SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC 20549
FORM 10-Q
(Mark One)
/X/ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934
For the quarterly period ended MARCH 31, 1999
or
/ / Transition Report Pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934
Commission File No. 1-3548
MINNESOTA POWER, INC.
A Minnesota Corporation
IRS Employer Identification No. 41-0418150
30 West Superior Street
Duluth, Minnesota 55802
Telephone - (218) 722-2641
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 and (2) has been subject to such filing requirements for
the past 90 days.
Yes X No
---- ----
Common Stock, no par value,
72,821,087 shares outstanding
as of April 30, 1999
MINNESOTA POWER, INC.
INDEX
Page
Part I. Financial Information
Item 1. Financial Statements
Consolidated Balance Sheet -
March 31, 1999 and December 31, 1998 1
Consolidated Statement of Income -
Quarter Ended March 31, 1999 and 1998 2
Consolidated Statement of Cash Flows -
Quarter Ended March 31, 1999 and 1998 3
Notes to Consolidated Financial Statements 4
Item 2. Management's Discussion and Analysis of
Financial Condition and Results of Operations 8
Item 3. Quantitative and Qualitative Disclosures
about Market Risk 13
Part II. Other Information
Item 5. Other Information 13
Item 6. Exhibits and Reports on Form 8-K 15
Signatures 16
i
DEFINITIONS
The following abbreviations or acronyms are used in the text.
Abbreviation or Acronym Term
- ----------------------- ----
1998 Form 10-K Minnesota Power's Annual Report on Form 10-K
for the Year Ended December 31, 1998
ADESA ADESA Corporation
AFC Automotive Finance Corporation
Capital Re Capital Re Corporation
CFS Commercial Financial Services Inc.
Common Stock Minnesota Power, Inc. Common Stock
Company Minnesota Power, Inc. and its subsidiaries
DRIP Dividend Reinvestment and Stock Purchase Plan
ESOP Employee Stock Ownership Plan
FERC Federal Energy Regulatory Commission
Heater Heater Utilities, Inc.
Florida Water Florida Water Services Corporation
FPSC Florida Public Service Commission
kWh Kilowatthour(s)
MAPP Mid-Continent Area Power Pool
Minnesota Power Minnesota Power, Inc. and its subsidiaries
MPUC Minnesota Public Utilities Commission
MW Megawatt(s)
NCUC North Carolina Utilities Commission
Palm Coast Palm Coast Holdings, Inc.
PCUC Palm Coast Utilities Corporation
PSCW Public Service Commission of Wisconsin
Square Butte Square Butte Electric Cooperative
SWL&P Superior Water, Light and Power Company
ii
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 quarterly report on Form 10-Q, in
presentations, in response to questions or otherwise. Any statements that
express, or involve discussions as to expectations, beliefs, plans, objectives,
assumptions or future events or performance (often, but not always, through the
use of words or phrases such as "anticipates", "believes", "estimates",
"expects", "intends", "plans", "predicts", "projects", "will likely result",
"will continue", or similar expressions) are not statements of historical facts
and may be forward-looking.
Forward-looking statements involve estimates, assumptions, and uncertainties
and are qualified in their entirety by reference to, and are accompanied by, the
following important factors, which are difficult to predict, contain
uncertainties, are beyond the control of the Company and may cause actual
results to differ materially from those contained in forward-looking
statements:
- prevailing governmental policies and regulatory actions, including those
of the FERC, the MPUC, the FPSC, the NCUC and the PSCW, with respect to
allowed rates of return, industry and rate structure, acquisition and
disposal of assets and facilities, operation and construction of plant
facilities, recovery of purchased power and other capital investments,
and present or prospective wholesale and retail competition (including
but not limited to retail wheeling and transmission costs);
- economic and geographic factors including political and economic risks;
- changes in and compliance with environmental and safety laws and
policies;
- weather conditions;
- population growth rates and demographic patterns;
- competition for retail and wholesale customers;
- Year 2000 issues;
- delays or changes in costs of Year 2000 compliance;
- failure of major suppliers, customers or others with whom the company
does business to resolve their own Year 2000 issues on a timely basis;
- pricing and transportation of commodities;
- market demand, including structural market changes;
- changes in tax rates or policies or in rates of inflation;
- changes in project costs;
- unanticipated changes in operating expenses and capital expenditures;
- capital market conditions;
- competition for new energy development opportunities; and
- legal and administrative proceedings (whether civil or criminal) and
settlements that influence the business and profitability of the
Company.
Any forward-looking statement speaks only as of the date on which such statement
is made, and the Company undertakes no obligation to update any forward-looking
statement to reflect events or circumstances after the date on which such
statement is made or to reflect the occurrence of unanticipated events. New
factors emerge from time to time and it is not possible for management to
predict all of such factors, nor can it assess the impact of any such factor on
the business or the extent to which any factor, or combination of factors, may
cause results to differ materially from those contained in any forward-looking
statement.
iii
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
MINNESOTA POWER
CONSOLIDATED BALANCE SHEET
Millions
MARCH 31, DECEMBER 31,
1999 1998
Unaudited Audited
- ------------------------------------------------------------------------------------------------------
ASSETS
PLANT AND INVESTMENTS
Electric Operations $ 766.0 $ 771.5
Water Services 414.1 329.4
Automotive Services 195.4 186.2
Investments 266.5 263.5
--------- --------
Total Plant and Investments 1,642.0 1,550.6
--------- --------
CURRENT ASSETS
Cash and Cash Equivalents 147.9 89.4
Trading Securities 167.2 169.9
Accounts Receivable (less Allowance of $10.3 and $9.6) 275.4 156.1
Fuel, Material and Supplies 23.4 24.0
Prepayments and Other 56.0 48.1
--------- --------
Total Current Assets 669.9 487.5
--------- --------
OTHER ASSETS
Goodwill 169.1 169.8
Deferred Regulatory Charges 52.4 56.1
Other 55.2 53.1
--------- --------
Total Other Assets 276.7 279.0
--------- --------
TOTAL ASSETS $ 2,588.6 $2,317.1
- ------------------------------------------------------------------------------------------------------
CAPITALIZATION AND LIABILITIES
CAPITALIZATION
Common Stock without Par Value, 130.0 Shares Authorized;
72.7 and 72.3 Shares Outstanding $ 538.2 $ 529.0
Unearned ESOP Shares (61.7) (62.5)
Accumulated Other Comprehensive Income 2.5 1.5
Retained Earnings 320.5 317.6
--------- --------
Total Common Stock Equity 799.5 785.6
Cumulative Preferred Stock 11.5 11.5
Redeemable Serial Preferred Stock 20.0 20.0
Company Obligated Mandatorily Redeemable Preferred Securities of
Subsidiary MP&L Capital I Which Holds Solely Company
Junior Subordinated Debentures 75.0 75.0
Long-Term Debt 672.1 672.2
--------- --------
Total Capitalization 1,578.1 1,564.3
--------- --------
CURRENT LIABILITIES
Accounts Payable 244.5 123.3
Accrued Taxes, Interest and Dividends 77.4 62.9
Notes Payable 160.4 81.0
Long-Term Debt Due Within One Year 8.9 9.0
Other 46.7 69.8
--------- --------
Total Current Liabilities 537.9 346.0
--------- --------
OTHER LIABILITIES
Accumulated Deferred Income Taxes 149.0 153.4
Contributions in Aid of Construction 170.8 108.2
Deferred Regulatory Credits 56.1 55.2
Other 96.7 90.0
--------- --------
Total Other Liabilities 472.6 406.8
--------- --------
TOTAL CAPITALIZATION AND LIABILITIES $ 2,588.6 $2,317.1
- ------------------------------------------------------------------------------------------------------
The accompanying notes are an integral part of these statements.
-1-
MINNESOTA POWER
CONSOLIDATED STATEMENT OF INCOME
Millions Except Per Share Amounts - Unaudited
QUARTER ENDED
MARCH 31,
1999 1998
- --------------------------------------------------------------------------------
OPERATING REVENUE
Electric Operations $ 132.2 $ 134.0
Water Services 24.4 20.8
Automotive Services 96.8 76.7
Investments 4.1 15.1
------- -------
Total Operating Revenue 257.5 246.6
------- -------
OPERATING EXPENSES
Fuel and Purchased Power 47.6 49.7
Operations 164.0 152.4
Interest Expense 14.2 19.8
------- -------
Total Operating Expenses 225.8 221.9
------- -------
INCOME (LOSS) FROM EQUITY INVESTMENTS (2.2) 4.2
------- -------
OPERATING INCOME 29.5 28.9
DISTRIBUTIONS ON REDEEMABLE
PREFERRED SECURITIES OF SUBSIDIARY 1.5 1.5
INCOME TAX EXPENSE 7.1 8.9
------- -------
NET INCOME 20.9 18.5
DIVIDENDS ON PREFERRED STOCK 0.5 0.5
------- -------
EARNINGS AVAILABLE FOR COMMON STOCK $ 20.4 $ 18.0
======= =======
AVERAGE SHARES OF COMMON STOCK 67.8 62.3
BASIC AND DILUTED
EARNINGS PER SHARE OF COMMON STOCK $0.30 $0.29
DIVIDENDS PER SHARE OF COMMON STOCK $0.2675 $0.255
- --------------------------------------------------------------------------------
The accompanying notes are an integral part of this statement.
-2-
MINNESOTA POWER
CONSOLIDATED STATEMENT OF CASH FLOWS
Millions - Unaudited
QUARTER ENDED
MARCH 31,
1999 1998
- -------------------------------------------------------------------------------------------------------------------
OPERATING ACTIVITIES
Net Income $ 20.9 $ 18.5
Loss (Income) From Equity Investments - Net of Dividends Received 2.2 (4.2)
Depreciation and Amortization 18.4 18.5
Deferred Income Taxes (4.5) (1.9)
Deferred Investment Tax Credits (0.4) (0.3)
Changes In Operating Assets and Liabilities
Trading Securities 2.7 (8.4)
Notes and Accounts Receivable (119.3) (80.4)
Fuel, Material and Supplies 0.6 2.1
Accounts Payable 121.2 59.0
Other Current Assets and Liabilities (16.5) (2.4)
Other - Net 4.3 10.2
------- -------
Cash From Operating Activities 29.6 10.7
------- -------
INVESTING ACTIVITIES
Proceeds From Sale of Investments in Securities 9.9 13.5
Additions to Investments (15.8) (10.0)
Additions to Plant (32.1) (16.5)
Changes to Other Assets - Net (3.8) (1.6)
------- -------
Cash For Investing Activities (41.8) (14.6)
------- -------
FINANCING ACTIVITIES
Issuance of Common Stock 8.7 8.7
Issuance of Long-Term Debt 3.6 2.0
Changes in Notes Payable - Net 79.4 67.7
Reductions of Long-Term Debt (3.8) (2.4)
Dividends on Preferred and Common Stock (18.0) (16.7)
------- -------
Cash From Financing Activities 69.9 59.3
------- -------
EFFECT OF EXCHANGE RATE CHANGES ON CASH 0.8 0.2
------- -------
CHANGE IN CASH AND CASH EQUIVALENTS 58.5 55.6
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD 89.4 41.8
------- -------
CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 147.9 $ 97.4
======= =======
SUPPLEMENTAL CASH FLOW INFORMATION
Cash Paid During the Period For
Interest - Net of Capitalized $17.7 $22.0
Income Taxes $3.4 $5.5
- -------------------------------------------------------------------------------------------------------------------
The accompanying notes are an integral part of this statement.
-3-
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The accompanying unaudited consolidated financial statements and notes should be
read in conjunction with the Company's 1998 Form 10-K. In the opinion of the
Company, all adjustments necessary for a fair statement of the results for the
interim periods have been included. The results of operations for an interim
period may not give a true indication of results for the year.
NOTE 1. STOCK SPLIT
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.
NOTE 2. BUSINESS SEGMENTS
Millions
Investments
---------------------
Electric Water Automotive Portfolio & Real Corporate
Consolidated Operations Services Services Reinsurance Estate Charges
- -----------------------------------------------------------------------------------------------------------------------
For the Quarter Ended March 31, 1999
- ------------------------------------
Operating Revenue $ 257.5 $ 132.2 $ 24.4 $ 96.8 $ 0.6 $ 3.6 $ (0.1)
Operation and Other Expense 193.2 97.8 15.7 72.9 1.1 3.0 2.7
Depreciation and Amortization 18.4 10.9 3.2 4.2 - - 0.1
Interest Expense 14.2 5.3 2.4 2.4 - - 4.1
Loss from Equity Investments (2.2) - - - (2.2) - -
--------- -------- -------- ------- -------- ------ -------
Operating Income (Loss) 29.5 18.2 3.1 17.3 (2.7) 0.6 (7.0)
Distributions on Redeemable
Preferred Securities
of Subsidiary 1.5 0.4 - - - - 1.1
Income Tax Expense (Benefit) 7.1 6.8 1.2 7.7 (5.2) 0.2 (3.6)
--------- -------- -------- ------- -------- ------ -------
Net Income (Loss) $ 20.9 $ 11.0 $ 1.9 $ 9.6 $ 2.5 $ 0.4 $ (4.5)
========= ======== ======== ======= ======== ====== =======
Total Assets $ 2,588.6 $1,034.5 $ 463.1 $ 722.6 $ 290.8 $ 77.2 $ 0.4
Accumulated Depreciation
and Amortization $ 843.1 $ 607.1 $ 189.6 $ 44.7 - $ 1.7 -
Construction Work in Progress $ 32.8 $ 14.4 $ 16.4 $ 2.0 - - -
Capital Expenditures $ 15.3 $ 6.6 $ 4.2 $ 4.5 - - -
- -----------------------------------------------------------------------------------------------------------------------
For the Quarter Ended March 31, 1998
- ------------------------------------
Operating Revenue $ 246.6 $ 134.0 $ 20.8 $ 76.7 $ 7.1 $ 8.1 $ (0.1)
Operation and Other Expense 183.6 100.8 14.0 60.1 0.9 4.9 2.9
Depreciation and Amortization 18.5 11.8 2.9 3.6 - 0.1 0.1
Interest Expense 19.8 5.5 2.6 2.2 - - 9.5
Income from Equity Investments 4.2 - - - 4.2 - -
--------- -------- -------- ------- -------- ------ -------
Operating Income (Loss) 28.9 15.9 1.3 10.8 10.4 3.1 (12.6)
Distributions on Redeemable
Preferred Securities
of Subsidiary 1.5 0.4 - - - - 1.1
Income Tax Expense (Benefit) 8.9 6.0 0.6 5.4 3.9 1.3 (8.3)
--------- -------- -------- ------- -------- ------ -------
Net Income (Loss) $ 18.5 $ 9.5 $ 0.7 $ 5.4 $ 6.5 $ 1.8 $ (5.4)
========= ======== ======== ======= ======== ====== =======
Total Assets $ 2,312.2 $1,012.0 $ 380.2 $ 557.1 $ 296.0 $ 66.3 $ 0.6
Accumulated Depreciation
and Amortization $ 732.2 $ 573.6 $ 126.9 $ 30.3 - $ 1.4 -
Construction Work in Progress $ 43.9 $ 17.2 $ 10.7 $ 16.0 - - -
Capital Expenditures $ 16.5 $ 9.2 $ 3.0 $ 4.3 - - -
- -----------------------------------------------------------------------------------------------------------------------
Included $11.4 million of Canadian operating revenue in 1999 ($7.6 million in 1998).
Included $89.1 million of Canadian assets in 1999 ($54.5 million in 1998).
Included a $1.7 million charge for the net impact of a loss reserve
established by Capital Re for reinsurance of securities issued by CFS.
Included $0.1 million of minority interest in 1999 ($0.5 million in 1998).
-4-
NOTE 3. REGULATORY MATTERS
Florida Water 1995 Rate Case. Florida Water requested an $18.1 million annual
rate increase in June 1995 for all water and wastewater customers of Florida
Water regulated by the FPSC. In October 1996 the FPSC issued its final order
approving an $11.1 million annual increase. The new rates were implemented in
September 1996. In November 1996 Florida Water filed with the Florida First
District Court of Appeals (Court of Appeals) an appeal of the FPSC's final order
seeking judicial review of issues relating to the amount of investment in
utility facilities recoverable in rates from current customers. Other parties to
the rate case also filed appeals. In the course of the appeals process, the FPSC
reconsidered an issue in its initial decision and, in June 1997, allowed Florida
Water to resume collecting approximately $1 million, on an annual basis, in new
customer fees. On June 10, 1998 the Court of Appeals ruled in Florida Water's
favor on all material issues appealed by Florida Water and remanded the matter
back to the FPSC for action consistent with the Court's order. The Court of
Appeals also overturned its decision in Florida Water's 1991 Rate Case which had
required a "functional relationship" between service areas as a precondition to
implementation of uniform rates. On December 15, 1998 the FPSC granted Florida
Water an additional annual revenue increase of approximately $1.2 million
related to several of the issues reversed by the Court of Appeals, and permitted
collection of approximately $2.4 million in surcharges to reimburse Florida
Water for revenue (plus interest) wrongfully denied in the FPSC's October 1996
order. Florida Water began collecting the new rates in January 1999 and expects
to begin collecting the surcharges in mid 1999. Intervenors protested the
surcharge allocation methodology. As a result collection is delayed and interest
accumulates until the FPSC approves a methodology. The FPSC reopened the record
on two remaining issues on remand from the Court of Appeals regarding the amount
of investment in utility facilities recoverable in rates from current customers,
but no hearing dates will be set until procedural matters have been resolved. A
decision in the Company's favor would result in additional revenue and
surcharges. The Company is unable to predict the timing or outcome of these
proceedings.
1991 Rate Case Refunds. In 1995 the Court of Appeals reversed a 1993 FPSC order
establishing uniform rates for most of Florida Water's service areas. With
"uniform rates" all customers in each uniform rate area pay the same rates for
water and wastewater services. In response to the Court of Appeals' order, in
August 1996 the FPSC ordered Florida Water to issue refunds to those customers
who paid more since October 1993 under uniform rates than they would have paid
under stand-alone rates. This order did not permit a balancing surcharge to
customers who paid less under uniform rates. Florida Water appealed, and the
Court of Appeals ruled in June 1997 that the FPSC could not order refunds
without balancing surcharges. In response to the Court of Appeals' ruling, the
FPSC issued an order on January 26, 1998 that did not require refunds. Florida
Water's potential refund liability at that time was about $12.5 million, which
included interest, to customers who paid more under uniform rates.
In the same January 26, 1998 order, the FPSC required Florida Water to refund
$2.5 million, the amount paid by customers in the Spring Hill service area from
January 1996 through June 1997 under uniform rates which exceeded the amount
these customers would have paid under a modified stand-alone rate structure. No
balancing surcharge was permitted. The FPSC ordered this refund because Spring
Hill customers continued to pay uniform rates after other customers began paying
modified stand-alone rates effective January 1996 pursuant to the FPSC's interim
rate order in Florida Water's 1995 Rate Case (see Florida Water 1995 Rate Case).
The FPSC did not include Spring Hill in this interim rate order because Hernando
County had assumed jurisdiction over Spring Hill's rates. In June 1997 Florida
Water reached an agreement with Hernando County to revert prospectively to
stand-alone rates for Spring Hill customers.
Customer groups which paid more under uniform rates have appealed the FPSC's
January 26, 1998 order, arguing that they are entitled to a refund because the
FPSC had no authority to order uniform rates. The Company has appealed the $2.5
million refund order. Initial briefs were filed by all parties on May 22, 1998.
Upon issuance of the June 10, 1998 opinion of the Court of Appeals with respect
to Florida Water's 1995 Rate Case (see 1995 Rate Case) in which the court
reversed its previous ruling that the FPSC was without authority to order
uniform rates, customer groups supporting the FPSC's January 1998 order filed a
motion with the Court of Appeals seeking dismissal of the appeal by customer
groups seeking refunds. Customers seeking refunds filed amended briefs on
September 14, 1998. No provision for refund has been recorded. The Company is
unable to predict the timing or outcome of the appeals process.
-5-
NOTE 4. TOTAL COMPREHENSIVE INCOME
For the quarter ended March 31, 1999 total comprehensive income was $21.9
million ($19.0 million for the quarter ended March 31, 1998). Total
comprehensive income includes net income, unrealized gains and losses on
securities classified as available-for-sale, and foreign currency translation
adjustments.
NOTE 5. INCOME TAX EXPENSE
Quarter Ended
March 31,
1999 1998
- --------------------------------------------------------------------------------
Millions
Current Tax
Federal $ 10.0 $ 7.8
Foreign 0.4 0.8
State 1.6 2.5
------ -----
12.0 11.1
------ -----
Deferred Tax
Federal (1.6) (1.4)
State (2.9) (0.5)
------ -----
(4.5) (1.9)
------ -----
Deferred Tax Credits (0.4) (0.3)
------ -----
Total Income Tax Expense $ 7.1 $ 8.9
- --------------------------------------------------------------------------------
NOTE 6. ACQUISITIONS
Palm Coast Utilities Corporation. On January 22, 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. 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. Pro forma financial results have not been presented
due to immateriality. PCUC provides service to approximately 15,000 water and
14,000 wastewater customers in Flagler County, Florida.
-6-
NOTE 7. SQUARE BUTTE PURCHASED POWER CONTRACT
The Company has had a power purchase agreement with Square Butte since 1977 to
provide a long-term supply of low-cost energy to customers in the Company's
service territory and to meet power pool reserve requirements. Square Butte, a
North Dakota cooperative corporation, owns a 455-megawatt coal-fired generating
unit (Unit) near Center, North Dakota. The Unit is adjacent to a generating unit
owned by Minnkota Power Cooperative, Inc. (Minnkota), a North Dakota cooperative
corporation whose Class A members are also members of Square Butte. Minnkota
serves as the operator of the Unit and also purchases power from Square Butte.
In May 1998 the Company and Square Butte entered into a new power purchase
agreement (1998 Agreement), replacing the 1977 agreement. The Company extended
by 20 years, to January 1, 2027, its access to Square Butte's low-cost
electricity and eliminated its unconditional obligation for all of Square
Butte's costs if not paid by Square Butte when due. The 1998 Agreement was
reached in conjunction with the termination of Square Butte's previous leveraged
lease financing arrangement and refinancing of associated debt.
Similar to the previous agreement, the Company is initially entitled to
approximately 71 percent 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 percent annually, to a
minimum of 50 percent.
Under the 1998 Agreement, the Company is obligated to pay its pro rata share of
Square Butte's costs based on the Company's entitlement to Unit output. The
Company's payment obligation is suspended if Square Butte fails to deliver any
power, whether produced or purchased, for a period of one year. Under the 1977
agreement the Company was unconditionally obligated to pay all of Square Butte's
costs, if not paid by Square Butte when due. Square Butte's fixed costs consist
primarily of debt service. At March 31, 1999 Square Butte had total debt
outstanding of $343.4 million. Total annual debt service for Square Butte is
expected to be approximately $36 million in each of the years 1999 through 2002
and $23 million in 2003. Variable operating costs include the price of coal
purchased from BNI Coal, a subsidiary of Minnesota Power, under a long-term
contract. The Company's payments to Square Butte are approved as purchased power
expense for ratemaking purposes by both the MPUC and FERC.
-7-
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
MINNESOTA POWER is a broadly diversified service company with operations in four
business segments: (1) Electric Operations, which include electric and gas
services, coal mining and telecommunications; (2) Water Services, which include
water and wastewater services; (3) Automotive Services, which include a network
of vehicle auctions, a finance company, an auto transport company and a vehicle
remarketing company; and (4) Investments, which include a securities portfolio,
a 23 percent equity investment in a financial guaranty reinsurance and specialty
insurance company, intermediate-term investments and real estate operations.
Corporate Charges represent general corporate expenses, including interest, not
specifically allocated to any one business segment.
CONSOLIDATED OVERVIEW
Strong performances by the Company's Electric Operations, Water Services and
Automotive Services contributed to a 13 percent increase in 1999 net income over
the first three months of 1998. Earnings per share increased 3 percent over the
first three months of 1998 and reflected the impact of the additional 4.2
million shares of Common Stock issued by the Company in an underwritten public
offering in September 1998.
Quarter Ended
March 31,
1999 1998
- --------------------------------------------------------------------------------
Millions
Operating Revenue
Electric Operations $ 132.2 $ 134.0
Water Services 24.4 20.8
Automotive Services 96.8 76.7
Investments 4.1 15.2
Corporate Charges .0 (0.1)
------- -------
$ 257.5 $ 246.6
======= =======
Operating Expenses
Electric Operations $ 114.0 $ 118.1
Water Services 21.3 19.5
Automotive Services 79.5 65.9
Investments 4.0 5.9
Corporate Charges 7.0 12.5
------- -------
$ 225.8 $ 221.9
======= =======
Net Income
Electric Operations $ 11.0 $ 9.5
Water Services 1.9 0.7
Automotive Services 9.6 5.4
Investments 2.9 8.3
Corporate Charges (4.5) (5.4)
------- -------
$ 20.9 $ 18.5
======= =======
- --------------------------------------------------------------------------------
Basic and Diluted
Earnings Per Share
of Common Stock $0.30 $0.29
Average Shares of
Common Stock - Millions 67.8 62.3
- --------------------------------------------------------------------------------
NET INCOME
Electric Operations reflected increased sales to residential and commercial
customers, and reduced operating expenses in 1999.
Water Services generated higher net income in 1999 due to increased consumption
as a result of the recent purchase of PCUC assets and dry weather conditions
compared to record rainfall during the same period in 1998. In addition, Water
Services included increased rates approved by the FPSC in December 1998.
-8-
Automotive Services recognized record sales volume in 1999 as the number of
vehicles offered for sale at ADESA auction facilities increased 16 percent. The
maturing of AFC's recently opened loan production offices also contributed to
higher net income from Automotive Services.
Investments reported lower net income in 1999 from Portfolio and Reinsurance
because of stock market volatility affecting returns from short-term investments
and a loss reserve established by Capital Re for reinsurance of securities
issued by CFS. Together, the Company's securities portfolio and its equity
investment in Capital Re earned an annualized after-tax return of 3.2 percent in
1999 (5.8 percent in 1998). In 1998 net income included dividend income received
from a venture capital investment and two large bulk land sales by Real Estate
Operations.
COMPARISON OF THE QUARTERS ENDED MARCH 31, 1999 AND 1998
OPERATING REVENUE
Electric Operations operating revenue was slightly lower in 1999. Revenue from
electric sales was about the same, even though kilowatthour sales were down 4
percent from 1998. Decreased taconite production, paper manufacturing and
pipeline usage reduced revenue from large industrial customers in 1999. Revenue
from residential and commercial customers was higher in 1999 because the winter
weather in Northern Minnesota and Wisconsin was colder than 1998. Sales to other
power suppliers were lower due to less hydro generation available in Canada and
the Midwest and a sufficient supply of generation available in the region.
Revenue from electric sales to taconite customers accounted for 16 percent of
consolidated operating revenue in 1999 (17 percent in 1998). Electric sales to
paper and pulp mills accounted for 6 percent of consolidated operating revenue
in both 1999 and 1998. Sales to other power suppliers and marketers also
accounted for 6 percent of consolidated operating revenue in both 1999 and 1998.
Water Services operating revenue was $3.6 million higher in 1999, with $1.9
million of the increase coming from PCUC which was purchased in January 1999.
The remainder of the increase resulted from higher rates approved by the FPSC in
December 1998 and more consumption due to dry weather conditions in 1999
compared to record rainfall in 1998. Overall consumption increased 29 percent in
1999.
Automotive Services operating revenue was $20.1 million higher in 1999 due to
increased sales at ADESA auction facilities and the maturing of AFC loan
production offices opened in 1998. ADESA offered for sale on consignment 396,000
vehicles (340,000 in 1998) at its 28 auction facilities in 1999 (25 in 1998).
AFC financed approximately 149,000 vehicles (120,000 in 1998) through its 84
loan production offices in 1999 (57 in 1998).
Investments. Portfolio operating revenue was $6.5 million lower in 1999 due to
stock market volatility affecting returns from short-term investments. Also,
revenue in 1998 included $3.9 million of dividend income received from a venture
capital investment. Real Estate Operations operating revenue was $4.5 million
lower in 1999 because 1998 included $5.1 million of revenue from two large bulk
land sales at Palm Coast.
OPERATING EXPENSES
Electric Operations operating expenses were $4.1 million lower in 1999 primarily
due to a reduction in purchased power expense. Operating expenses were also
lower in 1999 because the amortization of an early retirement program was
completed in July 1998.
Water Services operating expenses were $1.8 million higher in 1999 due to
inclusion of PCUC operations.
Automotive Services operating expenses were up $13.6 million 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.
Investments. Real Estate Operations operating expenses were $2.0 million lower
in 1999 due to fewer sales.
-9-
Corporate Charges operating expenses were $5.6 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, in
the first quarter of 1998 amounts previously accrued as income tax expense were
reversed and recorded as interest expense. There was no impact on consolidated
net income from this transaction.
INCOME (LOSS) FROM EQUITY INVESTMENTS
Income (loss) from equity investments reflected a loss of $2.4 million in 1999
(income of $4.2 million in 1998) from the Company's equity investment in Capital
Re. The decrease was attributed to a loss reserve established by Capital Re for
reinsurance of securities issued by CFS. CFS is under investigation by the
Securities and Exchange Commission and the Oklahoma Securities Commission for
allegations of irregularities relating to these securities. CFS filed for
Chapter 11 bankruptcy protection in December 1998.
LIQUIDITY AND FINANCIAL POSITION
CASH FLOW ACTIVITIES. Cash flow from operations during the first quarter of 1999
reflected improved operating results and continued focus on working capital
management. Cash from operating activities was also affected by a number of
factors representative of normal operations.
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 9 million original issue shares of Common Stock
are available for issuance through the DRIP.
A substantial amount of ADESA's working capital is generated internally from
payments made by vehicle purchasers. However, ADESA uses commercial paper issued
by the Company to meet short-term working capital requirements arising from the
timing of payment obligations to vehicle sellers and the availability of funds
from vehicle purchasers. During the sales process, ADESA does not typically take
title to vehicles.
AFC also uses commercial paper issued by the Company to meet its operational
requirements. AFC offers short-term on-site financing for dealers to purchase
vehicles at auctions in exchange for a security interest in those vehicles. The
financing is provided through the earlier of the date the dealer sells the
vehicle or a general borrowing term of 30 to 45 days. 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 of $225.0
million, to third party purchasers under an agreement which expires at the end
of 2001. At March 31, 1999 AFC had sold $260.9 million of finance receivables to
this subsidiary ($202.9 million at December 31, 1998). Third party purchasers
had purchased an undivided interest in finance receivables of $193.0 million
from this subsidiary at March 31, 1999 ($170.0 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.
Significant changes in accounts receivable and accounts payable balances at
March 31, 1999 compared to December 31, 1998 were due to increased sales
activity by Automotive Services. Typically auction volumes are down during the
winter months and in December because of the holidays. As a result, both ADESA
and AFC had lower receivables and fewer payables at year end.
Notes payable increased temporarily to finance Automotive Services' cash
requirements due to significant auction sales and financing growth. The Company
also used the temporary increase in 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 $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.
-10-
CAPITAL REQUIREMENTS. Consolidated capital expenditures for the three months
ended March 31, 1999 totaled $15.3 million ($16.5 million in 1998). Expenditures
for 1999 included $6.6 million for Electric Operations, $4.2 million for Water
Services and $4.5 million for Automotive Services. Internally generated funds
and proceeds from the September 1998 issuance of Common Stock were the primary
sources of funding for these expenditures.
NEW ACCOUNTING STANDARDS. In June 1998 the FASB issued SFAS No. 133, "Accounting
for Derivative Instruments and Hedging Activities," effective for fiscal years
beginning after June 15, 1999. SFAS 133 establishes accounting and reporting
standards requiring that every derivative instrument be recorded on the balance
sheet as either an asset or liability measured at fair value. SFAS 133 requires
that changes in the derivative's fair value be recognized currently in earnings
unless specific hedge accounting criteria are met. Special accounting for
qualifying hedges allows a derivative's gains and losses to offset the related
results on the hedged item. The Company currently 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. However,
Capital Re has determined that it is likely that its credit default swap
business will be subject to the requirements of SFAS 133 and is in the process
of determining what the effect will be on its earnings and financial position.
The Company accounts for its investment in Capital Re under the equity method
and is unable to predict the impact of Capital Re's adoption of SFAS 133.
YEAR 2000. The Year 2000 issue relates to computer systems that recognize the
year in a date field using only the last two digits. Unless corrected, the Year
2000 may be interpreted as 1900, causing errors or shutdowns in computer systems
which may, in turn, disrupt operations.
State of Readiness. The Company has been addressing the Year 2000 issue for five
years. In the ordinary course of business, it has replaced, or is in the process
of replacing, many of its major computer systems with new systems that have been
designed to be Year 2000 compliant. These updated systems handle critical
aspects of the Company's operations, including energy management and generation
control for Electric Operations, and customer information and financial
management Company-wide.
Each of the business segments has its own Year 2000 plan, which has been
reviewed and is being monitored by a corporate-level Year 2000 Risk Assessment
Team. The Company's plan for Year 2000 readiness involves four phases:
inventory, evaluation, remediation and contingency planning. Testing is an
ongoing and integral part of the evaluation, remediation and contingency
planning phases.
Inventory. Each business segment has performed an extensive inventory of
its information technology systems and other systems that use embedded
microprocessors (collectively, "Systems"). The business processes supported
by each System have been prioritized based on the degree of impact business
operations would encounter if the System were disrupted.
The inventory phase also includes identifying third parties with whom the
Company has material relationships. The degree to which each business
segment depends on third party support varies. Water Services, Automotive
Services and Real Estate Operations have identified minimal risk in most
areas. Where a third party is critical to a business process, efforts have
been initiated to obtain Year 2000 compliance information to identify the
degree of risk exposure the Company may encounter. Electric Operations is
working with its large power customers to share Year 2000 information and
determine their readiness. In addition, Electric Operations is working with
its fuel and transportation providers in an effort to ensure adequate
supplies of fuel.
The electric industry is unique in its reliance on the integrity of the
power pool grid to support and maintain reliable, efficient operations.
Preparation for the Year 2000 by Electric Operations is linked to the Year
2000 compliance efforts of other utilities as well as to those of its major
customers whose loads support the integrity of the power pool grid.
Electric Operations is coordinating its Year 2000 efforts with the plans
established by the North American Electric Reliability Council under the
direction of the U.S. Department of Energy and is also working with the
MAPP Year 2000 Task Force and a utility industry consortium to obtain and
share utility-specific Year 2000 compliance information.
The internal inventory phase was substantially completed in June 1998.
Regular contact with third parties with whom the Company has material
relationships will continue throughout 1999.
-11-
Evaluation. This phase involves computer program code review and testing,
vendor contacts, System testing and fully-integrated System testing where
practical. The objective of this phase is to develop and update the
remediation plan. Some Systems, upon inspection, are determined to be
non-compliant and are immediately placed on the remediation schedule. Some
Systems require testing to determine compliance status. The evaluation
phase was substantially complete in February 1999.
Remediation. In this phase each System is either fixed, replaced or
removed. Critical Systems fixed or replaced are tested again for Year 2000
readiness. Remediation is expected to be substantially complete by
June 30, 1999. The Company estimates that as of May 7, 1999 the remediation
phase is approximately 57 percent complete based on the number of systems
remediated.
Contingency Planning. Each business segment has developed contingency plans
designed to continue critical processes in the event the Company
experiences Year 2000 disruptions despite remediation and testing. These
plans include establishment of internal communications, securing adequate
on-site supplies of certain critical materials and staffing for key Year
2000 dates. Contingency plans will also be tested when appropriate. Some
contingency plans have already undergone testing. The Company successfully
participated in the April 9, 1999 NERC drill which tested inter and intra
backup communications for the scenario that assumed 10 percent of voice and
data communications had failed. The Company plans to participate in the
September 1999 NERC drill which will be a dress rehearsal for the
millennium rollover. Contingency plans are expected to be substantially
complete by June 30, 1999. The Company estimates that as of May 7, 1999 the
contingency planning phase is approximately 75 percent complete.
The Company is on schedule for substantial Year 2000 readiness by June 30, 1999,
with certain systems reserved for final integrated testing during scheduled
maintenance outages at certain Company generating facilities in the second half
of 1999.
Costs. In the ordinary course of business over the last five years, the Company
has replaced major business and operating computer systems. These systems should
require minimal remediation efforts because of their recent implementation.
Formal Year 2000 readiness plans were established in March 1998. Since that
time, the Company has incurred $1.7 million in expenses primarily for labor
associated with inventory, evaluation and remediation efforts. The Company
estimates its remaining costs to prepare for the Year 2000 will be $5 million to
$7 million, the majority of which are non-labor costs that will be incurred
during the second and third quarters of 1999. Funds to address Year 2000 issues
have been provided for in the Company's existing budgets. These costs include
the assignment of existing personnel to Year 2000 projects, maintenance and
repair expenses, and capitalized improvements. To date no critical projects have
been deferred because of Year 2000 issues. The Company does not anticipate that
its costs associated with Year 2000 readiness will materially impact the
Company's earnings in any year.
Risks. Based upon information to date, the Company believes that, in the most
reasonably likely worst-case scenario, Year 2000 issues could result in abnormal
operating conditions, such as short-term interruption of generation,
transmission and distribution functions within Electric Operations, as well as
Company-wide loss of system monitoring and control functions, and loss of voice
communications. These conditions, along with power outages due to possible
instability of the regional electric transmission grid, could result in
temporary interruption of service to customers. The Company does not believe the
overall impact of this scenario will have a material impact on its financial
condition or operations due to the anticipated short-term nature of
interruptions.
--------------------------
Readers are cautioned that forward-looking statements including those contained
above, should be read in conjunction with the Company's disclosures under the
heading: "SAFE HARBOR STATEMENT UNDER THE PRIVATE SECURITIES LITIGATION REFORM
ACT OF 1995" located in the preface of this Form 10-Q.
-12-
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
The Company's securities portfolio has exposure to both price and interest rate
risk. Investments held principally for near-term sale are classified as trading
securities and recorded at fair value. Trading securities consist primarily of
the common stock of publicly traded companies, with utilities being the largest
industry sector. Investments held for an indefinite period of time are
classified as available-for-sale securities and also recorded at fair value. The
available-for-sale securities portfolio consists primarily of the preferred
stock of utilities and financial institutions with investment grade debt
ratings.
In strategies designed to reduce market risks, the Company sells common stock
short and enters into short sales of treasury futures contracts. Selling common
stock short is intended to reduce price risks associated with securities in the
Company's trading securities portfolio. The stock sold short consists primarily
of the stock of companies in similar industries. Treasury futures are used as a
hedge to reduce interest rate risks associated with holding fixed dividend
preferred stocks included in the Company's available-for-sale securities
portfolio. Generally, treasury futures contracts mature in 90 days.
March 31, 1999 Fair Value
- --------------------------------------------------------------------------------
Millions
Trading Securities Portfolio $167.2
Available-For-Sale Securities Portfolio $53.3
Other Available-For-Sale Securities $17.2
- --------------------------------------------------------------------------------
The notional fair value of outstanding short sales of common stock was
approximately 85 percent of the fair value of the trading securities
portfolio.
The notional fair value of outstanding sales of treasury futures contracts
was $25.7 million, which represented 213 contracts with a notional basis of
$25.7 million.
Securities in a grantor trust established to fund certain employee
benefits.
PART II. OTHER INFORMATION
ITEM 5. OTHER INFORMATION
Reference is made to the Company's 1998 Form 10-K for background information on
the following updates. Unless otherwise indicated, cited references are to the
Company's 1998 Form 10-K.
Ref. Page 2. - Electric Sales - Eighth Paragraph
Ref. Page 25. - Outlook - Electric Operations - Tenth Paragraph
In 1998 the United States imported a record 42 million tons of steel which
represented an 83 percent increase over the 23 million ton average for the
previous eight years (1990-1997).
For the first three months of 1999, United States imports were running at about
the same levels as 1998. However, the United States Commerce Department has made
preliminary findings that set substantial antidumping margins on hot rolled
steel products from Japan and Brazil, and countervailing duty margins on
products from Brazil. This action should have a positive effect for the domestic
steel industry by reducing imports.
If imports continue at 1998 levels, lower demand for steel produced in the
United States is likely to have an adverse affect on the taconite producers and
the economy as a whole in Northern Minnesota. The Company is unable to predict
the eventual impact of this issue on the Company's Electric Operations.
-13-
Ref. Page 3. - Contract Status for Minnesota Power Large Power Customers
On March 25, 1999 Potlatch Corp. signed an agreement with Minnesota Power to
extend its contract to December 31, 2004 and to include in the billing the
Potlatch location in Grand Rapids. This agreement is pending regulatory
approval.
Ref. Page 4. - Purchased Power and Capacity Sales - Purchased Power - Second
Paragraph
Ref. Page 25. - Outlook - Electric Operations - First Paragraph
On March 18, 1999 the Company, through wholly owned subsidiary Rainy River
Energy Corporation, entered into a 15-year power purchase agreement with a
subsidiary of LS Power, LLC (LS Power), a privately owned independent power
producer. Under the agreement, the Company will purchase approximately 275
megawatts from a 1,100 megawatt natural gas-fired combined cycle generation
facility to be built, owned and operated by LS Power near Chicago, Illinois.
Construction of the generation facility is scheduled to begin in mid 1999 with
commercial operation expected in mid 2001. The Company expects the agreement
will enhance its ability to serve an expanding customer base outside of
Wisconsin and Minnesota, 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. The Company 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. The Company
will be responsible for the purchase and transportation of natural gas. The
Company will incur no significant charges until the facility commences
operations.
The Company can terminate the agreement under certain circumstances, including
prolonged construction delays or facility outages.
Ref. Page 6. - Minnesota Public Utilities Commission - Seventh Full Paragraph
Ref. Page 25. - Outlook - Electric Operations - First Paragraph
In 1998 the MPUC initiated a proceeding to analyze the recommendation made by
the Minnesota Department of Public Service to discontinue the recovery of lost
margins for investments in Conservation Improvement Programs (CIP). The MPUC
required the Company and other gas and electric utilities to file specific plans
for phasing-out lost margin recovery. The Company has proposed a phase-out plan
that would recover the lost margins associated with large power customer
contract revisions related to CIP activity. If the plan is accepted by the MPUC,
the Company would recover approximately $3.5 million in 1999, and $2.0 million
in each of the years 2000, 2001, 2002 and 2003. The MPUC has not established a
time frame for acting on these proposals, and the Company is unable to predict
the outcome of this matter.
Ref. Page 6. - Insert after Seventh Full Paragraph
Ref. Page 25. - Outlook - Electric Operations - First Paragraph
Public Service Commission of Wisconsin. On April 15, 1999 Wisconsin Public
Service Corporation (WPSC) and Minnesota Power announced a preliminary plan to
construct a 250 mile 345-kilovolt transmission line from Wausau, Wisconsin to
Duluth, Minnesota. The project, called "Power Up Wisconsin," is being
constructed to enhance reliability in Wisconsin and is estimated to cost between
$125 million and $175 million. Potential routes for the line are being
developed, using current rights-of-way where possible. The plan will be
submitted to the PSCW and the Minnesota Environmental Quality Board when
construction permit applications are filed this summer. Depending on siting and
regulatory review and approval, the line could be in service during 2002. The
Company currently anticipates an approximate 50 percent ownership in the
project.
-14-
Ref. Page 9. - National Pollutant Discharge Elimination System Permits Table
The Company anticipates the Minnesota Pollution Control Agency will issue new
National Pollutant Discharge Elimination System Permits for the Boswell Energy
Center and the Laskin Energy Center (Laskin) in the second quarter of 1999. The
Laskin permit will contain a schedule of compliance requiring the construction
of a new ash disposal pond by December 31, 2000. The Company expects to spend
approximately $3.3 million in 1999 and another $3.3 million in 2000 to construct
the Laskin ash disposal pond.
Ref. Page 10. - Water Services - Third Full Paragraph
Ref. Page 25. - Outlook - Water Services - Twelfth Paragraph
On March 31, 1999 Heater announced it had reached an agreement to acquire the
water and wastewater operations of Mid South Water System, Inc. of Sherills
Ford, North Carolina, which serves approximately 12,000 customers. The
acquisition is expected to be completed in the next few months pending
regulatory approval. Upon completion, Heater will be the largest investor-owned
water utility in North Carolina serving almost 45,000 customers in 29 counties.
Ref. Page 12. - Automotive Services - Second Paragraph
Ref. Page 17. - Automotive Services - Table
Ref. Page 26. - Outlook - Automotive Services - First Paragraph
On April 30, 1999 ADESA acquired Des Moines Auto Auction located in Des Moines,
Iowa. The three lane auction which primarily serves consignment and fleet/lease
accounts operates on a 25 acre facility. The auction offers on site
reconditioning and pick up and delivery services. AFC provides dealer
floorplanning at this auction. ADESA operates 28 vehicle auction facilities.
Ref. Page 13. - Investments - Real Estate Operations - Sixth Paragraph
Ref. Page 18. - Third Paragraph
Ref. Page 26. - Outlook - Investments - Second Paragraph
On May 4, 1999 MP Real Estate Holdings, Inc., a wholly owned subsidiary of the
Company, signed an agreement to purchase, for $45 million, certain real estate
properties located in Cape Coral, Florida, from a subsidiary 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 to be purchased include approximately 2,500 acres of commercial and
residential zoned land, including home sites, a golf resort, marina, shopping
center and commercial buildings. The Company anticipates closing this
transaction in June 1999, once the necessary state regulatory approval has been
received. The Company anticipates funding this transaction with internally
generated funds and proceeds from the sale of certain investments in the
Company's securities portfolio.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits.
27 Financial Data Schedule
(b) Reports on Form 8-K.
Report on Form 8-K dated and filed February 12, 1999 with respect to Item 5.
Other Events.
Report on Form 8-K dated and filed February 26, 1999 with respect to Item 5.
Other Events.
-15-
SIGNATURES
Pursuant to the requirements 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.
---------------------------------
(Registrant)
May 7, 1999 D. G. Gartzke
---------------------------------
D. G. Gartzke
Senior Vice President - Finance
and Chief Financial Officer
May 7, 1999 Mark A. Schober
---------------------------------
Mark A. Schober
Controller
-16-
INDEX TO EXHIBITS
Exhibit
Number
27 Financial Data Schedule
UT
1,000,000
3-MOS
DEC-31-1999
JAN-01-1999
MAR-31-1999
PER-BOOK
1,180
462
670
53
224
2,589
538
0
321
800
95
12
672
160
0
0
9
0
0
0
782
2,589
258
7
212
226
30
(4)
35
14
21
1
20
17
0
30
0.30
0.30
Included a $2 million Loss from Equity Investments and $2 million for
Distributions on Redeemable Preferred Securities of Subsidiary.
