakehead Pipe Line Co. L.P. Deer River, MN Lakehead Pipe Line May 31, 2001
Floodwood, MN Partners, L.P.
Minnesota Pipeline Company Staples, MN 60% Koch Pipeline Co. L.P. September 30, 2002
Little Falls, MN 40% Marathon Ashland
Park Rapids, MN Petroleum LLC
--------------------------------------------------------------------------------------------------------------------------
</TABLE>
PURCHASED POWER AND CAPACITY SALES
The Company 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 risk
management policy, 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. The largest contract is one with Square Butte. 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 5.) Another
purchased power contract with LTV Steel Mining Co. for 75 MW extends until
October 31, 2005. The Company has entered into various smaller purchased power
contracts for the purposes of meeting its capacity needs or marketing power.
Participation power purchase contracts require the Company to pay the demand
charges for generating capacity under contract and an energy charge for each
megawatthour 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.
On September 9, 1999 Rainy River entered into a second amended and restated
15-year power purchase agreement, with a subsidiary of LS Power, a privately
owned independent power producer. Under the agreement, Rainy River will be
provided the full output of one complete unit (approximately 275 MW) of a four
unit (approximately 1,100 MW) project. The natural gas-fired combined cycle
generation facility to be built, owned and operated by LS Power is near Chicago,
Illinois. Construction of the generation facility is scheduled to begin in 2000
with commercial operation expected in May 2002. The Company expects the
agreement will enhance its ability to serve an expanding customer base outside
of the MAPP region, as well as enable additional participation in the wholesale
bulk power marketplace.
Generally, there will be a charge for both capacity made available and energy
delivered by LS Power. Rainy River will be obligated to pay the capacity related
charge as long as capacity is made available. The capacity related charge will
be reduced if capacity is not available and replacement power is not provided.
Rainy River will be responsible for the purchase and transportation of natural
gas. Rainy River will incur no significant charges until the facility commences
operations.
Rainy River can terminate the LS Power agreement under certain circumstances,
including prolonged construction delays or facility outages.
Minnesota Power, Inc. 5
<PAGE>
CAPACITY SALES. Minnesota Power currently has approximately 300 MW under
contract to sell capacity to nonaffiliated utility companies. The Company also
has entered into various smaller capacity sales contracts for the purposes of
selling surplus capacity or marketing power. Participation power sales contracts
require the purchasing utility to pay the demand charges for megawatts under
contract and an energy charge for each megawatthour 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.
Firm power sales contracts require the purchasing utility to pay the demand
charges for megawatts under contract and an energy charge for each megawatthour
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 1999 was
about 4 million tons. As of December 31, 1999 the Company had a coal inventory
of about 400,000 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 2000 under these agreements and the spot market. This mix of
coal supply options allows the Company to reduce market risk and to take
advantage of favorable spot market prices. The Company is exploring future coal
supply options and believes that adequate supplies of low-sulfur, sub-bituminous
coal will continue to be available.
Burlington Northern Santa Fe Railroad transports 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 2003 to Laskin via a Duluth
Missabe & Iron Range Railway interchange.
Coal Delivered to Minnesota Power
Year Ended December 31 1999 1998 1997
----------------------------------------------------------------------------
Average Price Per Ton $20.60 $20.37 $20.26
Average Price Per MBtu $1.14 $1.12 $1.11
----------------------------------------------------------------------------
The Square Butte generating unit operated by Minnkota Power burns North Dakota
lignite supplied by BNI Coal, pursuant to the terms of a contract expiring in
2027. Square Butte's cost of lignite burned in 1999 was approximately 63 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 Note 5.) BNI Coal has experienced no difficulty in supplying
all of Square Butte's lignite requirements.
REGULATORY ISSUES
The Company and its subsidiaries are exempt from regulation under the Public
Utility Holding Company Act of 1935, except as to Section 9(a)(2) which relates
to acquisition of securities of public utility operations.
The Company and its subsidiaries are subject to the jurisdiction of various
regulatory authorities. The MPUC has regulatory authority over Electric Services
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 31%, 4% and 4%, respectively, of the Company's
1999 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.)
6 Minnesota Power, Inc.
<PAGE>
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 MW 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 and other contract terms are subject to
approval by appropriate regulatory authorities.
FEDERAL ENERGY REGULATORY COMMISSION. The FERC has jurisdiction over the
Company's wholesale electric service and transmission (wheeling) service.
The Company has long-term contracts with 16 Minnesota municipalities receiving
wholesale electric service. Four contracts are for service through 2002 and
2004, while the other 12 are for service through at least 2007. The contracts
limit rate increases (including fuel costs) to about 2% per year on a cumulative
basis. In 1999 municipal customers purchased 656,565 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 547,181 MWh from the Company in 1999.
The Company also has a contract through 2010 to supply electricity to Dahlberg
Light and Power Company (Dahlberg), a private utility. Dahlberg purchased 92,414
MWh from the Company in 1999.
The Company's hydroelectric facilities, which are located in Minnesota, are
licensed by the FERC. (See Environmental Matters - Water.)
Minnesota Power is a member of 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 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. Under the MAPP Restated Agreement, any member who
elects to withdraw from MAPP must first provide a 3-year notice of their intent
to do so.
As expected, in December 1999, the FERC approved a landmark order strongly
encouraging transmission-owning utilities to participate in large regional
transmission organizations (RTOs) that would be independent participants in
wholesale power markets. In order to induce utility participation in RTOs that
have the minimum characteristics and perform the functions specified by the
FERC, the FERC stated that utilities that agree to transfer operational control
over their transmission facilities to such RTOs may be eligible for financial
incentives such as innovative transmission rate treatment. Unless a utility has
previously filed an application with the FERC to transfer operational control of
its transmission facilities to an approved transmission entity, it will be
required to file at the FERC no later than October 15, 2000 either a proposal to
participate in an RTO or a description of efforts that the utility has made to
participate in an RTO and an explanation of the reasons why that utility has not
filed an application with the FERC.
In December 1999 MAPP and the Midwest ISO (MISO) approved a memorandum of
understanding to form a single entity to manage power transmission over a large
area of the Midwest. The MISO would serve 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. If consummated and approved by MAPP members, utilities
in MAPP could turn over control of their own electric transmission assets to the
MISO or enter into coordination agreements with MISO. A definitive agreement is
anticipated to be complete by March 2000. MAPP is also engaged in discussions
with other regional reliability organizations to explore formation of a larger
regional reliability organization. (See Competition - Wholesale.)
MINNESOTA PUBLIC UTILITIES COMMISSION. Minnesota Power'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 Power, Inc. 7
<PAGE>
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 Company's minimum spending requirement of $5.5 million for
1999 ($5.5 million for 1998; $5.1 million for 1997) was exceeded by the
Company's actual CIP spending of $7.1 million ($10.3 million in 1998; $5.8
million in 1997). During 1999 the Minnesota Legislature enacted Minnesota
Power-supported legislation allowing large utility customers with 20 MW or more
of connected load at one service point to opt out of the CIP minimum spending
requirements. The DOC (previously the Department of Public Service) is currently
reviewing petitions by many of the Company's largest customers requesting
opt-out approval. The Company's current 2000 - 2001 minimum spending level of
$5.6 million annually may change depending upon the success of the opt-out
petitions. If all are approved, the minimum spending level may be as low as $2.7
million annually. The MPUC allows utilities to accumulate, in a deferred account
for future recovery all CIP expenditures as well as a carrying charge on the
deferred account balance, $13.5 million at December 31, 1999. Through a billing
adjustment and recovered amounts included in retail base rates, the Company
collected $14.7 million in 1999 ($15.2 million in 1998; $13.7 million in 1997)
for the recovery of this deferred account balance. In prior years the MPUC
approved the Company's request to recover lost margins. In June 1999 the MPUC
denied Minnesota Power's request to recover $3.5 million of lost margins related
to 1998 CIP activities. Lost margins represent energy sales lost due to
Minnesota Power's efforts to assist customers in conserving energy, and lost
margin recovery compensates utilities for reduced sales resulting from CIP
activities. The MPUC's Order in this matter indicated that denial of lost margin
recovery was based upon the MPUC's finding that: (1) Minnesota Power was earning
above its authorized rate of return; (2) lost margins were not successfully
motivating the Company to increase its use of demand side management; and (3)
Minnesota Power had not met its burden of proof in showing that the requested
lost margin recovery was consistent with law and sound public policy. Prior to
this decision, the MPUC had not conditioned annual recovery of lost margins on
utility earnings or found that lost margin recovery in this circumstance was
inconsistent with law or policy. Minnesota Power's request for reconsideration
was denied. Upon receipt of the final written order from the MPUC, the Company
will determine whether it will appeal the MPUC decision.
In December 1999 the MPUC closed its investigation into the reasonableness of
Minnesota Power's rates. The limited investigation was opened by the MPUC in
June 1999, and required Minnesota Power to file a report explaining 1998 actual
and 1999 projected earnings, along with an explanation of why rates continued to
be just and reasonable. The DOC recommended acceptance of Minnesota Power's
report (which was filed in September 1999) and recommended closure of the
investigation without any further action. On a 3-0 vote, the MPUC closed its
preliminary investigation and determined it would not commence a full-scale rate
investigation.
MP Telecom was granted a Certificate of Authority to provide local niche and
inter-exchange telecommunication services in Minnesota in April 1998. This
Certificate of Authority governs MP Telecom's provision of local niche services
on an intrastate basis in the State of Minnesota. MP Telecom's fiber optic
facilities provide the link for both voice and data communications. These links
are primarily provided to entities who resell these services to end-users and,
to a lesser extent, to organizations with private communication networks. The
Certificate of Authority issued by the MPUC was amended on April 12, 1999
permitting MP Telecom to provide competitive local facilities-based services in
certain exchanges in Minnesota.
PUBLIC SERVICE COMMISSION OF WISCONSIN. On December 22, 1999 SWL&P filed an
application with the PSCW for authority to increase retail utility rates 1.8%.
This average increase is comprised of a 3.2% decrease in electric rates, a 1.1%
increase in gas rates and a 31% increase in water rates. The proposed water
increase is the result of construction currently underway to replace an aging
well system. SWL&P's current retail rates are based on a 1996 PSCW retail rate
order which allows for an 11.6% return on common equity.
In June 1999 Minnesota Power announced plans to build a natural gas-fired power
plant near the city of Superior, Wisconsin. The combustion turbine power
generating station will be capable of producing approximately 90 MW of electric
power and cost approximately $40 million to build. Combustion turbines produce
low emissions, making them an environmentally advantageous way to generate
electricity. The plant will help alleviate a developing shortage of electricity
during periods of peak electrical demand during summer and winter months,
thereby improving the dependability of the regional electric system. Economic
and risk analysis of the proposed plant is underway.
In April 1999 Minnesota Power and Wisconsin Public Service Corporation (WPS)
announced plans to construct a 250-mile, 345-kilovolt transmission line from
Wausau, Wisconsin to Duluth, Minnesota. The proposal, called "Power Up
Wisconsin," is a direct response to Wisconsin Governor Thompson's call to
address the pressing need for more dependable electricity in Wisconsin and the
Upper Midwest. Alternative routes for the line were selected using existing
rights-of-way where feasible. Public informational meetings in Minnesota were
held in May 1999 and in Wisconsin in July 1999. An application for approval to
construct the Wisconsin portion of the line and to determine a route was filed
with the PSCW in November 1999. In December 1999 the PSCW deemed the application
to build the power line complete. Official public hearings in Wisconsin are
tentatively set for mid 2000. The PSCW is expected to make a decision in late
2000 based on information gathered at the hearings. Application for approval of
the Minnesota portion of the line was filed with the Minnesota Environmental
Quality Board (MEQB) in September 1999. The
8 Minnesota Power, Inc.
<PAGE>
MEQB hearing is expected to take place in early 2000. Depending on siting and
regulatory review and approval, the new transmission line could be in service as
early as December 2002 at an estimated cost of between $125 million and $175
million. Approximately $30 million to $40 million of the estimated cost is for
facilities in Minnesota which will be owned by Minnesota Power. The facilities
in Wisconsin are being financed by WPS and may ultimately be owned by Minnesota
Power, WPS or a newly formed transmission company being established in
Wisconsin. (See Regulation - Federal Energy Regulatory Commission.) The
Wausau-Duluth line is designed to strengthen the regional electric network and
enhance reliability in Wisconsin, Minnesota and other parts of the Upper
Midwest.
The PSCW granted MP Telecom a certification as a competitive local exchange
carrier and alternative telecommunications utility authorizing it to provide
competitive local exchange services in northern Wisconsin on an interim basis as
of June 9, 1999. (See Minnesota Public Utilities Commission.)
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 Services is 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.
In November 1999 Great River Energy and Minnesota Power announced that they
intend to combine power supply resources and customer loads for joint dispatch
operations. MPEX will provide power trading, energy sourcing and risk management
services for the combined operations. Ownership of existing assets and customer
supply arrangements will not change. The companies plan to complete definitive
agreements and achieve full operation of the alliance by the summer of 2000,
subject to required regulatory approvals. With the volatile wholesale
marketplace within MAPP, they expect to mitigate risk in the marketplace and
create opportunities for both companies. This, in turn, will help deliver better
value to customers. Headquartered in Elk River, Minnesota, Great River Energy is
a consumer-owned generation and transmission cooperative and Minnesota's second
largest utility in terms of generating capacity. Great River Energy provides
low-cost electrical energy and related services to its 29 member distribution
cooperatives in Minnesota and Wisconsin.
MPEX continues to review 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.)
RETAIL. In April 1999 the MPUC opened a docket requiring the DOC to file
quarterly reports on the DOC's efforts to develop a statewide, comprehensive
program for gas and electric utility unbundling/retail choice/restructuring. In
the fall of 1999 the DOC hosted stakeholder sessions for work groups that
addressed the following six areas: (1) consumer issues; (2) competitive parity;
(3)energy conservation and alternative technologies; (4) service reliability -
wholesale and retail; (5) unbundling of functions/pricing of remaining regulated
functions and services; and (6) stranded costs and benefits. All six work groups
completed their meetings with participants providing a wide range of opinions
about restructuring. The DOC intends to solicit additional general comments on
restructuring, and DOC staff will present recommendations to the Commissioner of
the DOC in May 2000. After the Commissioner chooses a model for restructuring,
the DOC intends to solicit public comments and will work with stakeholders prior
to the 2001 Minnesota legislative session to develop a consensus approach.
Other restructuring related activities are underway in Minnesota. The Minnesota
Department of Revenue is examining Minnesota's personal property tax
infrastructure, and the need to develop a tax code change to insure competitive
parity within the state. The MEQB, MPUC and DOC are reviewing changes to
Minnesota Statutes necessary to make facility siting and planning more
responsive to changes that restructuring may bring. The Minnesota Legislative
Electric Energy Task Force has convened technical advisory work groups to assist
analyzing nine broad categories of issues relating to electric restructuring in
Minnesota. In addition, Minnesota Power has initiated a generic docket before
the MPUC to develop guidelines for determining functional boundaries between
transmission and generation, and between transmission and local distribution for
all transmission-owning electric service providers within the State of
Minnesota.
Minnesota Power, Inc. 9
<PAGE>
LEGISLATION. Restructuring of the electric utility industry continues
nationwide. Twenty-four states representing approximately two-thirds of the
United States population have passed either legislation or regulation that
initiates a process leading to retail customer choice. Neither Minnesota nor
Wisconsin (where Minnesota Power serves retail electric customers through its
subsidiary, SWL&P) has passed retail customer choice restructuring laws. In
2000, utility restructuring legislation will be debated at the federal level and
in Minnesota and Wisconsin. It is unlikely, however, that Congress or the
legislatures of Minnesota or Wisconsin will enact retail choice legislation into
law this year. The Company cannot predict the timing or substance of any future
legislation that might ultimately be enacted. The Company, however, is
encouraging enactment of retail customer choice in Minnesota and continues to
maintain its competitive position as a low-cost and long-term power supplier to
large industrial customers. With electric rates among the lowest in the United
States, high customer satisfaction, and long-term wholesale and large power
customer retail contracts in place, Minnesota Power believes Electric Services
is well positioned for the future.
FRANCHISES
Minnesota Power holds franchises to construct and maintain an electric
distribution and transmission system in 82 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
AIR. CLEAN AIR ACT. The federal Clean Air Act Amendments of 1990 (Clean Air Act)
require that specified fossil-fueled generating plants obtain air emission
permits from the EPA (or, when delegated, from individual state and pollution
control agencies), and meet new sulfur dioxide and nitrogen oxide emission
standards beginning January 1, 1995 (Phase I) and that virtually all generating
plants meet more strict emission standards beginning January 1, 2000 (Phase II).
None of Minnesota Power's generating facilities are covered by the Phase I
requirements of the Clean Air Act for sulfur dioxide. Phase II requirements,
however, 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. Square Butte anticipates meeting its sulfur dioxide requirements
through increased use of existing scrubbers and by annually purchasing
additional allowances as necessary. Minnesota Power will provide to Square Butte
its proportional share of the allowance shortfall from its surplus allowances
available from Minnesota Power's generating facilities.
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 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 are being 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
---------------------------------------------------------------------------
Minnkota Power, the operator of Square Butte, is currently operating under
existing air quality permits and is in the process of obtaining their Title V
permit from the North Dakota Department of Health (NDDH). Minnkota Power
submitted their permit Title V application to the NDDH on August 5, 1996. A
Title V permit is expected to be issued during 2000.
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
sequestration of greenhouse gas emissions. 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.
10 Minnesota Power, Inc.
<PAGE>
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 United States Senate must ratify the Protocol. However, the Protocol
does not currently satisfy the guidance provided in the 1997 Byrd Hagel Senate
resolution. The Fourth COP meeting was held in Buenos Aires in November 1998, at
which time a schedule was established targeting the January 2001, Sixth COP
meeting for completion of key treaty detail negotiations. The Company currently
cannot reasonably predict when or if a climate 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.
National Pollutant Discharge Elimination System Permits
------------------------------------------------------------------------------
Facility Effective Date Expiration Date
-------- -------------- ---------------
Boswell February 4, 1993 December 31, 1997 (a)
Laskin April 27, 1999 February 28, 2004 (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 (d)
------------------------------------------------------------------------------
(a) On June 27, 1997 a renewal application for this permit was submitted
to the MPCA. A new permit is expected to be issued during 2000. Permits
are extended by the timely filing of a renewal application which stays
the expiration of the previously issued permit.
(b) The new permit contains a Schedule of Compliance requiring
construction of a new ash disposal pond by December 30, 2000. The
Company spent approximately $3.5 million in 1999 and expects to spend
$3.1 million in 2000 to construct the Laskin ash disposal pond.
(c) On December 16, 1998 a renewal application for this permit was submitted
to the MPCA. A new permit is expected to be issued during 2000.
(d) On December 22, 1999 a permit renewal application for this permit was
submitted to the NDDH. Permits are extended by the timely filing of a
renewal application which stays the expiration of the previously issued
permit.
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 (a)
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 (b)
---------------------------------------------------------------------------
(a)The Company filed notice of its intent to file an application for a
new license with the FERC in 1998. The FERC approved the Company's 1998
request to use alternative procedures (i.e., collaborative process) in
filing the license application.
(b)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 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 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 2000, 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
Minnesota Power, Inc. 11
<PAGE>
equipment by the end of 2001 and the removal of PCB capacitors by 2004. The
total cost is expected to be between $2.5 million and $3 million, of which
$700,000 was spent through December 31, 1999.
MINING CONTROL AND RECLAMATION. BNI Coal's mining operations are governed by the
Federal Surface Mining Control and Reclamation Act of 1977. This Act, together
with the rules and regulations adopted thereunder by the Department of the
Interior, Office of Surface Mining Reclamation and Enforcement (OSM), governs
the approval or disapproval of all mining permits on federally owned land and
the actions of the OSM in approving or disapproving state regulatory programs
regulating mining activities. The North Dakota Reclamation of Strip Mined Lands
Act and rules and regulations enacted thereunder in 1969, as subsequently
amended by the North Dakota Mining and Reclamation Act and rules and regulations
enacted thereunder in 1977, govern the reclamation of surface mined lands and
are generally as stringent or more stringent than the federal rules and
regulations. Compliance is monitored by the North Dakota Public Service
Commission. The federal and state laws and regulations require a wide range of
procedures including water management, topsoil and subsoil segregation,
stockpiling and revegetation, and the posting of performance bonds to assure
compliance. In general these laws and regulations require the reclaiming of
mined lands to a level of usefulness equal to or greater than that available
before active mining. The Company considers BNI Coal to be in substantial
compliance with those environmental regulations currently applicable to its
operations and believes all necessary permits to conduct such operations have
been obtained.
AUTOMOTIVE SERVICES
Automotive Services include wholly owned subsidiaries which are integral parts
of the vehicle redistribution business: ADESA, a network of vehicle auctions;
AFC, a finance company; Great Rigs, an auto transport company; PAR, a vehicle
remarketing company; and AutoVIN, a provider of field information services to
the automotive industry. Automotive Services plans to grow through increased
sales at existing businesses, selective acquisitions and expanding services.
ADESA is the second largest vehicle auction network in North America.
Headquartered in Indianapolis, Indiana, ADESA owns (or leases) and operates 29
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 1999 ADESA acquired two new auction facilities. (See Note 3.)
ADESA also started remodeling the five-lane Concord, Massachusetts, vehicle
auction facility and began building a four-lane vehicle auction facility in
Calgary, Alberta, and an eight-lane auction facility on 29.5 acres near
LosAngeles, California. All three facilities are scheduled to open in 2000.
<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 <F3> Edinburgh, Indiana 1997 3
ADESA Indianapolis Plainfield, Indiana 1983 10
ADESA Des Moines <F1> Des Moines, Iowa 1965 3
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 5
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 10
ADESA Cincinnati/Dayton Franklin, Ohio 1986 8
ADESA Cleveland 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 8
ADESA Houston Houston, Texas 1995 8
ADESA San Antonio San Antonio, Texas 1989 8
ADESA Wisconsin Portage, Wisconsin 1984 5
- --------------------------------------------------------------------------------------------------------------------
<FN>
<F1> Leased auction facilities. (See Note 6.)
<F2> ADESA owns 51% of this auction business.
<F3> ADESA owns 80% of this auction business.
</FN>
</TABLE>
12 Minnesota Power, Inc.
<PAGE>
<TABLE>
<CAPTION>
Year No.
Operations Auction
ADESA Auctions Location Commenced Lanes
- --------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
Canada
ADESA Vancouver New Westminster, British Columbia 1972 6
ADESA Halifax Enfield, Nova Scotia 1993 3
ADESA Ottawa Vars, Ontario 1990 5
ADESA Montreal St. Eustache, Quebec 1974 12
- --------------------------------------------------------------------------------------------------------------------
</TABLE>
The previous tables list 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.
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 across North
America. 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 carriers
with over 150 automotive carriers, the majority of which are leased.
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. PAR services include assisting fleet owners, leasing agents and
lenders in transporting, remarketing or otherwise liquidating off-lease vehicles
by choosing the most cost-effective end-of-lease option. In 1999 PAR began
"doing business as" PAR North America. The name change coincides with PAR's
newest product offering full service Canadian importation. PAR is now able to
offer services to customers anywhere in the United States and Canada. PAR also
joined with a partner in Buffalo, New York, to initiate a full-service import
business for off-lease Canadian vehicles in demand in the United States. No
other firm offers this niche service.
AUTOVIN provides professional field information services to the automotive
industry, including vehicle condition reporting, inventory verification
auditing, program compliance auditing and facility inspection. AutoVIN has been
providing services to AFC and will now work closely with AFC to offer auto
dealers one-stop shopping for financial and information services. The Company
acquired 90% of AutoVIN, the Automated Vehicle Information Network, in September
1999, and will acquire the remaining 10% over time.
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.
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. In addition to its floorplan services, AFC, through alliances
with other experienced vendors, has expanded its service array to include sub
prime financing, physical damage insurance and warranty products to its dealer
base. This alliance with vendors experienced in these niche areas makes AFC a
one-stop shopping provider to its dealer base.
PAR is the third largest full-service provider of customized remarketing
services in North America. PAR's competition has changed and the primary source
of competition currently originates from financial institutions that choose to
manage the vehicle remarketing process internally. Competition from
non-financial institutions remains particularly intense. PAR has differentiated
itself from industry leaders by offering their customers the ability to rapidly
change their service delivery methods to meet their customers' evolving needs.
Continued emphasis on the growing lease-end and Canadian importation services,
two services no single competitor offers, further differentiates PAR from the
other members of the remarketing community.
Minnesota Power, Inc. 13
<PAGE>
Tyco International, Ltd. recently announced it has agreed to sell its ADT
auction unit to Manheim Auctions, Inc. for $1 billion, subject to regulatory and
other approvals. ADT owns 28 auctions in the United States. ADESA owns 29
auctions throughout the United States and Canada, with 3 auctions under
construction. If the Manheim/ADT transaction is completed in its present form,
the Company does not expect the transaction to have a material adverse impact on
its existing auction business. Manheim is also a provider of dealer floorplan
financing. The Company is unable to predict the impact the transaction may have
on the AFC offices located at the ADT auctions. AFC intends to continue
operations in the areas currently served by the 28 ADT auctions.
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.
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 continued 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, 1999 Florida Water served 142,000 water customers
and 68,000 wastewater customers, and maintained 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 17 billion gallons of water per year primarily from Florida's underground
aquifer. Substantially all of Florida Water's properties used in water and
wastewater operations are encumbered by a mortgage. In 1999 Florida Water
purchased Palm Coast Utility Corporation (PCUC) from ITT Industries, Inc. (ITT).
PCUC provides service to approximately 19,000 water and 14,000 wastewater
customers in Flagler County, Florida. Rates for PCUC are regulated by Flagler
County. (See Note 3.)
HEATER provides water and wastewater treatment services in North Carolina. As of
December 31, 1999 Heater served 42,000 water customers and 4,000 wastewater
treatment customers. Heater has water and wastewater systems located in
subdivisions surrounding Raleigh and Fayetteville, North Carolina, and the
Piedmont and Mountain regions of 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 396 interconnected and stand-alone systems and 797
wells. Heater also has 33 wastewater treatment plants, ranging in size from
10,000 gallons per day (gpd) to 670,000 gpd, and 77 lift stations located in its
wastewater collection systems. Substantially all of Heater's properties used in
its water and wastewater operations are encumbered by a mortgage. In 1999 Heater
acquired Mid South Water Systems, Inc. (Mid South) located in Sherills Ford,
North Carolina. Mid South serves approximately 12,000 customers. With the
acquisition of Mid South, Heater became the largest investor owned water utility
in North Carolina.
NON-REGULATED SUBSIDIARIES. AMERICA'S WATER SERVICES CORPORTION was
incorporated in 1997 and has offices in Naperville, Illinois; Grand Rapids,
Michigan; Plymouth, Wisconsin; and Longwood, Florida. Americas' Water offers
contract management, operations and maintenance services for water and
wastewater treatment facilities to governments and industries. Americas' Water
Services provides services in Illinois, Minnesota, Michigan, Wisconsin, Ohio and
Florida, with annual contracts ranging from $50,000 to $3 million.
INSTRUMENTATION 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. On a combined basis, these companies provide
services to over 500 customers.
REGULATORY ISSUES
FLORIDA PUBLIC SERVICE COMMISSION. 1995 RATE CASE. In September 1999 the FPSC
issued a final order that approved a 1999 settlement agreement with Florida
Water to resolve open items pertaining to its 1995 rate case. The final order
increased annual revenue by approximately $1 million; authorized Florida Water
to book approximately $8.5 million of accumulated surcharges, including
interest, as a regulatory asset recoverable in base rates beginning in the next
rate case; and provided a three-year moratorium on the initiation of rate cases
by Florida Water, exclusive of index filings. Index filings provide rate
adjustments based on inflationary costs associated with operation and
maintenance expenses. The annual rate increase of approximately $1million
associated with the settlement became effective on October 1, 1999. The FPSC
previously approved annual rate increases
14 Minnesota Power, Inc.
<PAGE>
in connection with the 1995 rate case of approximately $11.1 million and $1.2
million effective in September 1996 and January 1999, respectively. In total,
the FPSC approved $13.6 million of the $18.1 million rate increase requested by
Florida Water in the 1995 rate case.
1991 RATE CASE REFUNDS. In 1995 the Florida First District Court of Appeals
(Court of Appeals) reversed a 1993 FPSC order establishing uniform rates for
most of Florida Water's service areas. With "uniform rates" all customers in
each uniform rate area pay the same rates for water and wastewater services. In
response to the Court of Appeals' order, in August 1996 the FPSC ordered Florida
Water to issue refunds to those customers who paid more since October 1993 under
uniform rates than they would have paid under stand-alone rates. This order did
not permit a balancing surcharge to customers who paid less under uniform rates.
Florida Water appealed, and the Court of Appeals ruled in June 1997 that the
FPSC could not order refunds without balancing surcharges. In response to the
Court of Appeals' ruling, the FPSC issued an order in January 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 1998 order, the FPSC required Florida Water to refund, with
interest, $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 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 in May 1998. In
June 1998 the Court of Appeals reversed its previous ruling that the FPSC was
without authority to order uniform rates at which time 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 in September 1998. A mediation
session was held in September 1999. The parties could not reach settlement of
any issues. A provision for refund related to the $2.5 million refund order was
recorded in 1999. 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 strongly believes
that the continued growth in these markets will enable emerging companies like
Americas' Water to succeed.
FRANCHISES
Florida Water provides water and wastewater treatment services in 20 counties
regulated by the FPSC and holds franchises in 5 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. 15
<PAGE>
INVESTMENTS
Investments is comprised of an actively traded securities portfolio,
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 investment in the securities portfolio at
December 31, 1999 was $257 million ($227 million at December 31, 1998).
The Company exchanged its 7.3 million shares of Capital Re common stock for 4.7
million shares of ACE Limited common stock plus $25.1 million in cash on
December 30, 1999. The exchange of stock was the result of a revised merger
announced October 26, 1999. Each Capital Re share was exchanged for 0.65
ordinary shares of ACE plus $3.4456 in cash. Minnesota Power owned 20% of
Capital Re and now owns 2% of ACE. The ACE shares are included in the Company's
securities portfolio at December 31, 1999.
INTERMEDIATE-TERM INVESTMENTS. Since 1985 the Company has invested $17.1 million
in venture capital funds that seek long-term capital appreciation by making
investments in companies developing advanced technologies to be used by the
utility industry. The Company is committed to invest an additional $20.5 million
over the next eight 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.
The Company has a $4 million note receivable from Car Canada Corporation, a
start-up retail car "superstore" business with stores in Alexandria, Ottawa,
Toronto and Winnipeg. The note bears interest at an annual rate of 10% and is
due in 2002. 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 with 1,500 acres of land and approximately 400 home
sites adjacent to Fort Myers, Florida; (2) Sugarmill Woods with 650 home sites
in Citrus County, Florida; and (3) Palm Coast with 2,100 home sites and 10,000
acres of residential, commercial and industrial land at Palm Coast, Florida.
Palm Coast is a planned community between St. Augustine and Daytona Beach.
In 1999 Cape Coral Holdings, Inc., a subsidiary of the Company, purchased, for
$36.2 million, certain real estate properties located in Cape Coral, Florida,
from subsidiaries of Avatar Holdings Inc. Cape Coral, located adjacent to Fort
Myers, Florida, has a population of 100,000 and is Florida's second largest
municipality in land area. Properties purchased include approximately 2,500
acres of commercial and residential zoned land, including home sites, a golf
resort, marina and commercial buildings. (See Note 3.)
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.
16 Minnesota Power, Inc.
<PAGE>
EXECUTIVE OFFICERS OF THE REGISTRANT
<TABLE>
<CAPTION>
Initial
Executive Officers Effective Date
- --------------------------------------------------------- -----------------
<S> <C>
John Cirello, Age 56
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
Robert D. Edwards, Age 55
Executive Vice President and President - MP Electric July 26, 1995
Executive Vice President and Chief Operating Officer March 1, 1993
Brenda J. Flayton, Age 44
Vice President - Human Resources July 22, 1998
John E. Fuller, Age 56
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 51
Vice President - Corporate Development February 10, 1997
David G. Gartzke, Age 56
Senior Vice President - Finance and Chief
Financial Officer December 1, 1994
James P. Hallett, Age 46
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 51
Vice President, General Counsel and Secretary January 1, 1996
General Counsel and Corporate Secretary March 1, 1993
David P. Jeronimus, Age 57
Vice President - Environmental Services February 1, 1999
James A. Roberts, Age 49
Vice President - Corporate Relations January 1, 1996
Edwin L. Russell, Age 54
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 44
Controller March 1, 1993
James K. Vizanko, Age 46
Treasurer March 1, 1993
Claudia Scott Welty, Age 47
Vice President - Information Technology February 1, 1999
Vice President - Support Services July 1, 1995
</TABLE>
Minnesota Power, Inc. 17
<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.
Mr. Jeronimus was director of environmental resources.
Mr. Roberts was director of corporate relations.
Ms. Welty was director of technical support services.
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 9, 2000.
ITEM 2. PROPERTIES
Properties are included in the discussion of the Company's business in Item 1
and are incorporated by reference herein.
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 1999.
18 Minnesota Power, Inc.
<PAGE>
PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER
MATTERS
The Company has paid dividends without interruption on its Common Stock since
1948. A quarterly dividend of $0.2675 per share on the Common Stock will be paid
on March 1, 2000 to the holders of record on February 15, 2000. The Company's
Common Stock is listed on the New York Stock Exchange. Dividends paid per share,
and the high and low prices for the Company's Common Stock for the periods
indicated as reported by The Wall Street Journal, Midwest Edition, were as
follows:
Dividends
Price Range Paid Per Share
-------------------------- ------------------------
Quarter High Low Quarterly Annual
- --------------------------------------------------------------------------------
1999 - First $22 3/32 $19 17/32 $0.2675
- Second 21 13/16 18 15/16 0.2675
- Third 19 7/8 16 9/16 0.2675
- Fourth 18 11/16 16 0.2675 $1.07
1998 - First $21 23/32 $19 9/16 $0.2550
- Second 21 15/32 19 1/32 0.2550
- Third 22 1/2 19 17/32 0.2550
- Fourth 23 1/8 20 3/8 0.2550 $1.02
- --------------------------------------------------------------------------------
On March 2, 1999 the Company's Common Stock was split two-for-one. All common
share and per share amounts have been adjusted for all periods to reflect the
two-for-one stock split.
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 1999 the
Company paid out 110% (72% excluding the non-cash charge related to the Capital
Re transaction) of its per share earnings in dividends.
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, 1999 no retained earnings were
restricted as a result of these provisions. At January 31, 2000 there were
approximately 37,000 Common Stock shareholders of record.
Minnesota Power, Inc. 19
<PAGE>
ITEM 6. SELECTED FINANCIAL DATA
The Company's financial statements have been changed to reflect changes in the
way the Company looks at its business. Financial data from prior years have been
reclassified to present comparable information for all periods. All common share
and per share amounts have been adjusted for all periods to reflect the
Company's March 2, 1999 two-for-one Common Stock split. 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, in July
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 in June 1995.
<TABLE>
<CAPTION>
Balance Sheet 1999 1998 1997 1996 1995 1994
- ----------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
Millions
Assets
Current Assets $ 564.5 $ 487.5 $ 385.3 $ 334.4 $ 251.9 $ 266.1
Property, Plant and Equipment 1,258.8 1,178.9 1,170.2 1,188.8 1,149.1 998.2
Investments 197.2 263.5 252.9 236.5 201.4 355.3
Goodwill 181.0 169.8 158.9 167.0 120.2 1.9
Other Assets 111.1 109.2 119.0 123.6 126.8 99.3
-------- -------- -------- -------- -------- --------
$2,312.6 $2,208.9 $2,086.3 $2,050.3 $1,849.4 $1,720.8
Liabilities and Stockholders' Equity
Current Liabilities $ 398.3 $ 346.0 $ 342.6 $ 339.7 $ 256.8 $ 182.8
Long-Term Debt 712.8 672.2 685.4 694.4 639.5 601.3
Other Liabilities 289.2 298.6 301.8 298.9 320.5 326.5
Mandatorily Redeemable Preferred
Securities of MP&L Capital I 75.0 75.0 75.0 75.0 - -
Redeemable Preferred Stock 20.0 20.0 20.0 20.0 20.0 20.0
Stockholders' Equity 817.3 797.1 661.5 622.3 612.6 590.2
-------- -------- -------- -------- -------- --------
$2,312.6 $2,208.9 $2,086.3 $2,050.3 $1,849.4 $1,720.8
- ----------------------------------------------------------------------------------------------------------------------------
Income Statement 1999 1998 1997 1996 1995 1994
- ----------------------------------------------------------------------------------------------------------------------------
Millions
Operating Revenue
Electric Services $ 554.5 $ 559.8 $ 541.9 $ 529.2 $ 503.5 $ 458.4
Automotive Services 406.6 328.4 255.5 183.9 61.6 -
Water Services 112.9 95.6 95.5 85.2 66.1 87.5
Investments 57.8 55.5 60.7 48.6 36.1 31.1
-------- -------- -------- -------- -------- --------
1,131.8 1,039.3 953.6 846.9 667.3 577.0
-------- -------- -------- -------- -------- --------
Expenses
Fuel and Purchased Power 200.2 205.7 194.1 190.9 177.0 157.7
Operations 705.9 635.4 579.9 512.2 389.1 300.6
Interest Expense 59.5 64.9 64.2 62.1 48.0 46.7
-------- -------- -------- -------- -------- --------
965.6 906.0 838.2 765.2 614.1 505.0
-------- -------- -------- -------- -------- --------
Operating Income before Capital Re 166.2 133.3 115.4 81.7 53.2 72.0
Income (Loss) from Investment
in Capital Re (34.5) 15.2 14.8 11.8 9.8 8.1
-------- -------- -------- -------- -------- --------
Operating Income 131.7 148.5 130.2 93.5 63.0 80.1
Distributions on Redeemable
Preferred Securities of Subsidiary 6.0 6.0 6.0 4.7 - -
Income Tax Expense 57.7 54.0 46.6 19.6 1.1 20.6
-------- -------- -------- -------- -------- --------
Income from Continuing Operations 68.0 88.5 77.6 69.2 61.9 59.5
Income from
Discontinued Operations - - - - 2.8 1.8
-------- -------- -------- -------- -------- --------
Net Income 68.0 88.5 77.6 69.2 64.7 61.3
Preferred Dividends 2.0 2.0 2.0 2.4 3.2 3.2
-------- -------- -------- -------- -------- --------
Earnings Available for Common Stock 66.0 86.5 75.6 66.8 61.5 58.1
Common Stock Dividends 73.0 65.0 62.5 59.6 57.9 56.7
-------- -------- -------- -------- -------- --------
Earnings Retained in
(Disbursed From) the Business $ (7.0) $ 21.5 $ 13.1 $ 7.2 $ 3.6 $ 1.4
- ----------------------------------------------------------------------------------------------------------------------------
</TABLE>
20 Minnesota Power, Inc.
<PAGE>
<TABLE>
<CAPTION>
1999 1998 1997 1996 1995 1994
- ---------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
Shares Outstanding - Millions
Year-End 73.5 72.3 67.1 65.5 62.9 62.5
Average <F1> 68.4 64.0 61.2 58.6 57.0 56.5
Diluted Earnings Per Share
Continuing Operations $0.97<F2> $1.35 $1.24 $1.14 $1.03 $1.00
Discontinued Operations - - - - .05 .03
----- ----- ----- ----- ----- -----
$0.97<F2> $1.35 $1.24 $1.14 $1.08 $1.03
Return on Common Equity 8.3%<F2> 12.4% 12.1% 11.3% 10.7% 10.5%
Common Equity Ratio 49.2% 49.9% 44.9% 43.1% 45.6% 45.9%
Dividends Paid Per Share $1.07 $1.02 $1.02 $1.02 $1.02 $1.01
Dividend Payout 110%<F2> 76% 83% 89% 94% 98%
Book Value Per Share at Year-End $10.97 $10.86 $9.69 $9.32 $9.28 $8.99
Market Price Per Share
High 22 3/32 23 1/8 22 14 7/8 14 5/8 16 1/2
Low 16 19 1/32 13 1/2 13 12 1/8 12 3/8
Close 16 15/16 22 21 25/32 13 3/4 14 3/16 12 5/8
Market/Book at Year-End 1.54 2.03 2.25 1.48 1.53 1.40
Price Earnings Ratio at Year-End 17.5<F2> 16.3 17.6 12.1 13.1 12.3
Dividend Yield at Year-End 6.3% 4.6% 4.7% 7.4% 7.2% 8.0%
Employees 8,246 7,003 6,817 6,537 5,649 2,552
Net Income
Electric Services $45.0 $47.4 $43.1 $39.4 $41.0 $40.6
Automotive Services 39.9 25.5 14.0 3.7 - -
Water Services 12.2 7.5 8.2 5.4 (1.0) 13.7
Investments (9.4)<F2> 29.6 32.1 38.1 41.3 23.4
Corporate Charges (19.7) (21.5) (19.8) (17.4) (19.4) (18.2)
----- ----- ----- ----- ----- -----
68.0 88.5 77.6 69.2 61.9 59.5
Discontinued Operations - - - - 2.8 1.8
----- ----- ----- ----- ----- -----
$68.0 $88.5 $77.6 $69.2 $64.7 $61.3
Customers - Thousands
Electric 139.7 138.1 135.8 135.1 135.8 132.8
Water 255.3 205.1 201.0 197.2 198.4 176.0
Electric Sales - Millions of MWh 11.3 12.0 12.4 13.2 11.5 10.2
Power Supply - Millions of MWh
Steam Generation 6.2 6.3 6.1 6.4 6.0 5.5
Hydro Generation 0.7 0.6 0.6 0.7 0.7 0.7
Long-Term Purchase - Square Butte 2.3 2.1 2.3 2.4 1.9 2.3
Purchased Power 2.6 3.2 3.8 4.4 3.6 2.1
---- ---- ---- ---- ---- ----
11.8 12.2 12.8 13.9 12.2 10.6
Coal Sold - Millions of Tons 4.5 4.2 4.2 4.5 4.0 4.4
Vehicles Consigned - Millions 1.7 1.5 1.4 1.1 0.5 -
Water Sold - Billions of Gallons 20.3 18.1 16.5 16.0 14.7 14.8
Capital Expenditures - Millions $99.7 $80.8 $72.2 $101.5 $115.5 $81.0
- ---------------------------------------------------------------------------------------------------------------------------
<FN>
<F1>Excludes unallocated ESOP shares.
<F2>On December 30, 1999 Minnesota Power exchanged 7.3 million shares of Capital
Re common stock for 4.7 million shares of ACE common stock plus $25.1
million in cash. This transaction resulted in a non-cash charge of $36.2
million, or $0.52 per share, to Minnesota Power's net income for 1999.
Excluding the Capital Re transaction, diluted earnings per share were $1.49,
the return on common equity was 12.9%, the dividend payout was 72%, the
price earning ratio was 11.4 and net income from Investments was $26.8
million.
</FN>
</TABLE>
Minnesota Power, Inc. 21
<PAGE>
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
CONSOLIDATED OVERVIEW
Significant growth in the Company's Automotive Services and Water Services
segments contributed to higher operating results in 1999. Excluding a $36.2
million non-cash charge associated with the Company's investment in Capital Re
(see Note 9), 1999 net income increased 17.7% to $104.2 million. In addition,
basic and diluted earnings per share, excluding the Capital Re related charge,
were $1.49, a 10.4% increase over the prior year. Financial results for all of
the Company's business segments reflected ongoing operational improvements and
the successful strategies initiated to grow and diversify each business.
Earnings per share in 1999 also include the dilution from an additional 4.2
million shares of Common Stock issued by the Company in an underwritten public
offering in September 1998.
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.
1999 1998 1997
- --------------------------------------------------------------------------------
Millions
Operating Revenue
Electric Services $ 554.5 $ 559.8 $541.9
Automotive Services 406.6 328.4 255.5
Water Services 112.9 95.6 95.5
Investments 58.2 55.8 60.9
Corporate Charges (0.4) (0.3) (0.2)
-------- -------- ------
$1,131.8 $1,039.3 $953.6
-------- -------- ------
Operating Expenses
Electric Services $479.0 $ 480.5 $470.2
Automotive Services 337.3 281.5 227.1
Water Services 93.3 83.1 82.8
Investments 24.3 22.6 24.9
Corporate Charges 31.7 38.3 33.2
-------- -------- ------
$965.6 $906.0 $838.2
-------- -------- ------
Net Income
Electric Services $ 45.0 $47.4 $43.1
Automotive Services 39.9 25.5 14.0
Water Services 12.2 7.5 8.2
Investments 26.8(a) 29.6 32.1
Corporate Charges (19.7) (21.5) (19.8)
------ ----- -----
Net Income Before Capital Re
Transaction 104.2 88.5 77.6
Capital Re Transaction (36.2) - -
------ ----- -----
$ 68.0 $88.5 $77.6
- --------------------------------------------------------------------------------
Average Shares of Common Stock - Millions 68.4 64.0 61.2
Basic and Diluted Earnings Per Share of
Common Stock
Before Capital Re Transaction $ 1.49 $1.35 $1.24
Capital Re Transaction (0.52) - -
------ ----- -----
$ 0.97 $1.35 $1.24
Return on Common Equity
Excluding the Capital Re Transaction 12.9% 12.4% 12.1%
Including the Capital Re Transaction 8.3% - -
- --------------------------------------------------------------------------------
(a)Including the $36.2 million non-cash charge associated with the
Capital Re transaction, net income from Investments was a $9.4 million
loss.
22 Minnesota Power, Inc.
<PAGE>
The following summarizes significant events which impacted net income for each
of the Company's business segments for the past three years.
ELECTRIC SERVICES contributed net income of $45.0 million in 1999 ($47.4 million
in 1998; $43.1 million in 1997). In 1999 Electric Services reflected lower
kilowatthour sales to industrial customers, higher prices and margins from bulk
power sales, a denial of lost margin recovery for conservation improvement
programs and a one-time property tax levy associated with an industrial
development project. Total kilowatthour sales were 11.3 billion in 1999 (12.0
billion in 1998; and 12.4 billion in 1997). The 1999 decline in sales was
primarily attributable to fewer sales to taconite, paper and pipeline customers
because of lower demand for domestic steel, stronger competition in the paper
markets and lower pipeline pumping levels. The increase in 1998 net income was
from higher margins from bulk power sales to other power suppliers. An unusually
mild winter in 1998 negatively impacted both net income and kilowatt sales from
retail customers. Net income in 1997 reflected a strong demand for electricity
from industrial customers, increased margins from sales to other power suppliers
and gains from the sale of certain recreational land and microwave frequencies.
Gains from these two sales were offset by start-up costs associated with
strategic initiatives and incentive compensation awards related to total
shareholder return performances.
AUTOMOTIVE SERVICES contributed net income of $39.9 million in 1999 ($25.5
million in 1998; $14.0 million in 1997). In 1999 Automotive Services showed
significant growth reflecting a profitable mix of same-store growth and
selective acquisitions at ADESA as well as increased financing activity and the
maturing of loan production offices that were opened in 1998 by AFC. ADESA added
two new auction facilities in 1999 (three in 1998; two in 1997) and received on
consignment 1.7 million vehicles (1.5 million in 1998; 1.4 million in 1997).
Consigned vehicles are vehicles offered for sale at ADESA auctions. AFC has had
84 loan production offices since August 1998. AFC added 30 new loan production
offices in 1998 (25 in 1997). The growth of AFC's dealer/customer base to 14,700
in 1999 (11,500 in 1998; 10,000 in 1997) has also enabled AFC to finance
approximately 695,000 vehicles in 1999 (531,000 in 1998; 300,000 in 1997). In
1998 AFC's expansion was largely attributable to an agreement with ADT which
allows AFC to provide floorplan financing services at 26 ADT auctions. Also see
Item 1. Business - Automotive Services - Competition for a discussion of the
Manheim/ADT merger.
WATER SERVICES contributed net income of $12.2 million in 1999 ($7.5 million in
1998; $8.2 million in 1997). In 1999 Water Services generated higher net income
due to strategic asset purchases and customer growth that increased the customer
base by 24%, regulatory relief granted by the FPSC in the settlement of Florida
Water's 1995 rate case and increased average consumption. In 1998 Water Services
results reflected regulatory relief, customer growth, increased consumption and
operating efficiencies. In 1997 Water Services net income included a gain from
the sale of certain water and wastewater assets to Orange County, Florida.
Financial results for 1997 also reflected improved operating efficiencies,
one-time charges and start-up costs associated with non-regulated initiatives.
(See Item 1. Business - Water Services - Regulatory Issues.)
INVESTMENTS contribution to net income was $(9.4) million, $26.8 million
excluding the Capital Re transaction, in 1999 ($29.6 million in 1998; $32.1
million in 1997). In 1999 Investments reported gains from an investment in a
venture capital fund. A $36.2 million non-cash charge associated with the merger
of Capital Re with ACE (see Item 1. Business - Investments - Securities
Portfolio and Note 9), the discontinuance of equity accounting for the Company's
investment in Capital Re and stock market volatility affecting returns from the
securities portfolio during 1999 lowered Investment net income. The Company's
securities portfolio earned an annualized after-tax return of 3.3% in 1999 (5.5%
in 1998; 7.7% in 1997). In 1998 Investments reported a lower after-tax return
from the securities portfolio due to the under performance of certain
investments, which was offset by dividend income received from a venture capital
investment and strong sales by Real Estate Operations.
CORPORATE CHARGES were $19.7 million in 1999 ($21.5 million in 1998; $19.8
million in 1997). Corporate charges were lower in 1999 due to reduced interest
expense as a result of a lower average commercial paper balance. Corporate
Charges in 1998 included reduced 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 incurred to finance investments
in non-regulated operations and various strategic initiatives.
1999 COMPARED TO 1998
OPERATING REVENUE
ELECTRIC SERVICES operating revenue was $5.3 million lower in 1999. Revenue in
1999 reflected a $23.0 million increase from sales to other power suppliers
because of extreme weather conditions affecting power market prices during the
third quarter of 1999. Temperatures, which were at record highs during the last
week of July 1999, created a high demand for power from other power suppliers.
Revenue from industrial customers was down approximately $19 million in 1999 due
to decreased taconite production, paper manufacturing and pipeline usage.
Revenue from residential and commercial customers was $3.8 million higher in
1999 because the winter weather in northern Minnesota and Wisconsin was colder
than 1998 and July 1999 was unusually hot. In total,
Minnesota Power, Inc. 23
<PAGE>
$4.4 million less was collected from fuel clause adjustments. Revenue in 1998
included $3.8 million of CIP lost margin recovery. The Company was denied CIP
lost margin recovery in 1999.
AUTOMOTIVE SERVICES operating revenue was $78.2 million higher in 1999 due to
stronger sales at ADESA auction facilities, and increased financing activity and
12 months of operations at loan production offices opened in 1998 by AFC. ADESA
offered 13% more vehicles for sale on consignment in 1999 compared to 1998. In
1999 ADESA auction financial results included twelve months of operations from
three vehicle auctions acquired in 1998 and partial year results for two vehicle
auction facilities acquired in 1999. AFC financed 31% more vehicles in 1999
compared to 1998. AFC has had 84 loan production offices since August 1998, 30
of which were opened during 1998.
WATER SERVICES operating revenue was $17.3 million higher in 1999, with $12.3
million of the increase coming from PCUC, which was purchased in January 1999.
The remainder of the increase was attributed to regulatory relief granted by the
FPSC in December 1998 and September 1999, the acquisition of Mid South and more
consumption due to customer growth. Overall consumption increased 12% in 1999.
In 1998 overall consumption was lower than normal due to some of the Company's
water systems being adversely impacted by record rainfall during the first
quarter. Gains totaling $600,000 from the sale of a water system and the sale of
land were included in 1998 revenue.
INVESTMENTS operating revenue was $2.4 million higher in 1999 primarily due to
$10.7 million in gains received from an investment in a venture capital fund and
higher sales by Real Estate Operations. These increases were partially offset by
lower returns on the securities portfolio due to stock market volatility
affecting returns from short-term investments. Also, revenue in 1998 included
$4.3 million of dividend income received from a venture capital investment.
OPERATIONS EXPENSE
ELECTRIC SERVICES operating expenses were $1.5 million lower in 1999 primarily
due to a $5.5 million reduction in fuel and purchased power expenses because of
less steam generation and fewer purchases from other power suppliers, and a $1.9
million decrease in depreciation expense primarily the result of an updated
production plant depreciation study. Operating expenses were also $2.7 million
lower in 1999 because the amortization of an early retirement program was
completed in July 1998. These decreases were partially offset by a one-time
property tax levy and other expenses related to an industrial development
project totaling $3.6 million, and higher compensation and consulting service
expenses.
AUTOMOTIVE SERVICES operating expenses were $55.8 million higher in 1999
primarily due to increased sales activity at the auction facilities and the
floorplan financing business. Additional expenses associated with more auction
facilities and loan production offices also contributed to higher expenses in
1999.
WATER SERVICES operating expenses were $10.2 million higher in 1999 primarily
due to inclusion of PCUC and Mid South operations.
INVESTMENTS operating expenses were $1.7 million higher in 1999 primarily due to
more sales by Real Estate Operations.
CORPORATE CHARGES operating expenses were $6.6 million lower in 1999 because
interest expense in 1998 reflected a settlement with the Internal Revenue
Service on tax issues relating to prior years. As a result of the settlement,
$4.7 million previously accrued as income tax expense were reversed and recorded
as interest expense in the first quarter of 1998. There was no impact on
consolidated net income from this transaction. Also, interest expense was
reduced in 1999 because the average commercial paper balance was lower.
INCOME (LOSS) FROM INVESTMENT IN CAPITAL RE
In 1999 the Company reported a $34.5 million loss on its investment in Capital
Re. The loss was due to the non-cash charge associated with the merger of
Capital Re with ACE. The discontinuance of equity accounting for this
investment also reduced income in 1999.
1998 COMPARED TO 1997
OPERATING REVENUE
ELECTRIC SERVICES operating revenue was $17.9 million higher in 1998, even
though kilowatthour sales remained at similar levels. A $10.8 million increase
in sales to other power suppliers was attributable to a higher average sales
price for bulk power sold. Bulk sale prices were higher because of storm damages
and hot weather in the Midwest. Revenue related to the fuel clause adjustments
increased $9.9 million 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. Another $3.3 million
of the increase is related to CIP. 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.
24 Minnesota Power, Inc.
<PAGE>
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.
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.
INVESTMENTS operating revenue was $5.1 million lower in 1998 primarily due to
large bulk sales by Real Estate Operations in 1997. In 1998 Investments
operating revenue also 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.
OPERATING EXPENSE
ELECTRIC SERVICES operating expenses were $10.3 million higher in 1998. 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%. 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.
AUTOMOTIVE SERVICES operating expenses were $54.4 million higher in 1998 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.
WATER SERVICES operating expenses were $0.3 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.
INVESTMENTS operating expenses were $2.3 million lower in 1998 because in 1997
there was more sales activity by Real Estate Operations.
INCOME (LOSS) FROM INVESTMENT IN CAPITAL RE
Income from investment in Capital Re reflected $15.2 million of equity income in
1998 ($14.8 million in 1997) from the Company's investment in Capital Re.
OUTLOOK
CORPORATE OUTLOOK. Minnesota Power's strategic objectives over the next five
years are to achieve market leadership in each of its businesses; complete the
transition to a multi-services company; grow considerably in size and
profitability; and significantly enhance total shareholder return.
ELECTRIC SERVICES. The contribution from Electric Services is expected to remain
stable as the industry continues to restructure. Electric Services intends to
seek additional cost saving alternatives and efficiencies, and expand
non-regulated services to maintain its contribution to net income.
In 1999 Electric Services announced plans to: (1) form an alliance with Great
River Energy to combine power supply assets and customer loads for power pool
operations; (2) construct in partnership with Wisconsin Public Service
Corporation a 250-mile, 345-kilovolt transmission line from Wausau, Wisconsin,
to Duluth, Minnesota; and (3) build a 90-MW natural gas-fired power plant near
the city of Superior, Wisconsin. Rainy River entered into a 15-year, 275-MW
power purchase agreement with a subsidiary of LS Power which is expected to
begin in 2002. The Company's subsidiary, MP Telecom, which provides high
capacity fiber optic communication services to businesses and communities across
Minnesota and in Wisconsin is currently completing fiber routes that include the
Minneapolis-St. Paul metro area, Rochester, Owatonna, Albert Lea and Winona,
Minnesota. In 1999 MP Telecom received approval by the MPUC and PSCW to provide
competitive local exchange carrier services in Minnesota and Wisconsin,
respectively.
Annual taconite production in Minnesota was 43 million tons in 1999 (46 million
tons in 1998; 47 million tons in 1997). Based on the Company's research of the
taconite industry, Minnesota taconite production for 2000 is anticipated to be
above the 1999 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. Steel imports continue to depress steel prices and is
the critical issue facing the American steel industry, which includes the
taconite industry. (See Item 1. Business - Electric Services - Electric Sales.)
AUTOMOTIVE SERVICES. Vehicle sales within the auto auction industry are expected
to rise at a rate of 6% to 8% annually. With the continued 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. Two
Minnesota Power, Inc. 25
<PAGE>
vehicle auction facilities are in the process of being built. One is located in
Calgary, Alberta, and will have four lanes. The other one is located near Los
Angeles, California, and will have eight lanes. A third vehicle auction facility
in Concord, Massachusetts, is being remodeled and reopened. It will have five
auction lanes. All three auction facilities are scheduled to open in 2000. 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. Also see Item 1. Business - Automotive Services -
Competition for a discussion of the Manheim/ADT merger.
WATER SERVICES. Florida Water will continue to position itself by selectively
acquiring targeted water systems. 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. The Company anticipates 3% to 5% customer growth over the next
two years. 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.
INVESTMENTS. The Company's objective is to maintain corporate liquidity. 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. 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's Real Estate Operations 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 1997 cash from operating activities has increased 31% (up 19% from 1998 to
1999; up 10% from 1997 to 1998). Increased cash flow from operations 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.
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 8 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 proceeds from the sale of 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. AFC sells
certain finance receivables on a revolving basis to a wholly owned,
unconsolidated, qualified special purpose subsidiary. This subsidiary in turn
sells, on a revolving basis, an undivided interest in eligible finance
receivables, up to a maximum at any one time outstanding of $300 million, to
third party purchasers under an agreement which expires at the end of 2002. At
December 31, 1999 AFC had sold $296.8 million of finance receivables to the
special purpose subsidiary ($202.9 million at December 31, 1998). Third party
purchasers had purchased an undivided interest in finance receivables of $225
million from this subsidiary at December 31, 1999 ($170.0 million at December
31, 1998). Unsold finance receivables held by the special purpose subsidiary are
recorded by AFC as residual interest at fair value. 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 was not used due to the
short-term nature of the receivables sold. The fair value of AFC's residual
interest was $57.6 million at December 31, 1999 ($20.1 million at December 31,
1998). Proceeds from the sale of the receivables were used to repay borrowings
from the Company and fund vehicle inventory purchases for AFC's customers.
Notes payable increased temporarily to finance Automotive Services cash
requirements due to significant auction sales and financing growth. The Company
also used notes payable and proceeds from the September 1998 issuance of Common
Stock to fund the January 1999 purchase of PCUC. Florida Water purchased the
assets of PCUC from ITT Industries, Inc. for $16.8 million plus
26 Minnesota Power, Inc.
<PAGE>
$1,000 per new water connection for an eight-year period. The Company estimates
the present value of these future water connections to be $5.1 million.
In April 1999 ADESA acquired Des Moines Auto Auction located in Des Moines, Iowa
and in July 1999 ADESA Canada, Inc. purchased the Vancouver Auto Auction of New
Westminster, British Columbia. The two transactions had a combined purchase
price of $31.3 million. The Company funded these transactions with internally
generated funds and notes payable that are expected to be replaced with
long-term debt financing in 2000. ADESA plans to issue $25 million of Senior
Unsecured Notes Due 2010 in early 2000. Proceeds will be used to refinance
short-term bank indebtedness incurred for the acquisition of vehicle auction
facilities and for general corporate purposes.
In June 1999 Heater acquired the assets of Mid South of Sherills Ford, North
Carolina for $9 million. The Company funded this transaction with internally
generated funds and proceeds from a long-term revolving line of credit which
were repaid in January 2000.
In June 1999 Cape Coral Holdings, Inc., a subsidiary of MP Real Estate,
purchased, for $36.2 million, certain real estate properties located in Cape
Coral, Florida, from subsidiaries of Avatar Holdings Inc. The Company funded
this transaction with internally generated funds and proceeds from a long-term
revolving line of credit.
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 bond ratings is not a
recommendation to buy, sell or hold the Company's securities.
In 1999 the Company paid out 110% (76% in 1998; 83% in 1997) of its per share
earnings in dividends. Excluding the non-cash charge related to the Capital Re
transaction, the Company paid out 72% of its per share earnings in dividends.
CAPITAL REQUIREMENTS
Consolidated capital expenditures totaled $99.7 million in 1999 ($80.8 million
in 1998; $72.2 million in 1997). Expenditures in 1999 included $47.7 million for
Electric Services, $23.8 million for Automotive Services, $26.9 million for
Water Services, $0.9 million for Investments and $0.4 million for corporate
purposes. Internally generated funds, funds from original issue equity
securities and the issuance of long-term debt were the primary sources of
funding these capital expenditures.
Capital expenditures are expected to be $111 million in 2000 and total about
$360 million for 2001 through 2004. The 2000 amount includes $47 million for
electric system component replacement and upgrades, telecommunication fiber and
coal handling equipment; and $36 million for two new auctions currently under
construction, expansions and on-going improvements at existing vehicle auction
facilities, and associated computer systems; and $28 million to expand water and
wastewater treatment facilities to accommodate customer growth, to meet
environmental standards and for water conservation initiatives. The Company
expects to use internally generated funds, and the issuance of long-term debt
and 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 indeterminate period of time are
classified as available-for-sale securities and also recorded at fair value. At
December 31, 1999 available-for-sale securities consisted of 4.7 million shares
of ACE Limited and securities in a grantor trust established to fund certain
employee benefits.
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 market risks, and 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. Generally, treasury futures contracts
mature in 90 days. (See Note 10.)
December 31, 1999 Fair Value
-----------------------------------------------------------------------
Millions
Trading Securities Portfolio $179.6
Available-For-Sale Securities Portfolio $93.8
-----------------------------------------------------------------------
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 4.)
In December 1998 Florida Water entered into a ten-year interest rate swap
agreement with a notional amount of $35.1 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 (4.7% at December 31, 1999 and 3.4% at December 31, 1998)
Minnesota Power, Inc. 27
<PAGE>
and receives payments based on a fixed rate of 4.79%. The agreement is subject
to market risk due to interest rate fluctuations, and the fair value of the
agreement was $(2.3) million at December 31, 1999.
NEW ACCOUNTING STANDARDS
In June 1998 the Financial Accounting Standards Board issued SFAS 133,
"Accounting for Derivative Instruments and Hedging Activities," as amended
by SFAS 137, effective for fiscal years beginning after June 15, 2000. 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 Company
currently believes it has only a limited amount of derivative activity and
adoption of SFAS 133 is not expected to have a material impact on the Company's
financial position and results of operations.
YEAR 2000
In the ordinary course of business over the last six years, the Company has
replaced major business and operating computer systems. These systems required
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 $4.7 million in expenses primarily for labor associated
with inventory, evaluation and remediation efforts. The Company estimates it
will spend approximately $0.3 million during the year 2000 for remediation of
systems not critical to daily operations. Funds to address Year 2000 issues have
been provided for in the Company's existing budgets. These costs included the
assignment of existing personnel to Year 2000 projects, maintenance and repair
expenses, and capitalized improvements. No critical projects were deferred
because of Year 2000 issues. The Company has not experienced any service
disruptions due to Year 2000 issues.
----------------------------
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, 1999 and
1998 and for each of the three years in the period ended December 31, 1999, 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.
28 Minnesota Power, Inc.
<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 2000 Annual Meeting of Shareholders, except for
information with respect to executive officers which is set forth in Part I
hereof. The 2000 Proxy Statement will be filed with the Securities and Exchange
Commission within 120 days after the end of the Company's 1999 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 2000 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 2000 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 2000 Annual Meeting of Shareholders.
Minnesota Power, Inc. 29
<PAGE>
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, 1999 and 1998 37
For the Three Years Ended December 31, 1999
Consolidated Statement of Income 38
Consolidated Statement of Cash Flows 39
Consolidated Statement of Stockholders' 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 58
All other schedules have been omitted either because the information is not
required to be reported by the Company or because the information is included in
the consolidated financial statements or the notes thereto.
(3) Exhibits including those incorporated by reference
----------------------------
Exhibit
Number
*2 - Agreement and Plan of Merger by and among the Company, AC
Acquisition Sub, Inc., ADESA Corporation and Certain ADESA Management
Shareholders dated February 23, 1995 (filed as Exhibit 2 to the March
3, 1995 Form 8-K, File No. 1-3548).
*3(a)1 - Articles of Incorporation, amended and restated as of May 27, 1998
(filed as Exhibit 4(a) to the June 3, 1998 Form 8-K, 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
the June 3, 1998 Form 8-K, 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 (Douglas J. MacInnes, successor), Trustees (filed as
Exhibit 7(c), File No. 2-5865).
30 Minnesota Power, Inc.
<PAGE>
Exhibit
Number
*4(a)2 - Supplemental Indentures to Minnesota Power's 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(a)3
Twentieth November 1, 1997 1-3548 (1997 Form 10-K) 4(a)3
*4(b)1 - 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 U. S.
Bank Trust N.A., as Trustee (filed as Exhibit 7(c), File No. 2-8668).
*4(b)2 - Supplemental Indentures to Superior Water, Light and Power Company's
Mortgage and Deed of Trust:
Number Dated as of Reference File Exhibit
----------- ----------------- ----------------------- -------
First March 1, 1951 2-59690 2(d)(1)
Second March 1, 1962 2-27794 2(d)1
Third July 1, 1976 2-57478 2(e)1
Fourth March 1, 1985 2-78641 4(b)
Fifth December 1, 1992 1-3548 (1992 Form 10-K) 4(b)1
Sixth March 24, 1994 1-3548 (1996 Form 10-K) 4(b)1
Seventh November 1, 1994 1-3548 (1996 Form 10-K) 4(b)2
Eighth January 1, 1997 1-3548 (1996 Form 10-K) 4(b)3
*4(c)1 - 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 the
1992 Form 10-K, File No. 1-3548).
*4(c)2 - Supplemental Indentures to Florida Water Services Corporation's
Indenture:
Number Dated as of Reference File Exhibit
----------- ----------------- ----------------------- -------
First March 1, 1993 1-3548 (1996 Form 10-K) 4(c)1
Second March 31, 1997 1-3548 (March 31, 1997
Form 10-Q) 4
Third May 28, 1997 1-3548 (June 30, 1997
Form 10-Q) 4
*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 the March 31, 1996 Form 10-Q, File No. 1-3548), as modified
by Amendment No. 1, dated April 11, 1996 (filed as Exhibit 4(b) to
the March 31, 1996 Form 10-Q, File No. 1-3548).
Minnesota Power, Inc. 31
<PAGE>
Exhibit
Number
*4(e) - 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 the March 31, 1996 Form 10-Q, File No. 1-3548).
*4(f) - 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 the March 31, 1996 Form 10-Q, File
No. 1-3548).
*4(g) - 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 the March 31, 1996 Form 10-Q, File No. 1-3548).
*4(h) - 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 the
1996 Form 10-K, File No. 1-3548).
*4(i) - 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 the August 2, 1996 Form 8-K, File No. 1-3548).
*4(j) - 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 the 1996 Form 10-K, File No. 1-3548).
*4(k) - 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 the 1996 Form 10-K, File No. 1-3548).
*4(l) - 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 the 1996 Form 10-K, 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 the 1995 Form 10-K, 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 the 1995 Form
10-K, 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 the 1995 Form 10-K, 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 the 1995 Form
10-K, 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 the 1995 Form 10-K, File No. 1-3548).
*10(f)1 - 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 the 1996 Form 10-K, File No. 1-3548).
*10(f)2 - Amendments to Receivables Purchase Agreement:
Number Dated as of Reference File Exhibit
----------- ----------------- ----------------------- -------
First February 28, 1997 1-3548 (1996 Form 10-K) 10(g)
Second August 15, 1997 1-3548 (September 30, 1997
Form 10-Q) 10
Third October 30, 1998 1-3548 (September 30, 1999
Form 10-Q) 10(a)
Fourth September 22, 1999 1-3548 (September 30, 1999
Form 10-Q) 10(b)
*10(g) - Purchase and Sale Agreement dated as of December 31, 1996, between
AFC Funding Corporation and Automotive Finance Corporation (filed as
Exhibit 10(h) to the 1996 Form 10-K, File No. 1-3548).
*10(h) - Power Purchase and Sale Agreement between the Company and Square
Butte Electric Cooperative, dated as of May 29, 1998 (filed as
Exhibit 10 to the June 30, 1998 Form 10-Q, File No. 1-3548).
32 Minnesota Power, Inc.
<PAGE>
Exhibit
Number
+*10(i) - Minnesota Power Executive Annual Incentive Plan, effective January 1,
1996 (filed as Exhibit 10(a) to the 1995 Form 10-K, File No. 1-3548).
+*10(j) - Minnesota Power and Affiliated Companies Supplemental Executive
Retirement Plan, as amended and restated, effective August 1, 1994
(filed as Exhibit 10(b) to the 1995 Form 10-K, File No. 1-3548).
+*10(k) - Executive Investment Plan-I, as amended and restated, effective
November 1, 1988 (filed as Exhibit 10(c) to the 1988 Form 10-K, File
No. 1-3548).
+*10(l) - Executive Investment Plan-II, as amended and restated, effective
November 1, 1988 (filed as Exhibit 10(d) to the 1988 Form 10-K, File
No. 1-3548).
+*10(m) - Deferred Compensation Trust Agreement, as amended and restated,
effective January 1, 1989 (filed as Exhibit 10(f) to the 1988 Form
10-K, File No. 1-3548).
+*10(n) - Minnesota Power Executive Long-Term Incentive Compensation Plan,
effective January 1, 1996 (filed as Exhibit 10(a) to the June 30,
1996 Form 10-Q, File No. 1-3548).
+*10(o) - Minnesota Power Director Stock Plan, effective January 1, 1995
(filed as Exhibit 10 to the March 31, 1995 Form 10-Q, File No.
1-3548).
+*10(p) - Minnesota Power Director Long-Term Stock Incentive Plan, effective
January 1, 1996 (filed as Exhibit 10(b) to the June 30, 1996 Form
10-Q, File No. 1-3548).
12 - Computation of Ratios of Earnings to Fixed Charges and Supplemental
Ratios of Earnings to Fixed Charges. (Included as page 59 of this
document.)
*21 - Subsidiaries of the Registrant (reference is made to the Company's
Form U-3A-2 for the year ended December 31, 1999, File No. 69-78).
23(a) - Consent of Independent Accountants.
23(b) - Consent of General Counsel.
27(a) - Financial Data Schedule for the year ended December 31, 1999.
27(b) - Restated Financial Data Schedule for the year ended December 31,
1998.
- -------------------------------
* Incorporated herein by reference as indicated.
+ Management contract or compensatory plan or arrangement required to be filed
as an exhibit to this report pursuant to Item 14(c) of Form 10-K.
(b) Reports on Form 8-K.
Report on Form 8-K dated and filed October 20, 1999 with respect to Item 5.
Other Events.
Report on Form 8-K dated and filed December 16, 1999 with respect to Item 5.
Other Events.
Report on Form 8-K dated and filed December 30, 1999 with respect to Item 5.
Other Events.
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 7, 2000 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 7, 2000
- ------------------------- Chief Executive Officer
Edwin L. Russell and Director
David G. Gartzke Senior Vice President - Finance February 7, 2000
- ------------------------- and Chief Financial Officer
David G. Gartzke
Mark A. Schober Controller February 7, 2000
- ------------------------
Mark A. Schober
Kathleen A. Brekken Director February 7, 2000
- -------------------------
Kathleen A. Brekken
Merrill K. Cragun Director February 7, 2000
- -------------------------
Merrill K. Cragun
Dennis E. Evans Director February 7, 2000
- -------------------------
Dennis E. Evans
Peter J. Johnson Director February 7, 2000
- -------------------------
Peter J. Johnson
George L. Mayer Director February 7, 2000
- -------------------------
George L. Mayer
Jack I. Rajala Director February 7, 2000
- -------------------------
Jack I. Rajala
Arend J. Sandbulte Director February 7, 2000
- -------------------------
Arend J. Sandbulte
Nick Smith Director February 7, 2000
- -------------------------
Nick Smith
Bruce W. Stender Director February 7, 2000
- -------------------------
Bruce W. Stender
Donald C. Wegmiller Director February 7, 2000
- -------------------------
Donald C. Wegmiller
34 Minnesota Power, Inc.
<PAGE>
Consolidated Financial Statements
For the Years Ended December 31, 1999, 1998 and 1997
with
Report of Independent Accountants
and
Report of Management
Minnesota Power, Inc. 35
<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 stockholders' equity
present fairly, in all material respects, the financial position of Minnesota
Power and its subsidiaries at December 31, 1999 and 1998, and the results of
their operations and their cash flows for each of the three years in the period
ended December 31, 1999, in conformity with accounting principles generally
accepted in the United States. 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 auditing standards generally accepted in the
United States 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 17, 2000
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 1999 1998
- --------------------------------------------------------------------------------
Millions
Assets
Current Assets
Cash and Cash Equivalents $ 101.5 $ 89.4
Trading Securities 179.6 169.9
Accounts Receivable 176.4 156.1
Inventories 24.2 24.0
Prepayments and Other 82.8 48.1
-------- --------
Total Current Assets 564.5 487.5
Property, Plant and Equipment 1,258.8 1,178.9
Investments 197.2 263.5
Goodwill 181.0 169.8
Other Assets 111.1 109.2
-------- --------
Total Assets $2,312.6 $2,208.9
- --------------------------------------------------------------------------------
Liabilities and Stockholders' Equity
Liabilities
Current Liabilities
Accounts Payable $ 124.7 $ 123.3
Accrued Taxes, Interest and Dividends 79.4 62.9
Notes Payable and Long-Term Debt Due
Within One Year 105.6 90.0
Other 88.6 69.8
-------- --------
Total Current Liabilities 398.3 346.0
Long-Term Debt 712.8 672.2
Accumulated Deferred Income Taxes 139.9 153.4
Other Liabilities 149.3 145.2
Commitments and Contingencies
-------- --------
Total Liabilities 1,400.3 1,316.8
-------- --------
Company Obligated Mandatorily Redeemable
Preferred Securities of Subsidiary MP&L
Capital I Which Holds Solely Company Junior
Subordinated Debentures 75.0 75.0
Redeemable Serial Preferred Stock 20.0 20.0
Stockholders' Equity
Cumulative Preferred Stock 11.5 11.5
Common Stock Without Par Value, 130.0
Shares Authorized 73.5 and 72.3
Shares Outstanding 552.0 529.0
Unearned ESOP Shares (59.2) (62.5)
Accumulated Other Comprehensive Income 2.4 1.5
Retained Earnings 310.6 317.6
-------- --------
Total Stockholders' Equity 817.3 797.1
-------- --------
Total Liabilities and Stockholders' Equity $2,312.6 $2,208.9
- --------------------------------------------------------------------------------
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 1999 1998 1997
- --------------------------------------------------------------------------------
Millions except per share amounts
Operating Revenue
Electric Services $ 554.5 $ 559.8 $541.9
Automotive Services 406.6 328.4 255.5
Water Services 112.9 95.6 95.5
Investments 57.8 55.5 60.7
--------- --------- ------
Total Operating Revenue 1,131.8 1,039.3 953.6
--------- --------- ------
Operating Expenses
Fuel and Purchased Power 200.2 205.7 194.1
Operations 705.9 635.4 579.9
Interest Expense 59.5 64.9 64.2
--------- --------- ------
Total Operating Expenses 965.6 906.0 838.2
--------- --------- ------
Operating Income before Capital Re 166.2 133.3 115.4
Income (Loss) from Investment in Capital Re (34.5) 15.2 14.8
--------- --------- ------
Operating Income 131.7 148.5 130.2
Distributions on Redeemable Preferred
Securities of Subsidiary 6.0 6.0 6.0
Income Tax Expense 57.7 54.0 46.6
--------- --------- ------
Net Income 68.0 88.5 77.6
Dividends on Preferred Stock 2.0 2.0 2.0
--------- --------- ------
Earnings Available for Common Stock $ 66.0 $ 86.5 $ 75.6
--------- --------- ------
Average Shares of Common Stock 68.4 64.0 61.2
Basic and Diluted
Earnings Per Share of Common Stock $0.97 $1.35 $1.24
Dividends Per Share of Common Stock $1.07 $1.02 $1.02
- --------------------------------------------------------------------------------
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 1999 1998 1997
- --------------------------------------------------------------------------------
Millions
Operating Activities
Net Income $ 68.0 $ 88.5 $ 77.6
Loss (Income) From Investment in Capital Re
- Net of Dividends Received 34.5 (14.1) (13.9)
Depreciation and Amortization 76.9 75.0 70.8
Deferred Income Taxes (12.8) 1.1 2.0
Pre-Tax (Gain) Loss on Sale of Property - (0.6) (14.0)
Changes In Operating Assets and Liabilities
- Net of the Effects of Acquisitions
Trading Securities 16.1 (46.4) (36.7)
Accounts Receivable (20.3) (9.7) 20.0
Inventories (0.2) 1.0 (1.8)
Accounts Payable 1.4 26.4 20.9
Other Current Assets and Liabilities 0.3 5.1 (5.0)
Other - Net 9.9 20.0 12.5
------- ------ -------
Cash From Operating Activities 173.8 146.3 132.4
------- ------ -------
Investing Activities
Proceeds From Sale of Investments 67.6 35.2 47.7
Proceeds From Sale of Property - 1.4 19.4
Additions to Investments (27.5) (33.1) (42.5)
Additions to Property, Plant and Equipment (99.7) (80.8) (72.2)
Acquisitions - Net of Cash Acquired (93.6) (23.8) (2.4)
Other - Net (16.9) 2.3 17.5
------- ------ -------
Cash For Investing Activities (170.1) (98.8) (32.5)
------- ------ -------
Financing Activities
Issuance of Long-Term Debt 51.5 2.0 176.7
Issuance of Common Stock 21.8 111.0 19.7
Changes in Notes Payable - Net 15.5 (48.1) (27.2)
Reductions of Long-Term Debt (9.9) (10.0) (187.8)
Dividends on Preferred and Common Stock (75.0) (67.0) (64.5)
------- ------ -------
Cash From (For) Financing Activities 3.9 (12.1) (83.1)
------- ------ -------
Effect of Exchange Rate Changes on Cash 4.5 (3.9) (1.7)
------- ------ -------
Change in Cash and Cash Equivalents 12.1 31.5 15.1
------- ------ -------
Cash and Cash Equivalents at Beginning of
Period 89.4 57.9 42.8
------- ------ -------
Cash and Cash Equivalents at End of Period $ 101.5 $ 89.4 $ 57.9
------- ------ -------
Supplemental Cash Flow Information
Cash Paid During the Period For
Interest - Net of Capitalized $61.3 $63.0 $66.2
Income Taxes $60.3 $54.4 $31.3
- --------------------------------------------------------------------------------
The accompanying notes are an integral part of these statements.
Minnesota Power, Inc. 39
<PAGE>
<TABLE>
MINNESOTA POWER CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY
<CAPTION>
Accumulated
Total Other Unearned Cumulative
Stockholders' Retained Comprehensive ESOP Common Preferred
Equity Earnings Income Shares Stock Stock
- -----------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
Millions
Balance at December 31, 1996 $622.3 $283.0 $2.7 $(69.1) $394.2 $11.5
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 661.5 296.1 3.8 (65.9) 416.0 11.5
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 797.1 317.6 1.5 (62.5) 529.0 11.5
Comprehensive Income
Net Income 68.0 68.0
Other Comprehensive Income - Net of Tax
Unrealized Losses on Securities - Net (3.6) (3.6)
Foreign Currency Translation Adjustments 4.5 4.5
------
Total Comprehensive Income 68.9
Common Stock Issued - Net 23.0 23.0
Dividends Declared (75.0) (75.0)
ESOP Shares Earned 3.3 3.3
------ ------ ---- ------ ------ -----
Balance at December 31, 1999 $817.3 $310.6 $2.4 $(59.2) $552.0 $11.5
- ---------------------------------------------------------------------------------------------------------------------------
The accompanying notes are an integral part of these statements.
</TABLE>
40 Minnesota Power, Inc.
<PAGE>
NOTES TO FINANCIAL STATEMENTS
1. BUSINESS SEGMENTS
Millions
<TABLE>
<CAPTION>
Electric Automotive Water Corporate
For the Year Ended December 31 Consolidated Services Services Services Investments Charges
- -----------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
1999
Operating Revenue $1,131.8 $554.5 $406.6<F1> $112.9 $ 58.2 $ (0.4)
Operation and Other Expense 829.2 412.6 308.7 69.8 23.7<F3> 14.4
Depreciation and Amortization 76.9 45.2 17.7 13.5 0.2 0.3
Interest Expense 59.5 21.2 10.9 10.0 0.4 17.0
-------- ------ ------ ------ ------- ------
Operating Income (Loss) Before Capital Re 166.2 75.5 69.3 19.6 33.9 (32.1)
Loss from Investment in Capital Re (34.5) - - - (34.5) -
-------- ------ ------ ------ ------- ------
Operating Income (Loss) 131.7 75.5 69.3 19.6 (0.6) (32.1)
Distributions on Redeemable
Preferred Securities of Subsidiary 6.0 1.7 - - - 4.3
Income Tax Expense (Benefit) 57.7 28.8 29.4 7.4 8.8 (16.7)
-------- ------ ------ ------ ------- ------
Net Income (Loss) $ 68.0 $ 45.0 $ 39.9 $ 12.2 $ (9.4) $(19.7)
-------- ------ ------ ------ ------- ------
Total Assets $2,312.6 $995.7 $664.8<F2> $314.8 $ 336.9 $0.4
Property, Plant and Equipment $1,258.8 $770.0 $234.0 $254.8 - -
Accumulated Depreciation and Amortization $879.7 $629.7 $57.4 $190.7 $1.9 -
Capital Expenditures $99.7 $47.7 $23.8 $26.9 $0.9 $0.4
- -----------------------------------------------------------------------------------------------------------------------------
1998
Operating Revenue $1,039.3 $559.8 $328.4<F1> $ 95.6 $ 55.8 $ (0.3)
Operation and Other Expense 766.1 411.3 256.1 61.0 22.5<F3> 15.2
Depreciation and Amortization 75.0 47.1 15.7 11.8 0.1 0.3
Interest Expense 64.9 22.1 9.7 10.3 - 22.8
-------- ------ ------ ------ ------- ------
Operating Income (Loss) Before Capital Re 133.3 79.3 46.9 12.5 33.2 (38.6)
Income from Investment in Capital Re 15.2 - - - 15.2 -
-------- ------ ------ ------ ------- ------
Operating Income (Loss) 148.5 79.3 46.9 12.5 48.4 (38.6)
Distributions on Redeemable
Preferred Securities of Subsidiary 6.0 1.7 - - - 4.3
Income Tax Expense (Benefit) 54.0 30.2 21.4 5.0 18.8 (21.4)
-------- ------ ------ ------ ------- ------
Net Income (Loss) $ 88.5 $ 47.4 $ 25.5 $ 7.5 $ 29.6 $(21.5)
-------- ------ ------ ------ ------- ------
Total Assets $2,208.9 $998.6 $529.3<F2> $269.1 $411.6 $0.3
Property, Plant and Equipment $1,178.9 $770.2 $186.2 $222.5 - -
Accumulated Depreciation and Amortization $775.6 $596.1 $42.7 $135.2 $1.6 -
Capital Expenditures $80.8 $36.1 $22.0 $21.8 $0.1 $0.8
- -----------------------------------------------------------------------------------------------------------------------------
1997
Operating Revenue $ 953.6 $541.9 $255.5<F1> $ 95.5 $ 60.9 $ (0.2)
Operation and Other Expense 703.2 403.7 203.2 60.6 24.0<F3> 11.7
Depreciation and Amortization 70.8 45.2 14.0 11.2 0.1 0.3
Interest Expense 64.2 21.3 9.9 11.0 0.8 21.2
-------- ------ ------ ------ ------- ------
Operating Income (Loss) Before Capital Re 115.4 71.7 28.4 12.7 36.0 (33.4)
Income from Investments in Captital Re 14.8 - - - 14.8 -
-------- ------ ------ ------ ------- ------
Operating Income (Loss) 130.2 71.7 28.4 12.7 50.8 (33.4)
Distributions on Redeemable
Preferred Securities of Subsidiary 6.0 1.6 - - - 4.4
Income Tax Expense (Benefit) 46.6 27.0 14.4 4.5 18.7 (18.0)
-------- ------ ------ ------ ------- ------
Net Income (Loss) $ 77.6 $ 43.1 $ 14.0 $ 8.2 $ 32.1 $(19.8)
-------- ------ ------ ------ ------- ------
Total Assets $2,086.3 $972.5 $474.7<F2> $283.5 $ 354.9 $0.7
Property, Plant and Equipment $1,170.2 $782.1 $167.1 $221.0 - -
Accumulated Depreciation and Amortization $713.2 $562.1 $122.9 $26.9 $1.3 -
Capital Expenditures $72.2 $34.6 $22.2 $11.2 $0.2 $4.0
- -----------------------------------------------------------------------------------------------------------------------------
<FN>
<F1> Included $56.8 million of Canadian operating revenue in 1999 ($36.2 million
in 1998; $25.1 million in 1997).
<F2> Included $119.3 million of Canadian assets in 1999 ($60.9 million in 1998
$44.3 million in 1997).
<F3> Included $1.8 million of minority interest in 1999 ($2.0 million in 1998;
$2.3 million in 1997).
</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.
BUSINESS SEGMENTS. Minnesota Power is a multi-services company that has
operations in four principal business segments. The Electric Services,
Automotive Services and Water Services segments were determined based on
products and services provided. The Investment 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 SERVICES. Electric Services generate, transmit, distribute and market
electricity. Native load electric service is provided to 140,000 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 Services- Large Power Customers in this
Form 10-K.) MPEX, a division of Minnesota Power, markets power across the
Midwest and Canada. 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 5.)
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.
AUTOMOTIVE SERVICES. Automotive Services include wholly owned subsidiaries
operating as integral parts of the vehicle redistribution business: ADESA, a
network of vehicle auctions; AFC, a finance company; Great Rigs, an auto
transport company; PAR, a vehicle remarketing company; and AutoVIN, a provider
of field information services to the automotive industry. ADESA is the second
largest vehicle auction network in North America.
ADESA owns and operates 29 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. 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 150 automotive carriers. It offers customers
pick up and delivery service through 13 strategically located transportation
hubs in the United States. PAR provides customized remarketing services,
including transporting and liquidating off-lease vehicles, to various businesses
with fleet operations. AutoVIN provides professional field information services
to the automotive industry, including vehicle condition reporting, inventory
verification auditing, program compliance auditing and facility inspection.
ADESA, Great Rigs, PAR and AutoVIN 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 revenue is reported net of interest expense of $2.0 million in 1999
($1.8 million in 1998; $1.5 million in 1997). AFC generally sells its United
States dollar denomination financed receivables through a private securitization
structure. Gains and losses on such sales are generally recognized at the time
of settlement based on the difference between the sales proceeds and the
allocated basis of the finance receivables sold, adjusted for transaction fees
and residual interest retained. AFC also retains the right to service
receivables sold through the securitization and receives a fee for doing so.
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 is the largest investor owned
water utility in North Carolina. Heater also provides wastewater services in
North Carolina. In total, 184,000 water and 72,000 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. and
42 Minnesota Power, Inc.
<PAGE>
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.
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. Investments also include intermediate-term investments in
venture capital funds that invest in developing utility technologies. The
Company's Real Estate Operations include Cape Coral Holdings, Inc. 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.
DEPRECIATION. Property, plant and equipment are recorded at original cost, and
are reported on the balance sheet net of accumulated depreciation and
contributions in aid of construction. Expenditures for additions and significant
replacements and improvements are capitalized; maintenance and repair costs are
expensed as incurred. When property, plant and equipment are retired or
otherwise disposed of, gains or losses are recognized in revenue. When utility
property, plant and equipment are retired or otherwise disposed of, no gain or
loss is recognized. Contributions in aid of construction relate to utility
assets, and are amortized over the estimated life of the associated asset. This
amortization reduces depreciation expense. Contributions in aid of construction
relate to water assets and amounted to $189.6million in 1999 ($108.2 million in
1998).
Depreciation is computed using the estimated useful lives of the various classes
of plant. In 1999 average depreciation rates for the electric, automotive and
water services segments were 3.3%, 3.9% and 2.2%, respectively (3.5%, 4.1% and
2.6%, respectively, in 1998; 3.4%, 4.1% and 2.7%, respectively, in 1997).
ACCOUNTS RECEIVABLE. Accounts receivable is reported on the balance sheet net of
an allowance for doubtful accounts. The allowance is 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 certain finance receivables on a revolving basis to a wholly owned,
unconsolidated, qualified special purpose subsidiary. This subsidiary in turn
sells, on a revolving basis, an undivided interest in eligible finance
receivables, up to a maximum at any one time outstanding of $300.0 million, to
third party purchasers under an agreement which expires at the end of 2002.
Unsold finance receivables held by the special purpose subsidiary are recorded
by AFC as a residual interest at fair value. 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. The residual interest is recorded in
prepayments and other assets, with unrealized gains and losses recognized in
earnings. At December 31, 1999 AFC had sold $296.8 million of finance
receivables to the special purpose subsidiary ($202.9million at December 31,
1998). Third party purchasers had purchased an undivided interest in finance
receivables of $225million from this subsidiary at December 31, 1999 ($170.0
million at December 31, 1998). Fair value of the residual interest was $57.6
million at December 31, 1999 ($20.1 million at December 31, 1998).
Accounts Receivable
December 31 1999 1998
--------------------------------------------------------------------------
Millions
Trade Accounts Receivable $120.6 $116.0
Less: Allowance for Doubtful Accounts 7.6 6.0
------ ------
113.0 110.0
------ ------
Finance Receivables 366.5 252.6
Less: Amount Sold 296.8 202.9
Allowance for Doubtful Accounts 6.3 3.6
------ ------
63.4 46.1
------ ------
Total Accounts Receivable $176.4 $156.1
---------------------------------------------------------------------------
INVENTORIES. Inventories, which include 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.
Operating expenses in 1999 included $5.1 million of goodwill amortization ($4.9
million in 1998; $4.4 million in 1997).
UNAMORTIZED EXPENSE, DISCOUNT AND PREMIUM ON DEBT. Expense, discount and premium
on debt are deferred and amortized over the lives of the related issues.
Minnesota Power, Inc. 43
<PAGE>
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.
3. ACQUISITIONS AND DIVESTITURES
ACQUISITION OF PALM COAST UTILITY CORPORATION. In January 1999 Florida Water
purchased the assets and assumed certain liabilities of PCUC from ITT
Industries, Inc. for $16.8 million plus $1,000 per new water connection for an
eight-year period. The Company estimates the present value of these future water
connections at $5.1 million. PCUC provides service to approximately 19,000 water
and 14,000 wastewater customers in Flagler County, Florida. The transaction was
accounted for using the purchase method. Financial results have been included in
the Company's consolidated financial statements since the date of purchase.
Financial results prior to the acquisition were not material.
ACQUISITION OF AUCTION FACILITIES. In April 1999 ADESA acquired Des Moines Auto
Auction located in Des Moines, Iowa and in July 1999 ADESA Canada, Inc.
purchased the Vancouver Auto Auction of New Westminster, British Columbia. The
two transactions had a combined purchase price of $31.3 million and were
accounted for using the purchase method resulting in goodwill of $11.9 million.
Financial results for each facility have been included in the Company's
consolidated financial statements since the date of purchase. Financial results
prior to the acquisition were not material. The 33-acre Des Moines facility has
three auction lanes while the 70-acre Vancouver facility has six auction lanes.
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.
ACQUISITION OF CAPE CORAL. In June 1999 Cape Coral Holdings, Inc. (Cape Coral
Holdings), a subsidiary of MP Real Estate, purchased, for $45.0 million, certain
real estate properties located in Cape Coral, Florida, from subsidiaries of
Avatar Holdings Inc., a publicly traded developer and home builder headquartered
in Coral Gables, Florida. Cape Coral, located adjacent to Fort Myers, Florida,
has a population of 100,000 and is Florida's second largest municipality in land
area. Properties purchased include approximately 2,500 acres of commercial and
residential zoned land, including home sites, a golf resort, marina and
commercial buildings. Concurrently with the purchase, Cape Coral Holdings
assigned to a third party the rights to a shopping center and a portion of the
vacant land for $8.8 million, which reduced the net amount paid by Cape Coral
Holdings to $36.2 million. The transaction was accounted for using the purchase
method. Financial results have been included in the Company's consolidated
financial statements since the date of purchase. Financial results prior to the
acquisition were not material.
MID SOUTH WATER SYSTEMS, INC. In June 1999 Heater acquired the assets of Mid
South Water Systems, Inc. (Mid South) located in Sherills Ford, North Carolina
for $9 million. The acquisition was accounted for using the purchase method.
Financial results have been included in the Company's consolidated financial
statements since the date of purchase. Financial results prior to the
acquisition were not material. Mid South serves approximately 12,000 customers.
ACQUISITION OF LAGRANGE. In September 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.
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.
44 Minnesota Power, Inc.
<PAGE>
4. SHORT-TERM BORROWINGS AND COMPENSATING BALANCES
The Company has bank lines of credit aggregating $75 million ($74 million at
December 31, 1998), which make financing available through short-term bank loans
and provide support for commercial paper. At December 31, 1999, $74 million was
available for use ($34 million at December 31, 1998). At December 31, 1999 the
Company had issued commercial paper with a face value of $96.9million ($41
million in 1998), 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 6.42% to
6.70% at December 31, 1999 (5.7% to 7.75% at December 31, 1998). The weighted
average interest rate on short-term borrowings at December 31, 1999 was 6.59%
(5.8% at December 31, 1998). The total amount of compensating balances at
December 31, 1999 and 1998, was immaterial.
5. SQUARE BUTTE POWER PURCHASE AGREEMENT
The Company has had a power purchase agreement with Square Butte since 1977
which has provided a long-term supply of low-cost energy to customers in the
Company's electric service territory and enabled the Company to meet power pool
reserve requirements. Square Butte, a North Dakota electric 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%.
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. Square Butte's fixed costs consist
primarily of debt service. At December 31, 1999 Square Butte had total debt
outstanding of $343.1 million. Total annual debt service for Square Butte is
expected to be approximately $36 million in each of the years 2000 through 2003
and $23 million in 2004. 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 1999 was $58.7
million ($58.2 million in 1998; $56.9 million in 1997). This reflects the
Company's pro rata share of total Square Butte costs based on the 71% output
entitlement in 1999, 1998 and 1997. Included in this amount was the Company's
pro rata share of interest expense of $15.5 million in 1999 ($14.6million in
1998; $12.4 million in 1997). The Company's payments to Square Butte are
approved as purchased power expense for ratemaking purposes by both the MPUC and
FERC.
6. LEASING AGREEMENTS
ADESA leases three auction facilities which have five year lease terms ending in
2000 with no renewal options. 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. ADESA expects to refinance these leases on or before
April 1, 2000. Total lease expense at ADESA was $17.2 million in 1999 ($14.9
million in 1998; $9.6 million in 1997).
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 2000 is $13.5 million ($10.0 million in 2001; $7.1
million in 2002; $3.3 million in 2003; and $3.0 million in 2004). Total rent
expense was $18.5 million in 1999 ($15.6 million in 1998; $10 million in 1997).
Minnesota Power, Inc. 45
<PAGE>
7. 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. Interim rates in Minnesota and Florida are placed into
effect, subject to refund with interest, pending a final decision by the
appropriate commission. In 1999 47% of the Company's consolidated operating
revenue (52% in 1998, 55% in 1997) was under regulatory authority. The MPUC had
regulatory authority over approximately 31% in 1999 (36% in 1998; 39% in 1997)
of the Company's consolidated operating revenue.
ELECTRIC RATES. Restructuring of the electric utility industry continues.
Twenty-four states representing approximately two-thirds of the United States
population have either passed legislation or regulation that initiates retail
customer choice. Neither Minnesota nor Wisconsin (where Minnesota Power has
retail electric customers) have passed retail restructuring laws. In 2000,
utility restructuring legislation will be debated at both the federal level and
in Minnesota and Wisconsin. It is unlikely, however, that Congress or the
legislatures of Minnesota or Wisconsin will enact retail choice legislation into
law this year. The Company cannot predict the timing or substance of any future
legislation that might ultimately be enacted. The Company, however, is taking
all necessary steps to cultivate community and customer relations, and continues
to maintain its competitive position as a low-cost and long-term power supplier
to large industrial customers. With electric rates among the lowest in the
United States, customer satisfaction high, and long-term wholesale and Large
Power Customer retail contracts in place, Minnesota Power believes Electric
Services is well positioned for the future.
WATER AND WASTEWATER RATES. 1995 RATE CASE. In September 1999 the FPSC issued a
final order that approved a 1999 settlement agreement with Florida Water to
resolve open items pertaining to its 1995 rate case. The final order increased
annual revenue by approximately $1 million; authorized Florida Water to book
approximately $8.5 million of accumulated surcharges, including interest, as a
regulatory asset recoverable in base rates beginning in the next rate case; and
provided a three-year moratorium on the initiation of rate cases by Florida
Water, exclusive of index filings. Index filings provide rate adjustments based
on inflationary costs associated with operation and maintenance expenses. The
annual rate increase of approximately $1 million associated with the settlement
became effective on October 1, 1999. The FPSC previously approved annual rate
increases in connection with the 1995 rate case of approximately $11.1 million
and $1.2 million effective in September 1996 and January 1999, respectively. In
total, the FPSC approved $13.6 million of the $18.1 million rate increase
requested by Florida Water in the 1995 rate case.
1991 RATE CASE REFUNDS. In 1995 the Florida First District Court of Appeals
(Court of Appeals) reversed a 1993 FPSC order establishing uniform rates for
most of Florida Water's service areas. With "uniform rates" all customers in
each uniform rate area pay the same rates for water and wastewater services. In
response to the Court of Appeals' order, in August 1996 the FPSC ordered Florida
Water to issue refunds to those customers who paid more since October 1993 under
uniform rates than they would have paid under stand-alone rates. This order did
not permit a balancing surcharge to customers who paid less under uniform rates.
Florida Water appealed, and the Court of Appeals ruled in June 1997 that the
FPSC could not order refunds without balancing surcharges. In response to the
Court of Appeals' ruling, the FPSC issued an order in January 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 1998 order, the FPSC required Florida Water to refund, with
interest, $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 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 in May 1998. In
June 1998 the Court of Appeals reversed its previous ruling that the FPSC was
without authority to order uniform rates at which time 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 in September 1998. A mediation
session was held in September 1999. The parties could not reach settlement of
any issues. A provision for refund related to the $2.5 million refund order was
recorded in 1999. The Company is unable to predict the timing or outcome of the
appeals process.
46 Minnesota Power, Inc.
<PAGE>
DEFERRED REGULATORY CHARGES AND CREDITS. Deferred regulatory charges and credits
are included in other assets and other liabilities on the Company's consolidated
balance sheet. 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. Based on
current rate treatment, the Company believes all deferred regulatory charges are
probable of recovery.
Deferred Regulatory Charges and Credits
December 31 1999 1998
------------------------------------------------------------------------------
Millions
Deferred Charges
Income Taxes $17.0 $17.9
Conservation Improvement Programs 13.5 18.8
Postretirement Benefits - 2.8
Premium on Reacquired Debt 5.6 6.2
Other 21.5 10.4
----- -----
57.6 56.1
Deferred Credits
Income Taxes 55.1 55.2
----- -----
Net Deferred Regulatory Charges $ 2.5 $ 0.9
------------------------------------------------------------------------------
8. 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, 1999 was $310 million ($304million at December 31, 1998). The
corresponding provision for accumulated depreciation was $150 million at
December31, 1999 ($143 million at December 31, 1998).
9. INVESTMENT IN CAPITAL RE
On December 30, 1999 the shareholders of Capital Re Corporation (Capital Re)
approved the merger of Capital Re with ACE Limited (ACE) and the transaction
closed. Each Capital Re share was exchanged for 0.65 common shares of ACE plus
$3.4456 in cash which delivered an approximate value of $14 for each Capital Re
share.
In exchange for its 7.3 million shares of Capital Re, Minnesota Power received
4.7 million common shares of ACE and $25.1 million in cash. Based on the
December 29, 1999 $16.75 closing price of ACE, the total value of proceeds
received was $104.4 million. Minnesota Power recorded an additional $12.1
million non-cash charge to net income during the fourth quarter of 1999 to
reflect the final valuation of this transaction. This charge combined with a
$24.1 million non-cash charge recorded in June 1999 resulted in a total 1999
charge of $36.2 million to Minnesota Power's net income. Minnesota Power owned
20% of Capital Re before the merger. At December 31, 1999 Minnesota Power owned
2% of ACE.
In 1998 and 1997 Minnesota Power used the equity method to account for its
investment in Capital Re. As a result of the pending merger with ACE, in 1999
Minnesota Power discontinued the equity method of accounting for its investment
in Capital Re and accounted for its investment in Capital Re as an
available-for-sale security.
Minnesota Power, Inc. 47
<PAGE>
10. FINANCIAL INSTRUMENTS
SECURITIES INVESTMENTS. The Company's securities portfolio is managed internally
and by selected outside managers. Securities held principally for near-term sale
are classified as trading 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. Securities held for an
indefinite period of time are classified as available-for-sale securities and
included in investments 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. Prior to 1999, available-for-sale
securities consisted primarily of the preferred stock of utilities and financial
institutions with investment grade debt ratings. During 1999, the Company
changed its strategy for this preferred stock resulting in a reclassification to
trading securities. An unrealized pre-tax loss of $2.6 million was recognized in
earnings as a result of this reclassification. The table below does not include
the proceeds and realized loss on the merger of Capital Re with ACE. (See Note
9.) At December 31, 1999 available-for-sale securities consisted of 4.7 million
shares of ACE Limited and securities in a grantor trust established to fund
certain employee benefits.
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
----- ---- ------ ----- -------- ---- ------ --------------
1999 $87.8 $6.3 $(0.3) $93.8 $0.2 - - $1.6
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
- --------------------------------------------------------------------------------
Prior to discontinuance of the equity method of accounting in 1999, the Company
also recorded its share of unrealized gains and losses from available-for-sale
securities held by Capital Re. Unrealized gains recorded in accumulated other
comprehensive income from available-for-sale securities held by Capital Re were
$5.5 million and $5.0 million in 1998 and 1997, respectively.
The net unrealized loss included in earnings for trading securities in 1999 was
$1.6 million ($0.7 million loss in 1998; $2.0 million gain in 1997).
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. Treasury futures are
used as a hedge to reduce interest rate risks associated with holding fixed
dividend preferred stocks. Generally, treasury futures contracts entered into
have a maturity date of 90 days. Realized and unrealized gains and losses from
the short sales of common stock are included in investment income. Prior to
1999, gains and losses on treasury futures were deferred and recognized in
earnings concurrently with gains and losses from the underlying preferred stock
being hedged. During 1999, the hedged preferred stock was reclassified from
available-for-sale to trading, and accordingly, realized and unrealized gains
and losses from the short sale of treasury futures contracts are now included in
investment income.
In December 1998 Florida Water entered into an interest rate swap agreement with
a notional amount of $35.1 million to hedge its fixed rate long-term debt. Under
the 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 (4.7% at December 31, 1999 and 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.
The Fair Value of off-balance sheet financial instruments reflected the
estimated amounts that the Company would receive or pay if the contracts were
terminated at December 31. This Fair Value represents the difference between the
estimated future receipts and payments under the terms of each instrument, and
is estimated by obtaining quoted market prices or by using common pricing
models. These Fair Values should not be viewed in isolation, but rather in
relation to the fair value of the underlying hedged transaction.
48 Minnesota Power, Inc.
<PAGE>
Off-Balance-Sheet Financial Instruments
December 31 1999 1998
- --------------------------------------------------------------------------------
Millions
Fair Value Fair Value
Contract Receivable Contract Receivable
Amount (Payable) Amount (Payable)
-------- ---------- -------- ----------
Short Stock Sales Outstanding $58.5 $(2.1) $74.4 $(3.8)
Treasury Futures $8.6 $0.2 $25.0 $0.5
Interest Rate Swap $35.1 $(2.3) $35.1 $(0.4)
- --------------------------------------------------------------------------------
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 1999 1998
- --------------------------------------------------------------------------------
Millions
Carrying Fair Carrying Fair
Amount Value Amount Value
-------- ------ -------- ------
Long-Term Debt $712.8 $694.5 $672.2 $717.3
Redeemable Serial Preferred Stock $20.0 $20.0 $20.0 $21.3
Quarterly Income Preferred Securities $75.0 $65.3 $75.0 $76.1
- --------------------------------------------------------------------------------
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. Receivables from these
customers totaled approximately $8.2 million at December 31, 1999 ($9 million at
December 31, 1998). The Company does not obtain collateral to support utility
receivables, but monitors the credit standing of major customers.
11. PREFERRED STOCK
Preferred Stock
December 31 1999 1998
------------------------------------------------------------------------------
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
------------------------------------------------------------------------------
Minnesota Power, Inc. 49
12. LONG-TERM DEBT
Long-Term Debt
December 31 1999 1998
- --------------------------------------------------------------------------------
Millions
Minnesota Power
First Mortgage Bonds
61/4% Series Due 2003 $ 25.0 $ 25.0
6.68% Series Due 2007 20.0 20.0
7% Series Due 2007 60.0 60.0
71/2% Series Due 2007 35.0 35.0
73/4% 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 4.6 4.8
Leveraged ESOP Loan, 9.125%, Due 2000 - 2004 8.9 10.2
Other Long-Term Debt, Variable, Due 2001 - 2013 7.6 7.4
Subsidiary Companies
First Mortgage Bonds, 8.46%, Due 2013 54.7 54.8
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 2000 - 2026 98.0 55.9
Less Due Within One Year (9.1) (9.0)
------ ------
Total Long-Term Debt $712.8 $672.2
- --------------------------------------------------------------------------------
The aggregate amount of long-term debt maturing during 2000 is $9.1 million
($13.9 million in 2001; $14.4 million in 2002; $48.6 million in 2003; and $15.5
million in 2004). Substantially all Company electric and water plant is subject
to the lien of the mortgages securing various first mortgage bonds.
At December 31, 1999 subsidiaries of the Company had long-term bank lines of
credit aggregating $58.8 million ($13.8 million at December 31, 1998). Drawn
portions on these lines of credit aggregate $43.5 million at December 31, 1999
($0 at December 31, 1998) and are included in subsidiary companies other
long-term debt.
50 Minnesota Power, Inc.
<PAGE>
13. 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, 1999 no
retained earnings were restricted as a result of these provisions.
COMMON STOCK SPLIT. On March 2, 1999 the Company's Common Stock was split
two-for-one. All common share and per share amounts in these financial
statements and notes to the financial statements have been adjusted for all
periods to reflect the two-for-one stock split.
Summary of Common Stock Shares Equity
-------------------------------------------------------------------------------
Millions
Balance at December 31, 1996 65.5 $394.2
1997 Employee Stock Purchase Plan - 0.9
Dividend Reinvestment and Stock Purchase Plan 1.2 18.6
Other 0.4 2.3
---- ------
Balance at December 31, 1997 67.1 416.0
1998 Public Offering 4.2 89.9
Employee Stock Purchase Plan - 0.9
Dividend Reinvestment and Stock Purchase Plan 0.8 17.1
Other 0.2 5.1
---- ------
Balance at December 31, 1998 72.3 529.0
1999 Employee Stock Purchase Plan 0.1 1.3
Dividend Reinvestment and Stock Purchase Plan 0.9 17.4
Other 0.2 4.3
---- ------
Balance at December 31, 1999 73.5 $552.0
-------------------------------------------------------------------------------
COMMON STOCK ISSUANCE. In September 1998 4.2 million shares of the Company's
Common Stock were sold in a public offering at $21.875 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 two-hundredth of a share of
Junior Serial Preferred Stock A, without par value, at an exercise price of $45,
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 $.005 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.
Minnesota Power, Inc. 51
<PAGE>
14. INCOME TAX EXPENSE
Income Tax Expense
Year Ended December 31 1999 1998 1997
--------------------------------------------------------------------------
Millions
Current Tax Expense
Federal $57.6 $38.5 $31.9
Foreign 6.9 4.9 3.2
State 6.0 9.8 10.0
----- ----- -----
70.5 53.2 45.1
----- ----- -----
Deferred Tax Expense (Benefit)
Federal (6.4) 0.9 4.8
Foreign (0.4) (0.4) (0.1)
State (5.2) (0.4) (1.5)
----- ----- -----
(12.0) 0.1 3.2
----- ----- -----
Change in Valuation Allowance 0.7 2.3 (0.4)
----- ----- -----
Deferred Tax Credits (1.5) (1.6) (1.3)
----- ----- -----
Total Income Tax Expense $57.7 $54.0 $46.6
--------------------------------------------------------------------------
Reconciliation of Taxes from Federal Statutory Rate
to Total Income Tax Expense
Year Ended December 31 1999 1998 1997
--------------------------------------------------------------------------
Millions
Tax Computed at Federal Statutory
Rate $44.0 $49.8 $43.5
Increase (Decrease) in Tax
State Income Taxes - Net of
Federal Income Tax Benefit 6.5 6.6 5.6
Capital Re Transaction 10.8 - -
Dividend Received Deduction (1.4) (2.7) (2.0)
Foreign Taxes 2.3 2.0 0.9
Tax Credits (3.3) (2.4) (2.2)
Other (1.2) 0.7 0.8
----- ----- -----
Total Income Tax Expense $57.7 $54.0 $46.6
--------------------------------------------------------------------------
Deferred Tax Assets and Liabilities
December 31 1999 1998
--------------------------------------------------------------------------
Millions
Deferred Tax Assets
Allowance for Bad Debts $ 10.1 $ 7.0
Contributions in Aid of
Construction 16.3 20.3
Lehigh Basis Difference 7.8 9.7
Deferred Compensation Plans 19.2 18.9
Depreciation 13.4 13.0
Employee Stock Ownership Plan 8.6 7.7
Investment Tax Credits 19.7 20.8
Postemployment Benefits 8.8 7.8
Other 33.5 27.6
------ -----
Gross Deferred Tax Assets 137.4 132.8
Deferred Tax Asset Valuation
Allowance (3.3) (2.6)
------ -----
Total Deferred Tax Assets 134.1 130.2
------ -----
Deferred Tax Liabilities
Depreciation 196.7 198.9
Allowance for Funds Used During
Construction 16.9 15.0
Income from Equity Investments - 10.1
Investment Tax Credits 28.0 29.6
Unrealized Portfolio Gains 7.9 3.8
Other 24.5 26.2
------ -----
Total Deferred Tax Liabilities 274.0 283.6
------ -----
Accumulated Deferred Income Taxes $139.9 $153.4
--------------------------------------------------------------------------
52 Minnesota Power, Inc.
<PAGE>
UNDISTRIBUTED EARNINGS. Undistributed earnings of the Company's foreign
subsidiaries were approximately $19.3 million at December 31, 1999 ($9.7 million
at December 31, 1998). 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 $1.0 million would be payable upon
remittance of all previously unremitted earnings at December 31, 1999 ($0.5
million at December 31, 1998).
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
1997
Net 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
Gain Arising During the Year $ 1.9 $0.7 $ 1.2
Add: Loss Included in Net Income 0.6 0.2 0.4
----- ---- -----
Net Unrealized Gain on Securities 2.5 0.9 1.6
Foreign Currency Translation Adjustments (3.9) - (3.9)
----- ---- -----
Other Comprehensive Loss $(1.4) $0.9 $(2.3)
----- ---- -----
1999
Gain Arising During the Year $ 1.6 $0.7 $ 0.9
Add: Loss Included in Net Income 1.7 0.7 1.0
Less: Unrealized Gains of Disposed Equity Investee 6.7 1.2 5.5
----- ---- -----
Net Unrealized Loss on Securities (3.4) 0.2 (3.6)
Foreign Currency Translation Adjustments 4.5 - 4.5
----- ---- -----
Other Comprehensive Income $ 1.1 $0.2 $ 0.9
- -----------------------------------------------------------------------------------------------------------------------
</TABLE>
Accumulated other comprehensive income at December 31, 1999 consisted of $3.5
million ($7.1 million at December 31, 1998) in net unrealized gains on
securities and $(1.1) million ($(5.6) million at December 31, 1998) 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 1.2 million 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 5.6 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.
Year Ended December 31 1999 1998 1997
------------------------------------------------------------------------------
Millions
Expense
Interest Expense $0.9 $1.0 $1.1
Compensation Expense 2.2 2.8 1.7
---- ---- ----
Total Expense $3.1 $3.8 $2.8
---- ---- ----
Shares
Allocated Shares 3.8 3.6 3.6
Unreleased Shares 4.4 4.8 5.0
---- ---- ----
Total ESOP Shares 8.2 8.4 8.6
---- ---- ----
Fair Value of Unreleased Shares $75.8 $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, 1999, 1.1 million shares had
been issued under the plan and 222,265 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). The Executive Plan allows for the grant of up to 6.7 million
shares of Common Stock to key employees. 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 0.3 million shares of Common Stock
to nonemployee directors. Each nonemployee director receives an annual grant of
1,500 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 the Accounting Principles Board 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 1999 ($3 million in 1998; $4 million in 1997). Pro forma net income and
earnings per share under SFAS 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 1999 1998 1997
- --------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
Average Average Average
Exercise Exercise Exercise
Options Price Options Price Options Price
------- -------- ------- -------- ------- --------
Outstanding, Beginning of Year 963,500 $17.31 667,400 $13.89 244,600 $14.31
Granted 889,200 $21.77 419,800 $21.63 475,800 $13.69
Exercised (131,100) $13.91 (112,600) $13.95 (4,200) $14.31
Canceled (117,700) $21.25 (11,100) $16.73 (48,800) $13.93
--------- -------- -------
Outstanding, End of Year 1,603,900 $19.77 963,500 $17.31 667,400 $13.89
--------- -------- -------
Exercisable, End of Year 586,500 $16.38 361,000 $13.99 109,200 $14.31
Fair Value of Options Granted
During the Year $3.38 $3.11 $1.52
- --------------------------------------------------------------------------------------------------------------------
</TABLE>
At December 31, 1999 options outstanding consist of 397,300 with an exercise
price of $13.69 to $14.31, and 1,206,600 with an exercise price of $21.63 to
$21.94. The options with an exercise price of $13.69 to $14.31 have an average
remaining contractual life of 6.7 years with all exercisable on December 31,
1999 at an average price of $13.88. The options with an exercise price of $21.63
to $21.94 have an average remaining contractual life of 8.7 years with 189,200
exercisable on December 31, 1999 at an average price of $21.63.
A total of 277,000 performance share grants were awarded during 1999 and 1998
for the performance period ended December 31, 1999. The grant date fair value of
these shares was $6.0 million. Half of the shares will be issued in 2000, with
the remaining half issued equally in 2001 and 2002.
A total of 265,000 performance share grants were awarded during 1997 and 1996
for the performance period ended December 31, 1997. The grant date fair value of
these shares was $3.8 million. At December 31, 1999 75% of the shares had
already been issued, with the balance to be issued in 2000.
In January 2000 the Company granted stock options to purchase approximately one
million shares of Common Stock (exercise price of $16.25 per share) and
approximately 329,000 performance share awards.
Minnesota Power, Inc. 55
<PAGE>
18. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS
The Company's corporate and electric services 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 $0.6 million was accrued in 1999 ($0.8 million in
1998) for future costs associated with termination of the plan. This curtailment
expense is not included in pension expense below. At December 31, 1999
approximately 8% 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 $4.7
million in 1999 ($4.0 million in 1998; $3.2 million in 1997). The Company
provides certain health care and life insurance benefits for retired employees
in corporate, electric and water services. The deferred regulatory charge for
postretirement health and life benefits was fully amortized in 1999.
Plan Status Pension Health and Life
At September 30 1999 1998 1999 1998
- --------------------------------------------------------------------------------
Millions
Change in Benefit Obligation
Obligation, Beginning of Year $244.6 $218.8 $ 58.6 $ 50.7
Service Cost 4.7 4.1 2.7 2.3
Interest Cost 16.0 16.3 3.8 3.8
Actuarial (Gain) Loss (26.6) 19.8 (0.2) 3.6
Participant Contributions - - 0.7 0.7
Benefits Paid (14.6) (14.4) (3.0) (2.5)
------ ------ ------ ------
Obligation, End of Year 224.1 244.6 62.6 58.6
------ ------ ------ ------
Change in Plan Assets
Fair Value, Beginning of Year 267.5 270.8 27.6 20.4
Actual Return on Assets 31.6 9.8 3.1 1.4
Employer Contribution - - 3.2 7.6
Participant Contributions - - 0.7 0.7
Benefits Paid (14.6) (14.4) (3.0) (2.5)
Other 2.2 1.3 - -
------ ------ ------ ------
Fair Value, End of Year 286.7 267.5 31.6 27.6
------ ------ ------ ------
Funded Status 62.6 22.9 (31.0) (31.0)
Unrecognized Amounts
Net Gain (66.5) (31.4) (18.7) (18.8)
Prior Service Cost 4.2 4.7 (3.6) (3.8)
Transition Obligation 1.0 1.2 34.6 37.3
------ ------ ------ ------
Prepaid (Liability) Recognized $ 1.3 $ (2.6) $(18.7) $(16.3)
- --------------------------------------------------------------------------------
Benefit Expense Pension Health and Life
Year Ended December 31 1999 1998 1997 1999 1998 1997
- --------------------------------------------------------------------------------
Millions
Service Cost $ 4.7 $ 4.1 $ 3.6 $ 2.7 $ 2.3 $ 2.5
Interest Cost 16.0 16.3 15.8 3.8 3.8 4.1
Expected Return on Assets (24.9) (23.2) (19.5) (2.4) (1.7) (1.3)
Amortized Amounts
Unrecognized Gain (0.4) (1.1) (0.8) (0.9) (1.3) (0.6)
Prior Service Cost 0.5 0.5 0.6 (0.2) - -
Transition Obligation 0.2 0.2 0.2 2.6 2.3 2.6
------ ------ ------ ----- ----- -----
(3.9) (3.2) (0.1) 5.6 5.4 7.3
Early Retirement Expense - 2.8 4.7 - - -
Amortization of Deferred
Charge - - - 2.8 2.7 2.7
------ ------ ------ ----- ----- -----
Net Expense (Credit) $ (3.9) $ (0.4) $ 4.6 $ 8.4 $ 8.1 $10.0
- --------------------------------------------------------------------------------
56 Minnesota Power, Inc.
<PAGE>
Pension Health and Life
Actuarial Assumptions 1999 1998 1999 1998
- --------------------------------------------------------------------------------
Discount Rate 7.75% 6.75% 7.75% 6.75%
Expected Return on Plan Assets 10.0% 10.0% 6.0-10.0% 9.0%
Rate of Compensation Increase 3.5-4.5% 3.5-4.5% 3.5-4.5% 3.5-4.5%
Health Care Cost Trend Rate - - 7.8% 8.6%
- --------------------------------------------------------------------------------
The assumed health care cost trend rate declines gradually to an ultimate rate
of 6.0% by 2002. For postretirement health and life benefits, a 1% increase in
the assumed health care cost trend rate would result in a $7.3 million and $1.0
million increase in the benefit obligation and total service and interest costs,
respectively; a 1% decrease would result in a $6.0 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. Financial results for 1999 included
two non-cash charges associated with the merger of Capital Re with ACE. The
second quarter of 1999 included a $24.1 million charge, or $0.35 per share,
following the merger agreement and discontinuance of the Company's equity
accounting for Capital Re, and the fourth quarter included a $12.1 million
charge, or $0.17 per share, upon completion of the merger. (See Note 9.)
Quarter Ended Mar. 31 Jun. 30 Sept. 30 Dec. 31
-------------------------------------------------------------------------------
Millions Except Earnings Per Share
1999
Operating Revenue $257.7 $279.2 $308.0 $286.9
Operating Income $29.5 $28.2 $57.9 $16.1
Net Income $20.9 $1.9 $34.5 $10.7
Earnings Available for Common Stock $20.4 $1.4 $34.0 $10.2
Basic and Diluted Earnings Per
Share of Common Stock $0.30 $0.02 $0.50 $0.15
-------------------------------------------------------------------------------
1998
Operating Revenue $246.6 $269.0 $266.3 $257.3
Operating Income $28.9 $43.1 $44.9 $31.5
Net Income $18.5 $22.8 $25.8 $21.3
Earnings Available for Common Stock $18.0 $22.3 $25.3 $20.8
Basic and Diluted Earnings Per
Share of Common Stock $0.29 $0.36 $0.39 $0.31
-------------------------------------------------------------------------------
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 17, 2000 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 17, 2000
<TABLE>
SCHEDULE II
MINNESOTA POWER
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
1999 Trade Accounts Receivable $6.0 $3.9 - $2.3 $7.6
Finance Receivables 3.6 3.8 - 1.1 6.3
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
Deferred Asset Valuation Allowance
1999 Deferred Tax Assets 2.6 0.7 - - 3.3
1998 Deferred Tax Assets 0.3 2.3 - - 2.6
1997 Deferred Tax Assets 0.7 (0.4) - - 0.3
- ----------------------------------------------------------------------------------------------------------------------------
<FN>
<F1> Reserve for uncollectible accounts includes bad debts written off.
</FN>
</TABLE>
58 Minnesota Power, Inc.
<PAGE>
<TABLE>
Exhibit 12
Minnesota Power
Computation of Ratios of Earnings to Fixed Charges and
Supplemental Ratios of Earnings to Fixed Charges
<CAPTION>
For the Year Ended December 31 1995 1996 1997 1998 1999
- --------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
Millions except ratios
Income from Continuing Operations Per
Consolidated Statement of Income $ 61.9 $ 69.2 $ 77.6 $ 88.5 $ 68.0
Add (Deduct)
Current Income Tax Expense 13.4 31.4 44.7 52.9 70.5
Deferred Income Tax Expense (Benefit) (11.3) (9.8) 3.2 2.7 (11.3)
Deferred Investment Tax Credits (0.9) (2.0) (1.3) (1.6) (1.5)
Undistributed Income From Less Than 50%
Owned Equity Investments (9.1) (11.0) (13.9) (14.1) (0.6)
Minority Interest 0.2 3.3 2.3 2.0 1.8
------ ------ ------ ------ ------
54.2 81.1 112.6 130.4 126.9
------ ------ ------ ------ ------
Fixed Charges
Interest on Long-Term Debt 45.7 52.4 50.4 48.5 48.4
Capitalized Interest 1.4 1.5 1.5 1.0 0.7
Other Interest Charges - Net 7.9 10.2 14.3 17.1 12.0
Interest Component of All Rentals 3.7 2.5 3.7 5.7 4.8
Distributions on Redeemable Preferred Securities of Subsidiary - 4.7 6.0 6.0 6.0
------ ------ ------ ------ ------
Total Fixed Charges 58.7 71.3 75.9 78.3 71.9
------ ------ ------ ------ ------
Earnings Before Income Taxes and Fixed Charges
(Excluding Capitalized Interest) $111.5 $150.9 $187.0 $207.7 $198.1
------ ------ ------ ------ ------
Ratio of Earnings to Fixed Charges 1.90 2.12 2.46 2.65 2.76
- --------------------------------------------------------------------------------------------------------------------------------
Earnings Before Income Taxes and Fixed Charges
(Excluding Capitalized Interest) $111.5 $150.9 $187.0 $207.7 $198.1
Supplemental Charges 13.5 14.4 12.0 14.5 15.4
------ ------ ------ ------ ------
Earnings Before Income Taxes and Fixed
and Supplemental Charges (Excluding Capitalized Interest) $125.0 $165.3 $199.0 $222.2 $213.5
------ ------ ------ ------ ------
Total Fixed Charges $58.7 $71.3 $75.9 $78.3 $71.9
Supplemental Charges 13.5 14.4 12.0 14.5 15.4
----- ----- ----- ----- -----
Fixed and Supplemental Charges $72.2 $85.7 $87.9 $92.8 $87.3
----- ----- ----- ----- -----
Supplemental Ratio of Earnings to Fixed Charges (1) 1.73 1.93 2.26 2.39 2.45
- --------------------------------------------------------------------------------------------------------------------------------
<FN>
<F1> The supplemental ratio of earnings to fixed charges includes Minnesota
Power's obligation under a contract with Square Butte which extends through
2027, pursuant to which Minnesota Power is entitled to approximately 71% of
the output of a 455-megawatt coal-fired generating unit (Unit). Minnesota
Power is obligated to pay its pro rata share of Square Butte's costs based
on Unit output entitlement. Minnesota Power'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 under a long-term contract. (See Note 5.)
</FN>
</TABLE>
Minnesota Power, Inc. 59
<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,
333-82901) of Minnesota Power, Inc. of our report dated January 17, 2000
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 17, 2000 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 4, 2000
<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, 1999 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, 333-16445 and 333-82901 on Form S-8.
Philip R. Halverson
Philip R. Halverson
Duluth, Minnesota
February 4, 2000
<TABLE> <S> <C>
<ARTICLE> 5
<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, 1999, 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-31-1999
<PERIOD-START> JAN-01-1999
<PERIOD-END> DEC-31-1999
<CASH> 102
<SECURITIES> 180
<RECEIVABLES> 176
<ALLOWANCES> 18
<INVENTORY> 24
<CURRENT-ASSETS> 565
<PP&E> 1,259
<DEPRECIATION> 880
<TOTAL-ASSETS> 2,313
<CURRENT-LIABILITIES> 398
<BONDS> 713
95
12
<COMMON> 552
<OTHER-SE> 254
<TOTAL-LIABILITY-AND-EQUITY> 2,313
<SALES> 0
<TOTAL-REVENUES> 1,132
<CGS> 0
<TOTAL-COSTS> 906
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 60
<INCOME-PRETAX> 132
<INCOME-TAX> 58
<INCOME-CONTINUING> 68<F1>
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 68<F1>
<EPS-BASIC> 0.97<F1>
<EPS-DILUTED> 0.97<F1>
<FN>
<F1>Included a $36.2 million, or $0.52 per share, non-cash charge related to the
merger of Capital Re Corporation with ACE Limited. See Note 9 to Minnesota
Power's Consolidated Financial Statements filed as part of the Company's 1999
Form 10-K.
</FN>
</TABLE>
<TABLE> <S> <C>
<ARTICLE> 5
<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>
<RESTATED>
<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
<CASH> 89
<SECURITIES> 170
<RECEIVABLES> 156
<ALLOWANCES> 10
<INVENTORY> 24
<CURRENT-ASSETS> 488
<PP&E> 1,179
<DEPRECIATION> 776
<TOTAL-ASSETS> 2,209
<CURRENT-LIABILITIES> 346
<BONDS> 672
95
12
<COMMON> 529
<OTHER-SE> 257
<TOTAL-LIABILITY-AND-EQUITY> 2,209
<SALES> 0
<TOTAL-REVENUES> 1,039
<CGS> 0
<TOTAL-COSTS> 841
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 65
<INCOME-PRETAX> 149
<INCOME-TAX> 54
<INCOME-CONTINUING> 89
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 89
<EPS-BASIC> 1.35
<EPS-DILUTED> 1.35
</TABLE>
